American Electric Power (AEP) 10-K24 Feb 222021 FY Annual reportFinancial data

Company Profile

Cover

Cover	12 Months Ended
Cover	Dec. 31, 2021USD ($)shares
Entity Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2021
Document Transition Report	false
Entity File Number	1-3525
Entity Registrant Name	AMERICAN ELECTRIC POWER CO INC.
Entity Incorporation, State or Country Code	NY
Entity Tax Identification Number	13-4922640
Entity Address, Address Line One	1 Riverside Plaza,
Entity Address, City or Town	Columbus,
Entity Address, State or Province	OH
Entity Address, Postal Zip Code	43215-2373
City Area Code	(614)
Local Phone Number	716-1000
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	true
Entity Shell Company	false
Entity Public Float \| $	$ 42,651,294,349
Entity Common Stock, Shares Outstanding	504,212,015
Entity Central Index Key	0000004904
Amendment Flag	false
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	FY
Current Fiscal Year End Date	--12-31
Auditor Firm ID	238
Auditor Location	Columbus, Ohio
Auditor Name	PricewaterhouseCoopers LLP
AEP Texas Inc. [Member]
Entity Information [Line Items]
Entity File Number	333-221643
Entity Registrant Name	AEP TEXAS INC.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	51-0007707
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding	100,000,000
Entity Central Index Key	0001721781
Auditor Firm ID	238
Auditor Location	Columbus, Ohio
Auditor Name	PricewaterhouseCoopers LLP
AEP Transmission Co [Member]
Entity Information [Line Items]
Entity File Number	333-217143
Entity Registrant Name	AEP TRANSMISSION COMPANY, LLC
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	46-1125168
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Central Index Key	0001702494
Auditor Firm ID	238
Auditor Location	Columbus, Ohio
Auditor Name	PricewaterhouseCoopers LLP
Appalachian Power Co [Member]
Entity Information [Line Items]
Entity File Number	1-3457
Entity Registrant Name	APPALACHIAN POWER COMPANY
Entity Incorporation, State or Country Code	VA
Entity Tax Identification Number	54-0124790
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding	13,499,500,000,000
Entity Central Index Key	0000006879
Auditor Firm ID	238
Auditor Location	Columbus, Ohio
Auditor Name	PricewaterhouseCoopers LLP
Indiana Michigan Power Co [Member]
Entity Information [Line Items]
Entity File Number	1-3570
Entity Registrant Name	INDIANA MICHIGAN POWER COMPANY
Entity Incorporation, State or Country Code	IN
Entity Tax Identification Number	35-0410455
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding	1,400,000,000,000
Entity Central Index Key	0000050172
Auditor Firm ID	238
Auditor Location	Columbus, Ohio
Auditor Name	PricewaterhouseCoopers LLP
Ohio Power Co [Member]
Entity Information [Line Items]
Entity File Number	1-6543
Entity Registrant Name	OHIO POWER COMPANY
Entity Incorporation, State or Country Code	OH
Entity Tax Identification Number	31-4271000
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding	27,952,473,000,000
Entity Central Index Key	0000073986
Auditor Firm ID	238
Auditor Location	Columbus, Ohio
Auditor Name	PricewaterhouseCoopers LLP
Public Service Co Of Oklahoma [Member]
Entity Information [Line Items]
Entity File Number	0-343
Entity Registrant Name	PUBLIC SERVICE COMPANY OF OKLAHOMA
Entity Incorporation, State or Country Code	OK
Entity Tax Identification Number	73-0410895
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding	9,013,000,000,000
Entity Central Index Key	0000081027
Auditor Firm ID	238
Auditor Location	Columbus, Ohio
Auditor Name	PricewaterhouseCoopers LLP
Southwestern Electric Power Co [Member]
Entity Information [Line Items]
Entity File Number	1-3146
Entity Registrant Name	SOUTHWESTERN ELECTRIC POWER COMPANY
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	72-0323455
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding	3,680,000,000
Entity Central Index Key	0000092487
Auditor Firm ID	238
Auditor Location	Columbus, Ohio
Auditor Name	PricewaterhouseCoopers LLP
The NASDAQ Stock Market \| Common Stock, $6.50 par value [Member]
Entity Information [Line Items]
Title of 12(b) Security	Common Stock, $6.50 par value
Trading Symbol	AEP
Security Exchange Name	NASDAQ
The NASDAQ Stock Market \| 6.125% Corporate Units [Member]
Entity Information [Line Items]
Title of 12(b) Security	6.125% Corporate Units
Trading Symbol	AEPPL
Security Exchange Name	NASDAQ
The NASDAQ Stock Market \| 6.125% Corporate Units
Entity Information [Line Items]
Title of 12(b) Security	6.125% Corporate Units
Trading Symbol	AEPPZ
Security Exchange Name	NASDAQ

Consolidated Statements of Inco

Consolidated Statements of Income - USD ($) $ in Millions	12 Months Ended
Consolidated Statements of Income - USD ($) $ in Millions	Dec. 31, 2021		Dec. 31, 2020		Dec. 31, 2019
Revenues
Revenue from Contracts with Customers	$ 16,792		$ 14,918.5		$ 15,561.4
Sales to AEP Affiliates	0		0		0
TOTAL REVENUES	16,792		14,918.5		15,561.4
Expenses
Other Operation	2,547.7		2,572.4		2,743.7
Maintenance	1,121.8		1,010.4		1,213.9
Asset Impairments and Other Related Charges	11.6		0		156.4
Depreciation and Amortization	2,825.7		2,682.8		2,514.5
Taxes Other Than Income Taxes	1,407.6		1,295.5		1,234.5
TOTAL EXPENSES	13,380.7		11,930.8		12,969.1
OPERATING INCOME (LOSS)	3,411.3		2,987.7		2,592.3
Other Income (Expense):
Other Income	41.4		57		26.6
Allowance for Equity Funds Used During Construction	139.7		148.1		168.4
Non-Service Cost Components of Net Periodic Benefit Cost	118.6		119		120
Interest Expense	(1,199.1)		(1,165.7)		(1,072.5)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	2,511.9		2,146.1		1,834.8
Income Tax Expense (Benefit)	115.5		40.5		(12.9)
Equity Earnings (Loss) of Unconsolidated Subsidiaries	91.7		91.1		72.1
Net Income (Loss)	2,488.1		2,196.7		1,919.8
Net Income Attributable to Noncontrolling Interests	0		(3.4)		(1.3)
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS	$ 2,488.1		$ 2,200.1		$ 1,921.1
Earnings Per Share
WEIGHTED AVERAGE NUMBER OF BASIC AEP COMMON SHARES OUTSTANDING	500,522,177		495,718,223		493,694,345
Total Basic Earnings (Loss) per Share Attributable to AEP Common Shareholders	$ 4.97		$ 4.44		$ 3.89
WEIGHTED AVERAGE NUMBER OF DILUTED AEP COMMON SHARES OUTSTANDING	501,784,032		497,226,867		495,306,238
TOTAL DILUTED EARNINGS PER SHARE ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS	$ 4.96		$ 4.42		$ 3.88
Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers	$ 9,852.2		$ 8,753.2		$ 9,245.7
Transmission and Distribution Utilities [Member]
Revenues
Revenue from Contracts with Customers	4,464.1		4,238.7		4,319
Generation and Marketing Revenues [Member]
Revenues
Revenue from Contracts with Customers	2,108.3		1,621		1,721.8
Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	367.4		305.6		274.9
TOTAL REVENUES	227.6	[1],[2]	61.5	[3],[4]	61.7	[5],[6]
Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold	5,466.3		4,369.7		5,106.1
AEP Texas Inc. [Member]
Revenues
Revenue from Contracts with Customers	1,587.7		1,528		1,551.6
Sales to AEP Affiliates	3.9		90.8		160.5
TOTAL REVENUES	1,593.8		1,618.9		1,709.3
Expenses
Other Operation	489.5		488.9		492
Maintenance	86.2		80.5		158.8
Asset Impairments and Other Related Charges	0		0		32.5
Depreciation and Amortization	387		529.8		622.3
Taxes Other Than Income Taxes	155.1		136.4		140.6
TOTAL EXPENSES	1,117.8		1,249.3		1,477.3
OPERATING INCOME (LOSS)	476		369.6		232
Other Income (Expense):
Interest Income	0.8		1.4		3.4
Allowance for Equity Funds Used During Construction	21.5		19.4		15.2
Non-Service Cost Components of Net Periodic Benefit Cost	11.1		11.2		11.3
Interest Expense	(176.5)		(171.8)		(137.2)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	332.9		229.8		124.7
Income Tax Expense (Benefit)	43.1		(11.2)		(53.6)
Net Income (Loss)	289.8		241		178.3
AEP Texas Inc. [Member] \| Transmission and Distribution Utilities [Member]
Revenues
Revenue from Contracts with Customers	1,586.4		1,524.9		1,545.9
AEP Texas Inc. [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	3.5		3.2		2.9
TOTAL REVENUES	0	[7]	87.5	[8]	157.1	[9]
AEP Texas Inc. [Member] \| Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold	0		13.7		31.1
AEP Transmission Co [Member]
Revenues
Revenue from Contracts with Customers	1,410.9		1,232.7		1,042.1
Sales to AEP Affiliates	1,153.9		896.3		806.7
TOTAL REVENUES	1,469.3		1,145.7		1,021.4
Expenses
Other Operation	105.5		99.8		93.9
Maintenance	18.4		10.2		15.4
Depreciation and Amortization	297.3		249		176
Taxes Other Than Income Taxes	238.8		205.2		168.9
TOTAL EXPENSES	660		564.2		454.2
OPERATING INCOME (LOSS)	809.3		581.5		567.2
Other Income (Expense):
Interest Income	0.5		2.4		3
Allowance for Equity Funds Used During Construction	67.2		74		84.3
Interest Expense	(141.2)		(127.8)		(97.4)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	735.8		530.1		557.1
Income Tax Expense (Benefit)	144.1		106.7		117.4
Net Income (Loss)	591.7		423.4		439.7
AEP Transmission Co [Member] \| Transmission [Member]
Revenues
Revenue from Contracts with Customers	315.1		248.8		214.6
AEP Transmission Co [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	0.3		0.6		0.1
TOTAL REVENUES	0	[7]	0	[8]	0	[9]
Appalachian Power Co [Member]
Revenues
Revenue from Contracts with Customers	3,092.9		2,809.2		2,911.1
Sales to AEP Affiliates	197.9		174.7		205.3
TOTAL REVENUES	3,105.2		2,796.2		2,924.7
Expenses
Other Operation	610		530.5		567.6
Maintenance	265.5		226.8		255.4
Asset Impairments and Other Related Charges	0		0		92.9
Re-Establishment of Regulatory Asset - Coal Fired Generation	0		(49)		0
Depreciation and Amortization	546.2		507.5		466.8
Taxes Other Than Income Taxes	154.2		150.2		146.2
TOTAL EXPENSES	2,555.8		2,239.6		2,527.4
OPERATING INCOME (LOSS)	549.4		556.6		397.3
Other Income (Expense):
Interest Income	1		1.6		2.4
Allowance for Equity Funds Used During Construction	15.6		14.6		16.6
Non-Service Cost Components of Net Periodic Benefit Cost	19		18.8		17
Interest Expense	(214)		(217.6)		(205)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	371		374		228.3
Income Tax Expense (Benefit)	22.1		4.3		(78)
Net Income (Loss)	348.9		369.7		306.3
Appalachian Power Co [Member] \| Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers	2,895.5		2,610.9		2,708.2
Appalachian Power Co [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	11.8		10.6		11.2
TOTAL REVENUES	0	[7]	0	[8]	0	[9]
Appalachian Power Co [Member] \| Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold	440.3		513.3		607.5
Appalachian Power Co [Member] \| Purchased Electricity for Resale [Member]
Expenses
Cost of Goods and Services Sold	539.6		360.3		391
Indiana Michigan Power Co [Member]
Revenues
Revenue from Contracts with Customers	2,330.7		2,236		2,308.1
Sales to AEP Affiliates	3.8		10.5		10.5
Other Revenues - Affiliated	54		60.8		63.4
TOTAL REVENUES	2,326.7		2,241.8		2,306.7
Expenses
Purchased Electricity from AEP Affiliates	217.9		172.8		214.9
Other Operation	645.2		650		641.2
Maintenance	210		193.2		231.2
Depreciation and Amortization	446		411.6		350.6
Taxes Other Than Income Taxes	110.8		107.1		105.1
TOTAL EXPENSES	1,968.8		1,878.9		1,965.9
OPERATING INCOME (LOSS)	357.9		362.9		340.8
Other Income (Expense):
Other Income	11.7		10		18.2
Allowance for Equity Funds Used During Construction	12.8		11.5		19.4
Non-Service Cost Components of Net Periodic Benefit Cost	16.4		16.7		17.7
Interest Expense	(116.8)		(112.3)		(117.9)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	269.2		277.3		258.8
Income Tax Expense (Benefit)	(10.6)		(7.5)		(10.6)
Net Income (Loss)	279.8		284.8		269.4
Indiana Michigan Power Co [Member] \| Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers	2,261.2		2,165.3		2,222.1
Indiana Michigan Power Co [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	7.7		5.2		10.7
Sales to AEP Affiliates	60		69		73
TOTAL REVENUES	0	[7]	0	[8]	0	[9]
Indiana Michigan Power Co [Member] \| Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold	162.1		162		190.6
Indiana Michigan Power Co [Member] \| Purchased Electricity for Resale [Member]
Expenses
Cost of Goods and Services Sold	176.8		182.2		232.3
Ohio Power Co [Member]
Revenues
Revenue from Contracts with Customers	2,837.5		2,665		2,748.8
Sales to AEP Affiliates	24.8		41.5		27.3
TOTAL REVENUES	2,899.1		2,749.1		2,797.6
Expenses
Purchased Electricity from AEP Affiliates	51.9		119.7		156
Amortization of Generation Deferrals	0		0		65.3
Other Operation	836.8		822.6		742.6
Maintenance	158.2		127.1		150.1
Depreciation and Amortization	303.3		276.6		240.9
Taxes Other Than Income Taxes	485.7		450.2		434.2
TOTAL EXPENSES	2,513.9		2,345.4		2,396.4
OPERATING INCOME (LOSS)	385.2		403.7		401.2
Other Income (Expense):
Interest Income	0.6		1		3.2
Carrying Costs Income	1.2		1.6		1
Allowance for Equity Funds Used During Construction	10.8		12.5		18.2
Non-Service Cost Components of Net Periodic Benefit Cost	14.6		15		14.6
Interest Expense	(124.4)		(117.2)		(106.2)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	288		316.6		332
Income Tax Expense (Benefit)	34.4		45.2		34.9
Net Income (Loss)	253.6		271.4		297.1
Ohio Power Co [Member] \| Transmission and Distribution Utilities [Member]
Revenues
Revenue from Contracts with Customers	2,863.7		2,698.6		2,759.5
Ohio Power Co [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	10.6		9		10.8
TOTAL REVENUES	19	[7]	17.5	[8]	17.1	[9]
Ohio Power Co [Member] \| Purchased Electricity for Resale [Member]
Expenses
Cost of Goods and Services Sold	678		549.2		607.3
Public Service Co Of Oklahoma [Member]
Revenues
Revenue from Contracts with Customers	1,474.3		1,263.9		1,512.8
Sales to AEP Affiliates	4.2		5.2		6.1
TOTAL REVENUES	1,474.4		1,266.1		1,481.8
Expenses
Other Operation	353.8		327.3		315
Maintenance	97.2		98.4		100.7
Depreciation and Amortization	196.6		173.5		169.5
Taxes Other Than Income Taxes	49.6		47.5		43.3
TOTAL EXPENSES	1,281.5		1,090.2		1,282.5
OPERATING INCOME (LOSS)	192.9		175.9		199.3
Other Income (Expense):
Interest Income	4.3		0.1		1.2
Allowance for Equity Funds Used During Construction	2.4		4		2.7
Non-Service Cost Components of Net Periodic Benefit Cost	8.5		8.5		8.4
Interest Expense	(62.9)		(60.3)		(66.5)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	145.2		128.2		145.1
Income Tax Expense (Benefit)	4.1		5.2		7.5
Net Income (Loss)	141.1		123		137.6
Public Service Co Of Oklahoma [Member] \| Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers	1,465.3		1,246.1		1,469.6
Public Service Co Of Oklahoma [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	4.9		14.8		6.1
TOTAL REVENUES	0	[7]	0	[8]	0	[9]
Public Service Co Of Oklahoma [Member] \| Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold	584.3		443.5		654
Southwestern Electric Power Co [Member]
Revenues
Revenue from Contracts with Customers	2,126		1,735.3		1,799.2
Sales to AEP Affiliates	41.4		41		36.9
Provision for Refund	(0.4)		(2)		(32)
TOTAL REVENUES	2,131.8		1,738.5		1,750.9
Expenses
Other Operation	360.3		338.3		348
Maintenance	136.7		129.7		145.6
Asset Impairments and Other Related Charges	11.6		0		0
Depreciation and Amortization	295		272.7		249.1
Taxes Other Than Income Taxes	117.7		102.8		100.2
TOTAL EXPENSES	1,792.3		1,448		1,495.2
OPERATING INCOME (LOSS)	339.5		290.5		255.7
Other Income (Expense):
Interest Income	9.2		2.1		2.6
Allowance for Equity Funds Used During Construction	7		7.7		6.8
Non-Service Cost Components of Net Periodic Benefit Cost	8.3		8.4		8.5
Interest Expense	(125.9)		(118.5)		(119.1)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	238.1		190.2		154.5
Income Tax Expense (Benefit)	(0.6)		9.4		(4.7)
Equity Earnings (Loss) of Unconsolidated Subsidiaries	3.4		2.9		3
Net Income (Loss)	242.1		183.7		162.2
Net Income Attributable to Noncontrolling Interests	3.1		2.9		3.6
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS	239		180.8		158.6
Southwestern Electric Power Co [Member] \| Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers	2,088.9		1,696.6		1,744.6
Southwestern Electric Power Co [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	1.9		2.9		1.4
TOTAL REVENUES	0	[7]	0	[8]	0	[9]
Southwestern Electric Power Co [Member] \| Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold	$ 871		$ 604.5		$ 652.3

[1]	Amounts include affiliated and nonaffiliated revenues.
[2]	Generation & Marketing includes economic hedge activity.
[3]	Amounts include affiliated and nonaffiliated revenues.
[4]	Generation & Marketing includes economic hedge activity.
[5]	Amounts include affiliated and nonaffiliated revenues.
[6]	Generation & Marketing includes economic hedge activity.
[7]	Amounts include affiliated and nonaffiliated revenues.
[8]	Amounts include affiliated and nonaffiliated revenues.
[9]	Amounts include affiliated and nonaffiliated revenues.

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income (Loss) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Net Income (Loss)	$ 2,488.1	$ 2,196.7	$ 1,919.8
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	250.5	6.9	(79.4)
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(8.1)	(7)	(5.6)
Pension and OPEB Funded Status, Net of Tax	27.5	62.7	57.7
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)	269.9	62.6	(27.3)
TOTAL COMPREHENSIVE INCOME (LOSS)	2,758	2,259.3	1,892.5
Total Comprehensive Income Attributable to Noncontrolling Interest	0	(3.4)	(1.3)
TOTAL COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO SHAREHOLDERS	2,758	2,262.7	1,893.8
Cash Flow Hedges, Tax	66.6	1.8	(21.1)
Amortization of Pension and OPEB Deferred Costs, Tax	(2.2)	(1.9)	(1.5)
Pension and OPEB Funded Status, Tax	7.3	16.7	15.3
AEP Texas Inc. [Member]
Net Income (Loss)	289.8	241	178.3
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	1	1.1	1
Amortization of Pension and OPEB Deferred Costs, Net of Tax	0.2	0.2	0.2
Pension and OPEB Funded Status, Net of Tax	1.2	2.6	1.1
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)	2.4	3.9	2.3
TOTAL COMPREHENSIVE INCOME (LOSS)	292.2	244.9	180.6
Cash Flow Hedges, Tax	0.3	0.3	0.3
Amortization of Pension and OPEB Deferred Costs, Tax	0	0	0
Pension and OPEB Funded Status, Tax	0.3	0.7	0.3
AEP Transmission Co [Member]
Net Income (Loss)	591.7	423.4	439.7
Appalachian Power Co [Member]
Net Income (Loss)	348.9	369.7	306.3
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	8.3	(1.7)	(0.9)
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(4.2)	(3.8)	(2.5)
Pension and OPEB Funded Status, Net of Tax	13.1	7.7	13.4
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)	17.2	2.2	10
TOTAL COMPREHENSIVE INCOME (LOSS)	366.1	371.9	316.3
Cash Flow Hedges, Tax	2.2	(0.5)	(0.2)
Amortization of Pension and OPEB Deferred Costs, Tax	(1.1)	(1)	(0.7)
Pension and OPEB Funded Status, Tax	3.5	2	3.6
Indiana Michigan Power Co [Member]
Net Income (Loss)	279.8	284.8	269.4
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	1.6	1.6	1.6
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(0.1)	(0.1)	(0.2)
Pension and OPEB Funded Status, Net of Tax	4.2	3.1	0.8
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)	5.7	4.6	2.2
TOTAL COMPREHENSIVE INCOME (LOSS)	285.5	289.4	271.6
Cash Flow Hedges, Tax	0.4	0.4	0.4
Amortization of Pension and OPEB Deferred Costs, Tax	0	0	0
Pension and OPEB Funded Status, Tax	1.1	0.8	0.2
Ohio Power Co [Member]
Net Income (Loss)	253.6	271.4	297.1
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	0	0	(1)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)			(1)
TOTAL COMPREHENSIVE INCOME (LOSS)	253.6	271.4	296.1
Cash Flow Hedges, Tax	0	0	(0.3)
Public Service Co Of Oklahoma [Member]
Net Income (Loss)	141.1	123	137.6
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	(0.1)	(1)	(1)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)	(0.1)	(1)	(1)
TOTAL COMPREHENSIVE INCOME (LOSS)	141	122	136.6
Cash Flow Hedges, Tax	0	(0.3)	(0.3)
Southwestern Electric Power Co [Member]
Net Income (Loss)	242.1	183.7	162.2
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	1.5	1.5	1.5
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(1.6)	(1.5)	(1.1)
Pension and OPEB Funded Status, Net of Tax	4.9	3.2	3.7
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)	4.8	3.2	4.1
TOTAL COMPREHENSIVE INCOME (LOSS)	246.9	186.9	166.3
Total Comprehensive Income Attributable to Noncontrolling Interest	3.1	2.9	3.6
TOTAL COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO SHAREHOLDERS	243.8	184	162.7
Cash Flow Hedges, Tax	0.4	0.4	0.4
Amortization of Pension and OPEB Deferred Costs, Tax	(0.4)	(0.4)	(0.3)
Pension and OPEB Funded Status, Tax	$ 1.3	$ 0.9	$ 1

Condensed Consolidated Statemen

Condensed Consolidated Statements of Changes in Equity - USD ($) $ in Millions		Total	AEP Texas Inc. [Member]	AEP Transmission Co [Member]	Appalachian Power Co [Member]	Indiana Michigan Power Co [Member]	Ohio Power Co [Member]	Public Service Co Of Oklahoma [Member]	Southwestern Electric Power Co [Member]	Common Stock [Member]	Common Stock [Member]Appalachian Power Co [Member]	Common Stock [Member]Indiana Michigan Power Co [Member]	Common Stock [Member]Ohio Power Co [Member]	Common Stock [Member]Public Service Co Of Oklahoma [Member]	Common Stock [Member]Southwestern Electric Power Co [Member]	Additional Paid-in Capital [Member]		Additional Paid-in Capital [Member]AEP Texas Inc. [Member]	Additional Paid-in Capital [Member]AEP Transmission Co [Member]	Additional Paid-in Capital [Member]Appalachian Power Co [Member]	Additional Paid-in Capital [Member]Indiana Michigan Power Co [Member]	Additional Paid-in Capital [Member]Ohio Power Co [Member]	Additional Paid-in Capital [Member]Public Service Co Of Oklahoma [Member]	Additional Paid-in Capital [Member]Southwestern Electric Power Co [Member]	Retained Earnings [Member]		Retained Earnings [Member]AEP Texas Inc. [Member]	Retained Earnings [Member]AEP Transmission Co [Member]	Retained Earnings [Member]Appalachian Power Co [Member]	Retained Earnings [Member]Indiana Michigan Power Co [Member]	Retained Earnings [Member]Ohio Power Co [Member]	Retained Earnings [Member]Public Service Co Of Oklahoma [Member]	Retained Earnings [Member]Southwestern Electric Power Co [Member]	Accumulated Other Comprehensive Income [Member]	Accumulated Other Comprehensive Income [Member]AEP Texas Inc. [Member]	Accumulated Other Comprehensive Income [Member]Appalachian Power Co [Member]	Accumulated Other Comprehensive Income [Member]Indiana Michigan Power Co [Member]	Accumulated Other Comprehensive Income [Member]Ohio Power Co [Member]	Accumulated Other Comprehensive Income [Member]Public Service Co Of Oklahoma [Member]	Accumulated Other Comprehensive Income [Member]Southwestern Electric Power Co [Member]	Noncontrolling Interests [Member]	Noncontrolling Interests [Member]Southwestern Electric Power Co [Member]	AEP Wind Holdings LLC [Member]	AEP Wind Holdings LLC [Member]Noncontrolling Interests [Member]	Santa Rita East [Member]	Santa Rita East [Member]Noncontrolling Interests [Member]	Dry Lake Solar Project [Member]	Dry Lake Solar Project [Member]Noncontrolling Interests [Member]
TOTAL MEMBER'S EQUITY				$ 3,569.8															$ 2,480.6									$ 1,089.2
Common Stock, Dividends, Per Share, Declared		$ 2.71
Beginning Balance at Dec. 31, 2018		$ 19,059.4	$ 2,580.5		$ 4,006.1	$ 2,352.8	$ 2,297.4	$ 1,248	$ 2,315.6	$ 3,337.4	$ 260.4	$ 56.6	$ 321.2	$ 157.2	$ 135.7	$ 6,486.1		$ 1,257.9		$ 1,828.7	$ 980.9	$ 838.8	$ 364	$ 676.6	$ 9,325.3		$ 1,337.7		$ 1,922	$ 1,329.1	$ 1,136.4	$ 724.7	$ 1,508.4	$ (120.4)	$ (15.1)	$ (5)	$ (13.8)	$ 1	$ 2.1	$ (5.4)	$ 31	$ 0.3
Beginning Balance, Shares at Dec. 31, 2018		513,450,036								513,500,000
Issuance of Common Stock, Value		$ 65.3								$ 6						59.3
Issuance of Common Stock, Shares		923,595								900,000
Capital Contributions from Member			200															200
Common Stock Dividends		$ (1,350)																							(1,345.5)	[1]
Common Stock Dividends					(150)	(80)	(85)	(11.3)	(37.5)																				(150)	(80)	(85)	(11.3)	(37.5)
Common Stock Dividends									(3.3)																																(4.5)	(3.3)
Forward Equity Purchase Contracts Included in Current and Noncurrent Liabilities as of December 31,		(7.6)														(9.8)	[2]																								2.2
Acquisition																																											$ 134.8	$ 134.8	$ 118.8	$ 118.8
Net Income (Loss)		1,921.1							158.6																1,921.1								158.6
Net Income (Loss) Attributable to Noncontrolling Interests		(1.3)							3.6																																(1.3)	3.6
Net Income (Loss)		1,919.8	178.3	439.7	306.3	269.4	297.1	137.6	162.2																		178.3	439.7	306.3	269.4	297.1	137.6
Other Comprehensive Income (Loss)		(27.3)	2.3		10	2.2	(1)	(1)	4.1																									(27.3)	2.3	10	2.2	(1)	(1)	4.1
Ending Balance at Dec. 31, 2019		$ 19,913.2	2,961.1		4,172.4	2,544.4	2,508.5	1,373.3	2,441.1	$ 3,343.4	260.4	56.6	321.2	157.2	135.7	6,535.6		1,457.9		1,828.7	980.9	838.8	364	676.6	9,900.9		1,516		2,078.3	1,518.5	1,348.5	851	1,629.5	(147.7)	(12.8)	5	(11.6)	0	1.1	(1.3)	281	0.6
Ending Balance, Shares at Dec. 31, 2019		514,373,631								514,400,000
Dividends Paid to Member				0	(150)	(80)	(85)	(11.3)	(37.5)
TOTAL MEMBER'S EQUITY				4,009.5															2,480.6									1,528.9
Common Stock, Dividends, Per Share, Declared		$ 2.84
Issuance of Common Stock, Value		$ 155								$ 15.9						139.1
Issuance of Common Stock, Shares		2,434,723								2,400,000
Capital Contributions from Member				335				50											335				50
Capital Distribution of Radial Assets to Member				(50)															(50)
Common Stock Dividends		$ (1,424.9)																							(1,415)	[1]
Common Stock Dividends					(200)	(85)	(87.5)																						(200)	(85)	(87.5)
Stockholders Equity ASU 2016-13 Adoption		(1.8)				(0.4)	0.3	0.3	1.6																(1.8)					0.4	0.3	0.3	1.6
Reverse Common Stock Split	[3]								0						(135.6)									135.6
Common Stock Dividends									(1.9)																																(9.9)	(1.9)
Forward Equity Purchase Contracts Included in Current and Noncurrent Liabilities as of December 31,		(86.2)														(85.8)	[4]																								(0.4)
Acquisition																																													$ (43.7)	$ (43.7)
Net Income (Loss)		2,200.1							180.8																2,200.1								180.8
Net Income (Loss) Attributable to Noncontrolling Interests		(3.4)							2.9																																(3.4)	2.9
Net Income (Loss)		2,196.7	241	423.4	369.7	284.8	271.4	123	183.7																		241	423.4	369.7	284.8	271.4	123
Other Comprehensive Income (Loss)		62.6	3.9		2.2	4.6		(1)	3.2																									62.6	3.9	2.2	4.6		(1)	3.2
Ending Balance at Dec. 31, 2020		$ 20,774.5	3,206		4,344.3	2,749.2	2,692.7	$ 1,545.6	2,627.7	$ 3,359.3	260.4	56.6	321.2	157.2	0.1	6,588.9		1,457.9		1,828.7	980.9	838.8	414	812.2	10,687.8		1,757		2,248	1,718.7	1,532.7	974.3	1,811.9	(85.1)	(8.9)	7.2	(7)	0	0.1	1.9	223.6	1.6
Ending Balance, Shares at Dec. 31, 2020		516,808,354						10,482,000		516,800,000
Dividends Paid to Member				(5)	(200)	(85)	(87.5)	$ 0	0																			(5)
TOTAL MEMBER'S EQUITY				4,712.9															2,765.6									1,947.3
Common Stock, Dividends, Per Share, Declared		$ 3
Issuance of Common Stock, Value		$ 600.5								$ 49.4						551.1
Issuance of Common Stock, Shares		7,607,821								7,600,000
Capital Contributions from Member			96	184				625	280									96	184				625	280
Common Stock Dividends		$ (1,519.5)																							(1,507.7)	[1]
Common Stock Dividends					(62.5)	(250)	(100)	(20)																					(62.5)	(250)	(100)	(20)
Common Stock Dividends									(4.8)																																(11.8)	(4.8)
Forward Equity Purchase Contracts Included in Current and Noncurrent Liabilities as of December 31,		47.8														32.6									(1.1)																16.3
Acquisition																																															$ 18.9	$ 18.9
Net Income (Loss)		2,488.1							239																2,488.1								239
Net Income (Loss) Attributable to Noncontrolling Interests		0							3.1																																0	3.1
Net Income (Loss)		2,488.1	289.8	591.7	348.9	279.8	253.6	141.1	242.1																		289.8	591.7	348.9	279.8	253.6	141.1
Other Comprehensive Income (Loss)		269.9	2.4		17.2	5.7		(0.1)	4.8																									269.9	2.4	17.2	5.7		(0.1)	4.8
Ending Balance at Dec. 31, 2021		$ 22,680.2	$ 3,594.2		4,647.9	2,784.7	2,846.3	$ 2,291.6	3,149.8	$ 3,408.7	$ 260.4	$ 56.6	$ 321.2	$ 157.2	$ 0.1	$ 7,172.6		$ 1,553.9		$ 1,828.7	$ 980.9	$ 838.8	$ 1,039	$ 1,092.2	$ 11,667.1		$ 2,046.8		$ 2,534.4	$ 1,748.5	$ 1,686.3	$ 1,095.4	$ 2,050.9	$ 184.8	$ (6.5)	$ 24.4	$ (1.3)	$ 0	$ 0	$ 6.7	$ 247	$ (0.1)
Ending Balance, Shares at Dec. 31, 2021		524,416,175						10,482,000		524,400,000
Dividends Paid to Member				(112.5)	$ (62.5)	$ (250)	$ (100)	$ (20)	$ 0																			(112.5)
TOTAL MEMBER'S EQUITY				$ 5,376.1															$ 2,949.6									$ 2,426.5

[1]	(a) Cash dividends declared per AEP common share were $3.00, $2.84 and $2.71 for the years ended December 31, 2021, 2020 and 2019, respectively.
[2]	(b) Includes $(62) million related to a forward equity purchase contract associated with the issuance of Equity Units. See “Equity Units” section of Note 14 for additional information.
[3]	(a) In August 2020, SWEPCo executed a reverse stock split with each 2,048 shares of common stock issued and outstanding being combined into one share of common stock. The common stock of SWEPCo is wholly-owned by Parent.
[4]	(c) Includes $(121) million related to a forward equity purchase contract associated with the issuance of Equity Units. See “Equity Units” section of Note 14 for additional information.

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions		Dec. 31, 2021		Dec. 31, 2020
Current Assets
Cash and Cash Equivalents		$ 403.4		$ 392.7
Restricted Cash		48		45.6
Other Temporary Investments		220.4		200.8
Accounts Receivable:
Customers		720.9		613.6
Accrued Unbilled Revenues		204.4		248.7
Pledged Accounts Receivable - AEP Credit		1,038		1,018.4
Miscellaneous		33.9		33.1
Allowance for Uncollectible Accounts		(55.6)		(71.1)
Total Accounts Receivable		1,941.6		1,842.7
Fuel		307.9		629.4
Materials and Supplies		681.3		680.6
Risk Management Assets		194.4		94.7
Accrued Tax Benefits		121.5		185.3
Assets Held for Sale		2,919.7		0
Regulatory Asset for Under-Recovered Fuel Costs		647.8	[1]	90.7
Margin Deposits		193.4		62
Prepayments and Other Current Assets		129.8		127
TOTAL CURRENT ASSETS		7,809.2		4,351.5
Property, Plant and Equipment
Generation		23,088.1		23,133.9
Transmission		29,911.1		27,886.7
Distribution		24,440		23,972.1
Other Property, Plant and Equipment		5,682.9		5,294.6
Construction Work in Progress		3,684.3		4,025.7
Total Property, Plant and Equipment		86,806.4		84,313
Accumulated Depreciation and Amortization		20,805.1		20,411.4
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		66,001.3	[2]	63,901.6
Other Noncurrent Assets
Regulatory Assets		4,142.3	[1]	3,527
Securitized Assets		552.8		657
Spent Nuclear Fuel and Decommissioning Trusts		3,867		3,306.7
Goodwill		52.5		52.5
Derivative Asset, Noncurrent		267		242.2
Operating Lease Assets		578.3		866.4
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		4,398.3		3,852.3
TOTAL OTHER NONCURRENT ASSETS		13,858.2		12,504.1
TOTAL ASSETS		87,668.7	[3]	80,757.2
Current Liabilities
Accounts Payable		2,054.6		1,709.7
Short-term Debt:
Securitized Debt for Receivables - AEP Credit	[4]	750		592
Other Short-term Debt		1,864		1,887.3
Total Short-term Debt		2,614		2,479.3
Long-term Debt Due Within One Year		2,153.8		2,086.1
Risk Management Liabilities		75.4		78.8
Customer Deposits		321.6		335.6
Accrued Taxes		1,586.4		1,476.4
Accrued Interest		273.2		267.6
Obligations Under Operating Leases		97.6		241.3
Liabilities Held for Sale		1,880.9		0
Regulatory Liability for Over-Recovered Fuel Costs		1.5	[5]	52.6
Other Current Liabilities		1,369.2		1,251.9
TOTAL CURRENT LIABILITIES		12,426.7		9,926.7
Noncurrent Liabilities
Long-term Debt		31,300.7		28,986.4
Long-term Debt - Affiliated		0		0
Long-term Risk Management Liabilities		230.3		232.8
Deferred Income Taxes		8,202.5		8,240.9
Regulatory Liabilities and Deferred Investment Tax Credits		8,686.3	[5]	8,378.7
Asset Retirement Obligations		2,676.2		2,469.2
Employee Benefits and Pension Obligations		328.4		336.4
Obligations Under Operating Leases		492.8		638.4
Deferred Credits and Other Noncurrent Liabilities		601.3		728
TOTAL NONCURRENT LIABILITIES		52,518.5		50,010.8
TOTAL LIABILITIES		64,945.2		59,937.5
Rate Matters
Commitments and Contingencies
Contingently Redeemable Performance Share Awards		43.3		45.2
Total Mezzanine Equity		43.3		45.2
Equity
Common Stock		3,408.7		3,359.3
Paid-in Capital		7,172.6		6,588.9
Retained Earnings		11,667.1		10,687.8
Accumulated Other Comprehensive Income (Loss)		184.8		(85.1)
TOTAL COMMON SHAREHOLDERS' EQUITY		22,433.2		20,550.9
Noncontrolling Interests		247		223.6
TOTAL EQUITY		22,680.2		20,774.5
TOTAL LIABILITIES AND EQUITY		$ 87,668.7		$ 80,757.2
Common Stock, Par Value Per Share		$ 6.50		$ 6.50
Common Stock, Shares, Issued		524,416,175		516,808,354
Common Stock, Shares Authorized		600,000,000		600,000,000
Treasury Stock, Shares		20,204,160		20,204,160
Subsidiaries [Member]
Current Assets
Restricted Cash		$ 48		$ 45.6
Other Temporary Investments		214.8		194.6
Short-term Debt:
Long-term Debt Due Within One Year		190.5		198.3
Noncurrent Liabilities
Long-term Debt		840.5		950.1
AEP Texas Inc. [Member]
Current Assets
Cash and Cash Equivalents		0.1		0.1
Restricted Cash		30.4		28.7
Advances to Affiliates		6.9		7.1
Accounts Receivable:
Customers		123.4		112.8
Affiliated Companies		7.9		5.1
Accrued Unbilled Revenues		77.9		65.8
Allowance for Uncollectible Accounts		(4)		(0.1)
Total Accounts Receivable		205.2		183.6
Materials and Supplies		73.9		70
Accrued Tax Benefits		24.8		16.8
Prepayments and Other Current Assets		5.9		4.6
TOTAL CURRENT ASSETS		347.2		310.9
Property, Plant and Equipment
Transmission		5,849.9		5,279.6
Distribution		4,917.2		4,580.8
Other Property, Plant and Equipment		961.1		868.4
Construction Work in Progress		551.3		614.1
Total Property, Plant and Equipment		12,279.5		11,342.9
Accumulated Depreciation and Amortization		1,644.1		1,529.3
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		10,635.4		9,813.6
Other Noncurrent Assets
Regulatory Assets		275.2		266.8
Securitized Assets		367.6		446.8
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		211.3		192.1
TOTAL OTHER NONCURRENT ASSETS		854.1		905.7
TOTAL ASSETS		11,836.7		11,030.2
Current Liabilities
Advances from Affiliates		26.9		67.1
Accounts Payable		306.3		231.7
Affiliated Companies		32.5		44
Short-term Debt:
Long-term Debt Due Within One Year		716		88.7
Accrued Taxes		93.3		78.3
Accrued Interest		44.7		43.9
Obligations Under Operating Leases		14		14.5
Other Current Liabilities		78		108.6
TOTAL CURRENT LIABILITIES		1,311.7		676.8
Noncurrent Liabilities
Long-term Debt		4,464.8		4,731.7
Deferred Income Taxes		1,088.9		1,016.7
Regulatory Liabilities and Deferred Investment Tax Credits		1,242		1,270.8
Obligations Under Operating Leases		61.3		71
Deferred Credits and Other Noncurrent Liabilities		73.8		57.2
TOTAL NONCURRENT LIABILITIES		6,930.8		7,147.4
TOTAL LIABILITIES		8,242.5		7,824.2
Rate Matters
Commitments and Contingencies
Equity
Paid-in Capital		1,553.9		1,457.9
Retained Earnings		2,046.8		1,757
Accumulated Other Comprehensive Income (Loss)		(6.5)		(8.9)
TOTAL EQUITY		3,594.2		3,206
TOTAL LIABILITIES AND EQUITY		11,836.7		11,030.2
AEP Texas Inc. [Member] \| AEP Texas Transition and Restoration Funding [Member]
Current Assets
Restricted Cash		30.4		28.7
Other Noncurrent Assets
Securitized Assets		367.6		446.8
Short-term Debt:
Long-term Debt Due Within One Year		91		88.7
Accrued Interest		2.3		2.5
Noncurrent Liabilities
Long-term Debt		313.7		403.9
AEP Transmission Co [Member]
Current Assets
Cash and Cash Equivalents		0		0
Advances to Affiliates		27.2		109.1
Accounts Receivable:
Customers		22.5		22.9
Affiliated Companies		96.1		81.2
Total Accounts Receivable		118.6		104.1
Materials and Supplies		9.3		8.5
Accrued Tax Benefits		5.6		9.9
Assets Held for Sale		167.9		0
Prepayments and Other Current Assets		2.7		4.2
TOTAL CURRENT ASSETS		331.3		235.8
Property, Plant and Equipment
Transmission		10,886.3		9,593.5
Other Property, Plant and Equipment		427.4		329.5
Construction Work in Progress		1,394.8		1,422.6
Total Property, Plant and Equipment		12,708.5		11,345.6
Accumulated Depreciation and Amortization		772.8		572.8
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		11,935.7	[2]	10,772.8
Other Noncurrent Assets
Regulatory Assets		8.5		15.1
Deferred Property Taxes		245.7		220.1
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		3.2		2.2
TOTAL OTHER NONCURRENT ASSETS		257.4		237.4
TOTAL ASSETS		12,524.4	[6]	11,246
Current Liabilities
Advances from Affiliates		124		156.7
Accounts Payable		460.1		380.4
Affiliated Companies		69.9		97.3
Short-term Debt:
Long-term Debt Due Within One Year		104		50
Accrued Taxes		479		418.1
Accrued Interest		28.4		23.9
Obligations Under Operating Leases		0.9		1.2
Liabilities Held for Sale		27.6		0
Other Current Liabilities		3		9.9
TOTAL CURRENT LIABILITIES		1,296.9		1,137.5
Noncurrent Liabilities
Long-term Debt		4,239.9		3,898.5
Deferred Income Taxes		962.9		906.9
Regulatory Liabilities and Deferred Investment Tax Credits		644.1	[7]	581.8
Obligations Under Operating Leases		1.3		0.4
Deferred Credits and Other Noncurrent Liabilities		3.2		8
TOTAL NONCURRENT LIABILITIES		5,851.4		5,395.6
TOTAL LIABILITIES		7,148.3		6,533.1
Rate Matters
Commitments and Contingencies
Equity
Members' Capital		2,949.6		2,765.6
Retained Earnings		2,426.5		1,947.3
TOTAL MEMBER'S EQUITY		5,376.1		4,712.9
TOTAL LIABILITIES AND EQUITY		12,524.4		11,246
Appalachian Power Co [Member]
Current Assets
Cash and Cash Equivalents		2.5		5.8
Restricted Cash		17.6		16.9
Advances to Affiliates		20.8		21.4
Accounts Receivable:
Customers		158.5		142.8
Affiliated Companies		129.9		64.3
Accrued Unbilled Revenues		54		80.1
Miscellaneous		0.2		0.3
Allowance for Uncollectible Accounts		(1.6)		(3.1)
Total Accounts Receivable		341		284.4
Fuel		67.1		193.6
Materials and Supplies		109.8		99.6
Risk Management Assets		42		22.4
Regulatory Asset for Under-Recovered Fuel Costs		201.3		5.3
Margin Deposits		71.8		1.8
Prepayments and Other Current Assets		51.4		22.9
TOTAL CURRENT ASSETS		925.3		674.1
Property, Plant and Equipment
Generation		6,683.9		6,633.7
Transmission		4,322.4		3,900.5
Distribution		4,683.3		4,464.3
Other Property, Plant and Equipment		696.6		627.2
Construction Work in Progress		469.9		484.6
Total Property, Plant and Equipment		16,856.1		16,110.3
Accumulated Depreciation and Amortization		5,051.8		4,716.2
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		11,804.3		11,394.1
Other Noncurrent Assets
Regulatory Assets		757.6		686.3
Securitized Assets		185.1		210.1
Employee Benefits and Pension Assets		220.5		150.1
Operating Lease Assets		66.9		78.8
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		129.2		121.7
TOTAL OTHER NONCURRENT ASSETS		1,359.3		1,247
TOTAL ASSETS		14,088.9		13,315.2
Current Liabilities
Advances from Affiliates		199.3		18.6
Accounts Payable		262.2		212
Affiliated Companies		118.6		97.1
Short-term Debt:
Long-term Debt Due Within One Year		480.7		518.3
Customer Deposits		73.9		77.8
Accrued Taxes		119.7		109.9
Obligations Under Operating Leases		15.1		14.9
Other Current Liabilities		146.4		169.1
TOTAL CURRENT LIABILITIES		1,415.9		1,217.7
Noncurrent Liabilities
Long-term Debt		4,458.2		4,315.8
Deferred Income Taxes		1,804.7		1,749.9
Regulatory Liabilities and Deferred Investment Tax Credits		1,238.8		1,224.7
Asset Retirement Obligations		394.9		304.8
Employee Benefits and Pension Obligations		41.5		44
Obligations Under Operating Leases		52.4		64.4
Deferred Credits and Other Noncurrent Liabilities		34.6		49.6
TOTAL NONCURRENT LIABILITIES		8,025.1		7,753.2
TOTAL LIABILITIES		9,441		8,970.9
Rate Matters
Commitments and Contingencies
Equity
Common Stock		260.4		260.4
Paid-in Capital		1,828.7		1,828.7
Retained Earnings		2,534.4		2,248
Accumulated Other Comprehensive Income (Loss)		24.4		7.2
TOTAL EQUITY		4,647.9		4,344.3
TOTAL LIABILITIES AND EQUITY		$ 14,088.9		$ 13,315.2
Common Stock, No Par Value		$ 0		$ 0
Common Stock, Shares Authorized		30,000,000		30,000,000
Common Stock, Shares Outstanding		13,499,500		13,499,500
Indiana Michigan Power Co [Member]
Current Assets
Cash and Cash Equivalents		$ 1.3		$ 3.3
Advances to Affiliates		21.5		13.3
Accounts Receivable:
Customers		40.6		44
Affiliated Companies		78.2		51.3
Miscellaneous		2.5		2
Allowance for Uncollectible Accounts		(0.1)		(0.3)
Total Accounts Receivable		121.2		97
Fuel		56.8		86
Materials and Supplies		175.2		175.8
Risk Management Assets		3.3		3.6
Accrued Tax Benefits		12.7		10.3
Regulatory Asset for Under-Recovered Fuel Costs		6.4		5.4
Prepayments and Other Current Assets		41		24.1
TOTAL CURRENT ASSETS		439.4		418.8
Property, Plant and Equipment
Generation		5,531.8		5,264.7
Transmission		1,783.1		1,696.4
Distribution		2,800.1		2,594.6
Other Property, Plant and Equipment		792.9		686.7
Construction Work in Progress		302.8		362.4
Total Property, Plant and Equipment		11,210.7		10,604.8
Accumulated Depreciation and Amortization		3,899.8		3,552.5
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		7,310.9		7,052.3
Other Noncurrent Assets
Regulatory Assets		410.9		404.8
Spent Nuclear Fuel and Decommissioning Trusts		3,867		3,306.7
Operating Lease Assets		63.5		218.1
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		316.5		237.6
TOTAL OTHER NONCURRENT ASSETS		4,657.9		4,167.2
TOTAL ASSETS		12,408.2		11,638.3
Current Liabilities
Advances from Affiliates		93.3		103
Accounts Payable		174.4		153.2
Affiliated Companies		94.9		80.5
Short-term Debt:
Long-term Debt Due Within One Year		67		369.6
Risk Management Liabilities		5		0.1
Customer Deposits		45.2		41.7
Accrued Taxes		106.5		102.5
Accrued Interest		37		35.6
Obligations Under Finance Leases		130.5		6.4
Obligations Under Operating Leases		15.5		85.6
Regulatory Liability for Over-Recovered Fuel Costs		1.5		20.8
Other Current Liabilities		123.2		105.5
TOTAL CURRENT LIABILITIES		894		1,104.5
Noncurrent Liabilities
Long-term Debt		3,128		2,660.3
Deferred Income Taxes		1,100.2		1,064.4
Regulatory Liabilities and Deferred Investment Tax Credits		2,447.9		2,041.9
Asset Retirement Obligations		1,946.2		1,812.9
Obligations Under Operating Leases		48.9		135.9
Deferred Credits and Other Noncurrent Liabilities		58.3		69.2
TOTAL NONCURRENT LIABILITIES		8,729.5		7,784.6
TOTAL LIABILITIES		9,623.5		8,889.1
Rate Matters
Commitments and Contingencies
Equity
Common Stock		56.6		56.6
Paid-in Capital		980.9		980.9
Retained Earnings		1,748.5		1,718.7
Accumulated Other Comprehensive Income (Loss)		(1.3)		(7)
TOTAL EQUITY		2,784.7		2,749.2
TOTAL LIABILITIES AND EQUITY		$ 12,408.2		$ 11,638.3
Common Stock, No Par Value		$ 0		$ 0
Common Stock, Shares Authorized		2,500,000		2,500,000
Common Stock, Shares Outstanding		1,400,000		1,400,000
Indiana Michigan Power Co [Member] \| DCC Fuel [Member]
Short-term Debt:
Long-term Debt Due Within One Year		$ 65		$ 75.7
Ohio Power Co [Member]
Current Assets
Cash and Cash Equivalents		3		7.4
Advances to Affiliates		42		0
Accounts Receivable:
Customers		71.6		50
Affiliated Companies		71.8		65.1
Accrued Unbilled Revenues		1.3		14.8
Miscellaneous		5.9		3.9
Allowance for Uncollectible Accounts		(0.6)		(0.6)
Total Accounts Receivable		150		133.2
Materials and Supplies		74.1		66.9
Renewable Energy Credits		30.5		29.5
Prepayments and Other Current Assets		27.9		19.3
TOTAL CURRENT ASSETS		327.5		256.3
Property, Plant and Equipment
Transmission		2,992.8		2,831.9
Distribution		6,070.6		5,708.3
Other Property, Plant and Equipment		992.9		899.6
Construction Work in Progress		365		362.3
Total Property, Plant and Equipment		10,421.3		9,802.1
Accumulated Depreciation and Amortization		2,458.3		2,350
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		7,963		7,452.1
Other Noncurrent Assets
Regulatory Assets		293		385.8
Operating Lease Assets		81.2		92
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		601.1		524.2
TOTAL OTHER NONCURRENT ASSETS		975.3		1,002
TOTAL ASSETS		9,265.8		8,710.4
Current Liabilities
Advances from Affiliates		0		259.2
Accounts Payable		213.5		181
Affiliated Companies		125.4		118.4
Short-term Debt:
Long-term Debt Due Within One Year		0.1		500.1
Risk Management Liabilities		6.7		8.7
Customer Deposits		66.4		55.1
Accrued Taxes		702.4		631
Obligations Under Operating Leases		13.1		13.1
Regulatory Liability for Over-Recovered Fuel Costs		0		3.9
Other Current Liabilities		118.1		139.6
TOTAL CURRENT LIABILITIES		1,245.7		1,906.2
Noncurrent Liabilities
Long-term Debt		2,968.4		1,930.1
Long-term Risk Management Liabilities		85.8		101.6
Deferred Income Taxes		1,000.9		955.1
Regulatory Liabilities and Deferred Investment Tax Credits		1,020.9		1,005.2
Obligations Under Operating Leases		68.6		79.5
Deferred Credits and Other Noncurrent Liabilities		29.2		40
TOTAL NONCURRENT LIABILITIES		5,173.8		4,111.5
TOTAL LIABILITIES		6,419.5		6,017.7
Rate Matters
Commitments and Contingencies
Equity
Common Stock		321.2		321.2
Paid-in Capital		838.8		838.8
Retained Earnings		1,686.3		1,532.7
TOTAL EQUITY		2,846.3		2,692.7
TOTAL LIABILITIES AND EQUITY		$ 9,265.8		$ 8,710.4
Common Stock, No Par Value		$ 0		$ 0
Common Stock, Shares Authorized		40,000,000		40,000,000
Common Stock, Shares Outstanding		27,952,473		27,952,473
Public Service Co Of Oklahoma [Member]
Current Assets
Cash and Cash Equivalents		$ 1.3		$ 2.6
Accounts Receivable:
Customers		41.5		30.8
Affiliated Companies		35		15.6
Miscellaneous		0.6		2
Total Accounts Receivable		77.1		48.4
Fuel		14.5		17.9
Materials and Supplies		56.2		54
Risk Management Assets		12.1		10.3
Accrued Tax Benefits		17.6		10.9
Regulatory Asset for Under-Recovered Fuel Costs		194.6		30.1
Prepayments and Other Current Assets		13.4		7.1
TOTAL CURRENT ASSETS		386.8		181.3
Property, Plant and Equipment
Generation		1,802.4		1,480.7
Transmission		1,107.7		1,069.9
Distribution		3,004.9		2,853
Other Property, Plant and Equipment		437		393.3
Construction Work in Progress		156		128.7
Total Property, Plant and Equipment		6,508		5,925.6
Accumulated Depreciation and Amortization		1,705.2		1,605.6
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		4,802.8		4,320
Other Noncurrent Assets
Regulatory Assets		1,037.4		375
Employee Benefits and Pension Assets		95.2		65.8
Operating Lease Assets		68.9		42.6
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		7.9		6
TOTAL OTHER NONCURRENT ASSETS		1,209.4		489.4
TOTAL ASSETS		6,399		4,990.7
Current Liabilities
Advances from Affiliates		72.3		155.4
Accounts Payable		157.4		107
Affiliated Companies		51		43.4
Short-term Debt:
Long-term Debt Due Within One Year		125.5		0.5
Risk Management Liabilities		3.7		0
Customer Deposits		56.2		54.8
Accrued Taxes		27		26.8
Obligations Under Operating Leases		6.9		6.5
Other Current Liabilities		62.7		84.2
TOTAL CURRENT LIABILITIES		562.7		478.6
Noncurrent Liabilities
Long-term Debt		1,788		1,373.3
Deferred Income Taxes		782.3		688.5
Regulatory Liabilities and Deferred Investment Tax Credits		835.3		802.2
Asset Retirement Obligations		57.5		45.7
Obligations Under Operating Leases		62.2		36.2
Deferred Credits and Other Noncurrent Liabilities		19.4		20.6
TOTAL NONCURRENT LIABILITIES		3,544.7		2,966.5
TOTAL LIABILITIES		4,107.4		3,445.1
Rate Matters
Commitments and Contingencies
Equity
Common Stock		157.2		157.2
Paid-in Capital		1,039		414
Retained Earnings		1,095.4		974.3
Accumulated Other Comprehensive Income (Loss)		0		0.1
TOTAL EQUITY		2,291.6		1,545.6
TOTAL LIABILITIES AND EQUITY		$ 6,399		$ 4,990.7
Common Stock, Par Value Per Share		$ 15		$ 15
Common Stock, Shares, Issued		10,482,000		10,482,000
Common Stock, Shares Authorized		11,000,000		11,000,000
Common Stock, Shares Outstanding		9,013,000		9,013,000
Southwestern Electric Power Co [Member]
Current Assets
Cash and Cash Equivalents		$ 51.2		$ 13.2
Advances to Affiliates		155.9		2.1
Accounts Receivable:
Customers		35.8		27.1
Affiliated Companies		38.3		25.1
Miscellaneous		12.3		12.7
Total Accounts Receivable		86.4		64.9
Fuel		82.2		191.1
Materials and Supplies		81.9		95.8
Risk Management Assets		9.8		3.2
Accrued Tax Benefits		17.8		29.9
Regulatory Asset for Under-Recovered Fuel Costs		143.9		2.6
Prepayments and Other Current Assets		39.4		25.2
TOTAL CURRENT ASSETS		668.5		428
Property, Plant and Equipment
Generation		4,734.5		4,681.4
Transmission		2,316.9		2,165.7
Distribution		2,514.3		2,382.5
Other Property, Plant and Equipment		764		788.8
Construction Work in Progress		240.7		228.3
Total Property, Plant and Equipment		10,570.4		10,246.7
Accumulated Depreciation and Amortization		3,170.3		3,158.5
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		7,400.1		7,088.2
Other Noncurrent Assets
Regulatory Assets		1,005.3		403.1
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		251.8		234.8
TOTAL OTHER NONCURRENT ASSETS		1,257.1		637.9
TOTAL ASSETS		9,325.7		8,154.1
Current Liabilities
Advances from Affiliates		0		124.6
Accounts Payable		163.6		135.9
Affiliated Companies		61.4		43
Short-term Debt:
Other Short-term Debt		0		35
Long-term Debt Due Within One Year		6.2		106.2
Risk Management Liabilities		2.1		0.7
Customer Deposits		62.4		61.3
Accrued Taxes		44.3		41
Accrued Interest		36		34.6
Obligations Under Operating Leases		8.1		7.9
Regulatory Liability for Over-Recovered Fuel Costs		0		37.6
Other Current Liabilities		154.6		173.4
TOTAL CURRENT LIABILITIES		538.7		763.6
Noncurrent Liabilities
Long-term Debt		3,389		2,530.2
Deferred Income Taxes		1,087.6		1,017.6
Regulatory Liabilities and Deferred Investment Tax Credits		806.9		863.4
Asset Retirement Obligations		192.7		193.7
Employee Benefits and Pension Obligations		20.3		18.6
Obligations Under Operating Leases		77.7		44.1
Deferred Credits and Other Noncurrent Liabilities		63		95.2
TOTAL NONCURRENT LIABILITIES		5,637.2		4,762.8
TOTAL LIABILITIES		6,175.9		5,526.4
Rate Matters
Commitments and Contingencies
Equity
Common Stock		0.1		0.1
Paid-in Capital		1,092.2		812.2
Retained Earnings		2,050.9		1,811.9
Accumulated Other Comprehensive Income (Loss)		6.7		1.9
TOTAL COMMON SHAREHOLDERS' EQUITY		3,149.9		2,626.1
Noncontrolling Interests		(0.1)		1.6
TOTAL EQUITY		3,149.8		2,627.7
TOTAL LIABILITIES AND EQUITY		$ 9,325.7		$ 8,154.1
Common Stock, Par Value Per Share		$ 18		$ 18
Common Stock, Shares Authorized		3,680		3,680
Common Stock, Shares Outstanding		3,680		3,680
Southwestern Electric Power Co [Member] \| Sabine Mining Co [Member]
Current Assets
Cash and Cash Equivalents		$ 49.9		$ 10.1
Accounts Receivable:
Fuel		13.1		35.2
Materials and Supplies		12		23.3
Property, Plant and Equipment
Other Property, Plant and Equipment		219.9		223.7
Accumulated Depreciation and Amortization		$ 168.1		$ 126.5

[1]	2021 amounts exclude $485 million of regulatory assets classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[2]	Amount excludes $2.3 billion and $165 million for AEP and AEPTCo, respectively, of Property, Plant and Equipment - Net classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[3]	Amount includes Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[4]	Amount of securitized debt for receivables as accounted for under the “Transfers and Servicing” accounting guidance.
[5]	2021 amounts exclude $148 million of regulatory liabilities classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[6]	Amount includes Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[7]	2021 amounts exclude $8 million of regulatory liabilities classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating Activites
Net Income (Loss)	$ 2,488.1	$ 2,196.7	$ 1,919.8
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	2,825.7	2,682.8	2,514.5
Rockport Plant, Unit 2 Lease Amortization	135.4	136.5	136.5
Deferred Income Taxes	107.6	196.1	(17.8)
Asset Impairments and Other Related Charges	11.6	0	156.4
Allowance for Equity Funds Used During Construction	(139.7)	(148.1)	(168.4)
Mark-to-Market of Risk Management Contracts	112.3	66.5	(29.2)
Amortization of Nuclear Fuel	85.3	87.5	89.1
Pension and Postemployment Benefit Reserves	6.1	(8.5)	(24.6)
Pension Contributions to Qualified Plan Trust	0	(110.3)	0
Property Taxes	(68)	(43.3)	(73.8)
Deferred Fuel Over/Under-Recovery, Net	(1,647.9)	(31.8)	85.2
Change in Regulatory Assets	(238.9)	(337.9)	49.5
Change in Other Noncurrent Assets	(132.7)	(142.5)	(112.8)
Change in Other Noncurrent Liabilities	206.4	(54.5)	(116.1)
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(119.7)	(129.3)	247.8
Fuel, Materials and Supplies	300.2	(142.9)	(248.2)
Increase (Decrease) in Margin Deposits Outstanding	(70)	2.8	8.1
Accounts Payable	200.6	(35.3)	5.8
Accrued Taxes, Net	218.7	20.1	138.9
Rockport Plant, Unit 2 Operating Lease Payments	(147.7)	(147.7)	(147.7)
Other Current Assets	(151.3)	34.3	70.7
Other Current Liabilities	(212.2)	(255.5)	(205.5)
Net Cash Flows from Operating Activities	3,839.9	3,832.9	4,270.1
Investing Activities
Construction Expenditures	(5,659.6)	(6,246.3)	(6,051.4)
Purchases of Investment Securities	(1,955.1)	(1,678.8)	(1,576)
Sales of Investment Securities	1,901.4	1,644.3	1,494.2
Acquisitions of Nuclear Fuel	(104.5)	(69.7)	(92.3)
Other Investing Activities	151.1	116.6	(0.6)
Net Cash Flows Used for Investing Activities	(6,433.9)	(6,233.9)	(7,144.5)
Financing Activities
Issuance of Common Stock, Net	600.5	155	65.3
Issuance of Long-term Debt	6,486.3	5,626.1	4,536.6
Issuance of Short-term Debt with Original Maturities Greater Than 90 Days	1,393.3	1,396.5	0
Change in Short-term Debt with Original Maturities Less Than 90 Days, Net	(487.3)	(448.4)	928.3
Retirement of Long-term Debt	(2,989.3)	(1,339.8)	(1,220.8)
Redemption of Short-term Debt with Original Maturities Greater Than 90 Days	(771.3)	(1,307.1)	0
Principal Payments for Finance Lease Obligations	(64)	(61.7)	(70.7)
Dividends Paid on Common Stock	(1,519.5)	(1,424.9)	(1,350)
Redemption of Noncontrolling Interest	0	(100.2)	0
Other Financing Activities	(41.6)	(88.8)	(25.8)
Net Cash Flows from Financing Activities	2,607.1	2,406.7	2,862.9
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	13.1	5.7	(11.5)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	438.3	432.6	444.1
Cash and Cash Equivalents at Beginning of Period	392.7
Cash, Cash Equivalents and Restricted Cash at End of Period	451.4	438.3	432.6
Cash and Cash Equivalents at End of Period	403.4	392.7
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	1,137.2	1,029.1	1,022.5
Net Cash Paid (Received) for Income Taxes	13.2	(49.1)	6.1
Construction Expenditures Included in Current Liabilities as of December 31,	1,180.4	975.4	1,341.1
Acquisition of Nuclear Fuel Included in Current Liabilities as of December 31,	0	33.4	0.1
Expected Reimbursement For Spent Nuclear Fuel Dry Cask Storage	1.7	2.6	0.3
North Central Wind Energy Facilities
Investing Activities
Acquisition of Assets	652.8	0	0
Dry Lake Solar Project [Member]
Investing Activities
Acquisition of Assets	114.4	0	0
Sempra Renewable LLC and Santa Rita
Investing Activities
Acquisition of Assets	0	0	(918.4)
AEP Texas Inc. [Member]
Operating Activites
Net Income (Loss)	289.8	241	178.3
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	387	529.8	622.3
Deferred Income Taxes	43	(15.2)	(23.5)
Asset Impairments and Other Related Charges	0	0	32.5
Allowance for Equity Funds Used During Construction	(21.5)	(19.4)	(15.2)
Mark-to-Market of Risk Management Contracts	0	0	(0.2)
Pension Contributions to Qualified Plan Trust	0	(11.3)	0
Change in Other Noncurrent Assets	(78.2)	(74)	9.3
Change in Other Noncurrent Liabilities	26.4	(24.7)	11.3
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(21.6)	9.8	3.5
Fuel, Materials and Supplies	(3.9)	(7.4)	(1)
Accounts Payable	8.9	30.2	7.5
Accrued Taxes, Net	7	42.7	(11.8)
Other Current Assets	(0.9)	0.8	(0.4)
Other Current Liabilities	(39.4)	(88.1)	10.8
Net Cash Flows from Operating Activities	596.6	614.2	823.4
Investing Activities
Construction Expenditures	(1,033.3)	(1,295)	(1,275.1)
Change in Advances to Affiliates, Net	0.2	200.1	(199.2)
Other Investing Activities	32.3	29.5	2.1
Net Cash Flows Used for Investing Activities	(1,000.8)	(1,065.4)	(1,472.2)
Financing Activities
Capital Contributions from Member	96	0	200
Issuance of Long-term Debt	444.2	652.7	1,070.4
Change in Advances from Affiliates, Net	(40.2)	67.1	(216)
Retirement of Long-term Debt	(88.7)	(392.1)	(401.8)
Principal Payments for Finance Lease Obligations	(6.7)	(6.3)	(5.1)
Other Financing Activities	1.3	0.8	(0.7)
Net Cash Flows from Financing Activities	405.9	322.2	646.8
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	1.7	(129)	(2)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	28.8	157.8	159.8
Cash and Cash Equivalents at Beginning of Period	0.1
Cash, Cash Equivalents and Restricted Cash at End of Period	30.5	28.8	157.8
Cash and Cash Equivalents at End of Period	0.1	0.1
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	168.9	153.2	148.6
Net Cash Paid (Received) for Income Taxes	5.7	(42.9)	(11)
Noncash Acquisitions Under Finance Leases	4.4	5.6	11.4
Construction Expenditures Included in Current Liabilities as of December 31,	230	177.8	225.5
AEP Transmission Co [Member]
Operating Activites
Net Income (Loss)	591.7	423.4	439.7
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	297.3	249	176
Deferred Income Taxes	68.5	81.6	91.3
Allowance for Equity Funds Used During Construction	(67.2)	(74)	(84.3)
Property Taxes	(25.6)	(26.6)	(35.6)
Change in Other Noncurrent Assets	7.5	(8.2)	9.6
Change in Other Noncurrent Liabilities	3.7	8.3	(8.1)
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(16)	(19)	(5.4)
Fuel, Materials and Supplies	(0.8)	5.3	5.2
Accounts Payable	(2.2)	77.8	37.6
Accrued Taxes, Net	67.2	62.7	90.8
Accrued Interest	4.8	4.7	3.3
Other Current Assets	1.2	0.7	(0.3)
Other Current Liabilities	(4.4)	(14.5)	(11.2)
Net Cash Flows from Operating Activities	925.7	771.2	708.6
Investing Activities
Construction Expenditures	(1,424.8)	(1,615.9)	(1,410.1)
Change in Advances to Affiliates, Net	81.9	(23.7)	11.5
Acquisition of Assets	(17.9)	(6)	(9.4)
Other Investing Activities	1.8	5.2	4.8
Net Cash Flows Used for Investing Activities	(1,359)	(1,640.4)	(1,403.2)
Financing Activities
Capital Contributions from Member	184	335	0
Issuance of Long-term Debt	443.7	519.5	688
Change in Advances from Affiliates, Net	(31.9)	19.7	91.6
Retirement of Long-term Debt	(50)	0	(85)
Principal Payments for Finance Lease Obligations	0	0
Dividends Paid on Common Stock	(112.5)	(5)	0
Net Cash Flows from Financing Activities	433.3	869.2	694.6
Net Increase (Decrease) in Cash and Cash Equivalents	0	0	0
Cash and Cash Equivalents at Beginning of Period	0	0	0
Cash and Cash Equivalents at End of Period	0	0	0
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	132.9	119.7	90.6
Net Cash Paid (Received) for Income Taxes	65.7	22.9	1.5
Construction Expenditures Included in Current Liabilities as of December 31,	358.7	311.9	472.7
Noncash Distribution of Radial Assets to Member	0	(50)	0
Appalachian Power Co [Member]
Operating Activites
Net Income (Loss)	348.9	369.7	306.3
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	546.2	507.5	466.8
Deferred Income Taxes	15	(26.2)	(126.2)
Asset Impairments and Other Related Charges	0	0	92.9
Allowance for Equity Funds Used During Construction	(15.6)	(14.6)	(16.6)
Mark-to-Market of Risk Management Contracts	(22.3)	18.8	19.9
Pension Contributions to Qualified Plan Trust	0	(7)	0
Deferred Fuel Over/Under-Recovery, Net	(196)	37.2	57.1
Re-Establishment of Regulatory Asset - Coal Fired Generation	0	(49)	0
Change in Other Noncurrent Assets	(68.8)	(40.4)	(38.2)
Change in Other Noncurrent Liabilities	35.6	11.2	(40.3)
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(53.3)	(30.2)	35.7
Fuel, Materials and Supplies	116.1	(38.2)	(93.4)
Accounts Payable	36.8	(48.1)	37.7
Accrued Taxes, Net	(16.2)	31.3	(10.2)
Other Current Assets	(2.4)	15.5	7.3
Other Current Liabilities	(42.3)	(28.3)	(45.5)
Net Cash Flows from Operating Activities	611.7	712	661.4
Investing Activities
Construction Expenditures	(841.6)	(767.4)	(862.6)
Change in Advances to Affiliates, Net	0.6	0.7	0.9
Other Investing Activities	14.5	8.8	24.3
Net Cash Flows Used for Investing Activities	(826.5)	(757.9)	(837.4)
Financing Activities
Issuance of Long-term Debt	494	606.9	478.2
Change in Advances from Affiliates, Net	180.7	(218.1)	31.1
Retirement of Long-term Debt	(393)	(140.3)	(180.5)
Principal Payments for Finance Lease Obligations	(7.7)	(7.4)	(6.7)
Dividends Paid on Common Stock	(62.5)	(200)	(150)
Other Financing Activities	0.7	0.7	0.9
Net Cash Flows from Financing Activities	212.2	41.8	173
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(2.6)	(4.1)	(3)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	22.7	26.8	29.8
Cash and Cash Equivalents at Beginning of Period	5.8
Cash, Cash Equivalents and Restricted Cash at End of Period	20.1	22.7	26.8
Cash and Cash Equivalents at End of Period	2.5	5.8
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	207.5	207.1	190.7
Net Cash Paid (Received) for Income Taxes	32.8	0	63
Noncash Acquisitions Under Finance Leases	1.7	7.2	8.8
Construction Expenditures Included in Current Liabilities as of December 31,	139.1	105.6	149.7
Indiana Michigan Power Co [Member]
Operating Activites
Net Income (Loss)	279.8	284.8	269.4
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	446	411.6	350.6
Rockport Plant, Unit 2 Operating Lease Amortization	62.4	69.2	69.2
Deferred Income Taxes	(38)	(16.2)	(52.7)
Amortization (Deferral) of Incremental Nuclear Refueling Outage Expenses, Net	7.5	24.4	(26.4)
Allowance for Equity Funds Used During Construction	(12.8)	(11.5)	(19.4)
Mark-to-Market of Risk Management Contracts	5.2	5.9	(0.6)
Amortization of Nuclear Fuel	85.3	87.5	89.1
Pension Contributions to Qualified Plan Trust	0	(6.4)	0
Deferred Fuel Over/Under-Recovery, Net	(20.2)	12.4	(24.3)
Change in Other Noncurrent Assets	(54.1)	6.1	8.3
Change in Other Noncurrent Liabilities	7.5	45	33.7
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(22.3)	14.5	35.4
Fuel, Materials and Supplies	30.1	(34.7)	(22.4)
Accounts Payable	42.3	(10.8)	3.6
Accrued Taxes, Net	1.6	(20.2)	48.3
Rockport Plant, Unit 2 Operating Lease Payments	(73.9)	(73.9)	(73.9)
Other Current Assets	(15.2)	14.3	11.2
Other Current Liabilities	2.5	(25.7)	(13.9)
Net Cash Flows from Operating Activities	733.7	776.3	685.2
Investing Activities
Construction Expenditures	(500.9)	(544.7)	(585.9)
Change in Advances to Affiliates, Net	(8.2)	(0.1)	(0.5)
Purchases of Investment Securities	(1,928.2)	(1,637.2)	(1,531)
Sales of Investment Securities	1,886.4	1,593.4	1,473
Acquisitions of Nuclear Fuel	(104.5)	(69.7)	(92.3)
Other Investing Activities	22.3	9.4	16.6
Net Cash Flows Used for Investing Activities	(633.1)	(648.9)	(720.1)
Financing Activities
Issuance of Long-term Debt	546.7	69.5	123.3
Change in Advances from Affiliates, Net	(9.7)	(11.4)	113.3
Retirement of Long-term Debt	(383.5)	(93.2)	(117.1)
Principal Payments for Finance Lease Obligations	(6.8)	(6.5)	(5.7)
Dividends Paid on Common Stock	(250)	(85)	(80)
Other Financing Activities	0.7	0.5	0.7
Net Cash Flows from Financing Activities	(102.6)	(126.1)	34.5
Net Increase (Decrease) in Cash and Cash Equivalents	(2)	1.3	(0.4)
Cash and Cash Equivalents at Beginning of Period	3.3	2	2.4
Cash and Cash Equivalents at End of Period	1.3	3.3	2
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	110.9	107.6	111.9
Net Cash Paid (Received) for Income Taxes	29.3	42.1	3.4
Noncash Acquisitions Under Finance Leases	132.3	3	11.9
Construction Expenditures Included in Current Liabilities as of December 31,	87.8	62.8	86
Acquisition of Nuclear Fuel Included in Current Liabilities as of December 31,	0	33.4	0.1
Expected Reimbursement For Spent Nuclear Fuel Dry Cask Storage	1.7	2.6	0.3
Ohio Power Co [Member]
Operating Activites
Net Income (Loss)	253.6	271.4	297.1
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	303.3	276.6	240.9
Amortization of Generation Deferrals	0	0	65.3
Deferred Income Taxes	30.7	77.2	43.8
Carrying Costs Income	(1.2)	(1.6)	(1)
Allowance for Equity Funds Used During Construction	(10.8)	(12.5)	(18.2)
Mark-to-Market of Risk Management Contracts	(17.8)	6.7	4
Property Taxes	(35.3)	(16.6)	(33.7)
Refund of Global Settlement	0	0	(16.5)
Reversal of a Regulatory Provision	0	0	(56.2)
Change in Regulatory Assets	38.3	(69.4)	(20.1)
Change in Other Noncurrent Assets	(40.7)	(49.4)	(35.3)
Change in Other Noncurrent Liabilities	6.9	(66.4)	(93.2)
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(11.8)	4.2	75
Fuel, Materials and Supplies	(2.5)	(23.9)	(16.4)
Accounts Payable	19.1	10.3	0.4
Accrued Taxes, Net	78.2	43.3	38.7
Other Current Assets	(15.7)	1.9	0.8
Other Current Liabilities	(19.9)	(42.5)	(55.2)
Net Cash Flows from Operating Activities	575.6	410.9	421.2
Investing Activities
Construction Expenditures	(732.8)	(813.2)	(799.2)
Change in Advances to Affiliates, Net	(42)	0	0
Other Investing Activities	21.5	22.2	55.1
Net Cash Flows Used for Investing Activities	(753.3)	(791)	(744.1)
Financing Activities
Issuance of Long-term Debt	1,037.1	347	444.3
Change in Advances from Affiliates, Net	(259.2)	128.2	16.9
Retirement of Long-term Debt	(500.1)	(0.1)	(80.3)
Principal Payments for Finance Lease Obligations	(4.9)	(4.7)	(3.5)
Dividends Paid on Common Stock	(100)	(87.5)	(85)
Other Financing Activities	0.4	0.9	1.7
Net Cash Flows from Financing Activities	173.3	383.8	294.1
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(4.4)	3.7	(28.8)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	7.4	3.7	32.5
Cash and Cash Equivalents at Beginning of Period	7.4
Cash, Cash Equivalents and Restricted Cash at End of Period	3	7.4	3.7
Cash and Cash Equivalents at End of Period	3	7.4
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	119.5	111.2	100.6
Net Cash Paid (Received) for Income Taxes	(7.9)	(26.9)	7.3
Noncash Acquisitions Under Finance Leases	2.5	6.1	11.3
Construction Expenditures Included in Current Liabilities as of December 31,	97.1	76.7	125.9
Public Service Co Of Oklahoma [Member]
Operating Activites
Net Income (Loss)	141.1	123	137.6
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	196.6	173.5	169.5
Deferred Income Taxes	113.9	17	(18.2)
Allowance for Equity Funds Used During Construction	(2.4)	(4)	(2.7)
Mark-to-Market of Risk Management Contracts	1.9	5.5	(6.4)
Deferred Fuel Over/Under-Recovery, Net	(843.8)	(94)	43.8
Change in Other Noncurrent Assets	(18.3)	(17.9)	5.7
Change in Other Noncurrent Liabilities	4.4	1.6	(7.3)
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(28.7)	1.4	15.4
Fuel, Materials and Supplies	1.4	(14.1)	(1.9)
Accounts Payable	34.2	(29.5)	7
Accrued Taxes, Net	(6.5)	3.6	3.9
Other Current Assets	(6.3)	4.6	(0.7)
Other Current Liabilities	(20.8)	(13.7)	4.6
Net Cash Flows from Operating Activities	(433.3)	157	350.3
Investing Activities
Construction Expenditures	(332.1)	(337.9)	(291.9)
Change in Advances to Affiliates, Net	0	38.8	(38.8)
Acquisition of Assets	297	0	0
Other Investing Activities	2.4	4	2.6
Net Cash Flows Used for Investing Activities	(626.7)	(295.1)	(328.1)
Financing Activities
Capital Contributions from Member	625	0	0
Issuance of Long-term Debt	1,290	0	349.5
Change in Advances from Affiliates, Net	(83.1)	155.4	(105.5)
Retirement of Long-term Debt	(750.5)	(13.2)	(250.5)
Principal Payments for Finance Lease Obligations	(3.2)	(3.5)	(3.1)
Dividends Paid on Common Stock	(20)	0	(11.3)
Other Financing Activities	0.5	0.5	(1.8)
Net Cash Flows from Financing Activities	1,058.7	139.2	(22.7)
Net Increase (Decrease) in Cash and Cash Equivalents	(1.3)	1.1	(0.5)
Cash and Cash Equivalents at Beginning of Period	2.6	1.5	2
Cash and Cash Equivalents at End of Period	1.3	2.6	1.5
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	57	59.1	61.1
Net Cash Paid (Received) for Income Taxes	(102.9)	(11.8)	22.4
Noncash Acquisitions Under Finance Leases	3.6	3.2	5.3
Construction Expenditures Included in Current Liabilities as of December 31,	56.8	35.5	46
Noncash Contribution of Radial Assets from Parent	0	50	0
Southwestern Electric Power Co [Member]
Operating Activites
Net Income (Loss)	242.1	183.7	162.2
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	295	272.7	249.1
Deferred Income Taxes	16.6	32.4	(11)
Asset Impairments and Other Related Charges	11.6	0	0
Allowance for Equity Funds Used During Construction	(7)	(7.7)	(6.8)
Mark-to-Market of Risk Management Contracts	(7.3)	(0.1)	0.8
Pension Contributions to Qualified Plan Trust	0	(8.9)	0
Deferred Fuel Over/Under-Recovery, Net	(546.4)	26.3	16.5
Change in Regulatory Assets	(95.6)	(108.4)	3.5
Change in Other Noncurrent Assets	41.9	16.1	2.7
Change in Other Noncurrent Liabilities	(1.1)	25.2	2.7
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(21.5)	7.3	0
Fuel, Materials and Supplies	126.5	(46.4)	(46.1)
Accounts Payable	22	11.1	(28.4)
Accrued Taxes, Net	15.4	(23.1)	(3.2)
Other Current Assets	(3.6)	(2.8)	(8.9)
Other Current Liabilities	8.2	(21.1)	6.7
Net Cash Flows from Operating Activities	96.8	356.3	339.8
Investing Activities
Construction Expenditures	(414.6)	(402.7)	(412.7)
Change in Advances to Affiliates, Net	(153.8)	0	81.3
Acquisition of Assets	355.8	0	0
Other Investing Activities	3.5	10.1	1.2
Net Cash Flows Used for Investing Activities	(920.7)	(392.6)	(330.2)
Financing Activities
Capital Contributions from Member	280	0	0
Issuance of Long-term Debt	1,137.6	0	0
Change in Short-term Debt with Original Maturities Less Than 90 Days, Net	(35)	16.7	18.3
Change in Advances from Affiliates, Net	(124.6)	64.7	59.9
Retirement of Long-term Debt	(381.2)	(21.2)	(59.7)
Principal Payments for Finance Lease Obligations	(10.9)	(10.9)	(11)
Dividends Paid on Common Stock	0	0	(37.5)
Dividends Paid on Common Stock	(4.8)	(1.9)	(3.3)
Other Financing Activities	0.8	0.5	0.8
Net Cash Flows from Financing Activities	861.9	47.9	(32.5)
Net Increase (Decrease) in Cash and Cash Equivalents	38	11.6	(22.9)
Cash and Cash Equivalents at Beginning of Period	13.2	1.6	24.5
Cash and Cash Equivalents at End of Period	51.2	13.2	1.6
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	116.5	110.7	111.1
Net Cash Paid (Received) for Income Taxes	(28.8)	4.3	8.6
Noncash Acquisitions Under Finance Leases	4.8	8.9	7.4
Construction Expenditures Included in Current Liabilities as of December 31,	$ 69	$ 46	$ 69.1

Organization and Summary of Sig

Organization and Summary of Significant Accounting Policies	12 Months Ended
Organization and Summary of Significant Accounting Policies	Dec. 31, 2021
Organization and Summary of Significant Accounting Policies	ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES The disclosures in this note apply to all Registrants unless indicated otherwise. ORGANIZATION The Registrants engage in the generation, transmission and distribution of electric power. The Registrant Subsidiaries that conduct most of these activities are regulated by the FERC under the Federal Power Act and the Energy Policy Act of 2005 and maintain accounts in accordance with the FERC and other regulatory guidelines. Most of these companies are subject to further regulation with regard to rates and other matters by state regulatory commissions. AEP provides competitive electric and gas supply for residential, commercial and industrial customers in deregulated electricity markets and also provides energy management solutions throughout the United States, including energy efficiency services through its independent retail electric supplier. The Registrants also engage in wholesale electricity, natural gas and other commodity marketing and risk management activities in the United States and provide various energy-related services. In addition, AEP operates competitive wind and solar farms. I&M provides barging services to both affiliated and nonaffiliated companies. SWEPCo, through Sabine, conducts lignite mining operations to fuel the Pirkey Plant. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Rates and Service Regulation AEP’s public utility subsidiaries’ rates are regulated by the FERC and state regulatory commissions in the eleven state operating territories in which they operate. The FERC also regulates the Registrants’ affiliated transactions, including AEPSC intercompany service billings which are generally at cost, under the 2005 Public Utility Holding Company Act and the Federal Power Act. The FERC also has jurisdiction over certain issuances and acquisitions of securities of the public utility subsidiaries, the acquisition or sale of certain utility assets and mergers with another electric utility or holding company. The state regulatory commissions also regulate certain intercompany transactions under various orders and affiliate statutes. Both the FERC and state regulatory commissions are permitted to review and audit the relevant books and records of companies within a public utility holding company system. The FERC regulates wholesale power markets and wholesale power transactions. The Registrants’ wholesale power transactions are generally market-based. Wholesale power transactions are cost-based regulated when a cost-based contract is negotiated and filed with the FERC or the FERC determines that the Registrants have “market power” in the region where the transaction occurs. Wholesale power supply contracts have been entered into with various municipalities and cooperatives that are FERC-regulated, cost-based contracts. These contracts are generally formula rate mechanisms, which are trued-up to actual costs annually. The state regulatory commissions regulate all of the retail distribution operations and rates of the Registrants’ retail public utility subsidiaries on a cost basis. The state regulatory commissions also regulate the retail generation/power supply operations and rates except in Ohio and the ERCOT region of Texas. For generation in Ohio, customers who have not switched to a CRES provider for generation pay market-based auction rates. In addition, all OPCo distribution customers continue to pay for certain legacy deferred generation-related costs through PUCO approved riders. In the ERCOT region of Texas, the generation/supply business is under customer choice and market pricing is conducted by REPs. AEP has one active REP in ERCOT. AEP’s nonregulated subsidiaries enter into short and long-term wholesale transactions to buy or sell capacity, energy and ancillary services in the ERCOT market. In addition, these nonregulated subsidiaries control certain wind assets, the power from which is marketed and sold in ERCOT. Power from the Oklaunion Power Station was also marketed and sold by these nonregulated subsidiaries in ERCOT prior to its retirement in 2020. The FERC also regulates the Registrants’ wholesale transmission operations and rates. Retail transmission rates are based upon the FERC OATT rate when retail rates are unbundled in connection with restructuring. Retail transmission rates are based on formula rates included in the PJM OATT that are cost-based and are unbundled in Ohio for OPCo, in Virginia for APCo and in Michigan for I&M. AEP Texas’ retail transmission rates in Texas are unbundled but the retail transmission rates are regulated, on a cost basis, by the PUCT. Bundled retail transmission rates are regulated, on a cost basis, by the state commissions. Transmission rates for AEPTCo’s seven wholly-owned transmission subsidiaries within the AEP Transmission Holdco segment are based on formula rates included in the applicable RTO’s OATT that are cost-based. In West Virginia, APCo and WPCo provide retail electric service at bundled rates approved by the WVPSC, with rates set on a combined cost-of-service basis. In addition, the FERC regulates the SIA, Operating Agreement, TA and TCA, all of which allocate shared system costs and revenues among the utility subsidiaries that are parties to each agreement. The FERC also regulates the PCA. See Note 16 - Related Party Transactions for additional information. Principles of Consolidation AEP’s consolidated financial statements include its wholly-owned and majority-owned subsidiaries and VIEs of which AEP is the primary beneficiary. The consolidated financial statements for AEP Texas include the Registrant Subsidiary, its wholly-owned subsidiaries, Transition Funding (consolidated VIEs) and Restoration Funding (a consolidated VIE). The consolidated financial statements for APCo include the Registrant Subsidiary, its wholly-owned subsidiaries and Appalachian Consumer Rate Relief Funding (a consolidated VIE). The consolidated financial statements for I&M include the Registrant Subsidiary, its wholly-owned subsidiaries and DCC Fuel (consolidated VIEs). The consolidated statements of cash flows for OPCo include the Registrant Subsidiary and Ohio Phase-in Recovery Funding (a consolidated VIE) for the year ended December 31, 2019. In July 2019, the Ohio Phase-in Recovery Funding securitization bonds matured. The consolidated financial statements for SWEPCo include the Registrant Subsidiary, its wholly-owned subsidiary and Sabine (a consolidated VIE). Intercompany items are eliminated in consolidation. The equity method of accounting is used for equity investments where the Registrants exercise significant influence but do not hold a controlling financial interest. Such investments are initially recorded at cost in Deferred Charges and Other Noncurrent Assets on the balance sheets. The proportionate share of the investee’s equity earnings or losses is included in Equity Earnings of Unconsolidated Subsidiaries on the statements of income. AEP, I&M, PSO and SWEPCo have ownership interests in generating units that are jointly-owned. The proportionate share of the operating costs associated with such facilities is included on the income statements and the assets and liabilities are reflected on the balance sheets. See Note 17 - Variable Interest Entities and Equity Method Investments and Note 18 - Property, Plant and Equipment for additional information. In October 2020, AEP Texas, PSO and a nonaffiliated joint-owner executed an Environmental Liability and Property Transfer and Asset Purchase Agreement with a nonaffiliated third-party related to the Oklaunion Power Station site. See Note 7 – Acquisitions, Dispositions and Impairments for additional information. Accounting for the Effects of Cost-Based Regulation The Registrants’ financial statements reflect the actions of regulators that result in the recognition of certain revenues and expenses in different time periods than enterprises that are not rate-regulated. In accordance with accounting guidance for “Regulated Operations,” regulatory assets (deferred expenses) and regulatory liabilities (deferred revenue reductions or refunds) are recorded to reflect the economic effects of regulation in the same accounting period by matching expenses with their recovery through regulated revenues and by matching income with its passage to customers in cost-based regulated rates. Use of Estimates The preparation of these financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. These estimates include, but are not limited to, inventory valuation, allowance for doubtful accounts, goodwill, intangible and long-lived asset impairment, unbilled electricity revenue, valuation of long-term energy contracts, the effects of regulation, long-lived asset recovery, storm costs, the effects of contingencies and certain assumptions made in accounting for pension and postretirement benefits. The estimates and assumptions used are based upon management’s evaluation of the relevant facts and circumstances as of the date of the financial statements. Actual results could ultimately differ from those estimates. Cash and Cash Equivalents Cash and Cash Equivalents include temporary cash investments with original maturities of three months or less. Restricted Cash (Applies to AEP, AEP Texas and APCo) Restricted Cash primarily includes funds held by trustees for the payment of securitization bonds. Reconciliation of Cash, Cash Equivalents and Restricted Cash The following tables provide a reconciliation of Cash, Cash Equivalents and Restricted Cash reported within the balance sheets that sum to the total of the same amounts shown on the statement of cash flows: December 31, 2021 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 403.4 $ 0.1 $ 2.5 Restricted Cash 48.0 30.4 17.6 Total Cash, Cash Equivalents and Restricted Cash $ 451.4 $ 30.5 $ 20.1 December 31, 2020 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 392.7 $ 0.1 $ 5.8 Restricted Cash 45.6 28.7 16.9 Total Cash, Cash Equivalents and Restricted Cash $ 438.3 $ 28.8 $ 22.7 Other Temporary Investments (Applies to AEP) Other Temporary Investments primarily include marketable securities and investments by its protected cell of EIS. These securities have readily determinable fair values and are carried at fair value with changes in fair value recognized in net income. The cost of securities sold is based on the specific identification or weighted-average cost method. See “Fair Value Measurements of Other Temporary Investments” section of Note 11 for additional information. Inventory Fossil fuel inventories are carried at average cost with the exception of AGR, which carries these inventories at the lower of average cost or net realizable value. Materials and supplies inventories are carried at average cost. Accounts Receivable Customer accounts receivable primarily include receivables from wholesale and retail energy customers, receivables from energy contract counterparties related to risk management activities and customer receivables primarily related to other revenue-generating activities. Revenue is recognized over time as the performance obligations of delivering energy to customers are satisfied. To the extent that deliveries have occurred but a bill has not been issued, the Registrants accrue and recognize, as Accrued Unbilled Revenues on the balance sheets, an estimate of the revenues for energy delivered since the last billing. AEP Credit factors accounts receivable on a daily basis, excluding receivables from risk management activities, through purchase agreements with I&M, KGPCo, KPCo, OPCo, PSO, SWEPCo and a portion of APCo. Since APCo does not have regulatory authority to sell accounts receivable in its West Virginia regulatory jurisdiction, only a portion of APCo’s accounts receivable are sold to AEP Credit. AEP Credit has a receivables securitization agreement with bank conduits. Under the securitization agreement, AEP Credit receives financing from bank conduits for the interest in the billed and unbilled receivables they acquire from affiliated utility subsidiaries. See “Securitized Accounts Receivable – AEP Credit” section of Note 14 for additional information. Allowance for Uncollectible Accounts Generally, AEP Credit records bad debt expense based upon a 12-month rolling average of bad debt write-offs in proportion to gross accounts receivable purchased from participating AEP subsidiaries. The assessment is performed separately by each participating AEP subsidiary, which inherently contemplates any differences in geographical risk characteristics for the allowance. For receivables related to APCo’s West Virginia operations, the bad debt reserve is calculated based on a rolling two-year average write-off in proportion to gross accounts receivable. KPCo terminated selling accounts receivable to AEP Credit in the first quarter of 2022, based on the pending sale to Liberty. As a result of the termination, in the first quarter of 2022, KPCo will record an allowance for uncollectible accounts on its balance sheet for those receivables no longer sold to AEP Credit. For customer accounts receivables relating to risk management activities, accounts receivables are reviewed for bad debt reserves at a specific counterparty level basis. For AEP Texas, bad debt reserves are calculated using the specific identification of receivable balances greater than 120 days delinquent, and for those balances less than 120 days where the collection is doubtful. For miscellaneous accounts receivable, bad debt expense is recorded based upon a 12-month rolling average of bad debt write-offs in proportion to gross accounts receivable, unless specifically identified. In addition to these processes, management contemplates available current information, as well as any reasonable and supportable forecast information, to determine if allowances for uncollectible accounts should be further adjusted in accordance with the accounting guidance for “Credit Losses.” Management’s assessments contemplate expected losses over the life of the accounts receivable. Concentrations of Credit Risk and Significant Customers (Applies to Registrant Subsidiaries) APCo, I&M, OPCo, PSO and SWEPCo do not have any significant customers that comprise 10% or more of their operating revenues. AEP Texas had significant transactions with REPs which on a combined basis account for the following percentages of Total Revenues for the years ended December 31 and Accounts Receivable – Customers as of December 31: Significant Customers of AEP Texas: Reliant Energy, Direct Energy and TXU Energy (a) 2021 2020 2019 Percentage of Total Revenues 43 % 46 % 48 % Percentage of Accounts Receivable – Customers 41 % 40 % 43 % (a) In January 2021, NRG Energy, parent company of Reliant Energy, completed a deal to purchase Direct Energy from Centrica. AEPTCo had significant transactions with AEP Subsidiaries which on a combined basis account for the following percentages of Total Revenues for the years ended December 31 and Total Accounts Receivable as of December 31: Significant Customers of AEPTCo: AEP Subsidiaries 2021 2020 2019 Percentage of Total Revenues 79 % 78 % 79 % Percentage of Total Accounts Receivable 81 % 78 % 78 % The Registrant Subsidiaries monitor credit levels and the financial condition of their customers on a continuous basis to minimize credit risk. The regulatory commissions allow recovery in rates for a reasonable level of bad debt costs. Management believes adequate provisions for credit loss have been made in the accompanying Registrant Subsidiary financial statements. Renewable Energy Credits (Applies to all Registrants except AEP Texas and AEPTCo) In regulated jurisdictions, the Registrants record renewable energy credits (RECs) at cost. For AEP’s competitive generation business, management records RECs at the lower of cost or net realizable value. The Registrants follow the inventory model for these RECs. RECs expected to be consumed within one year are reported in Materials and Supplies on the balance sheets. RECs with expected consumption beyond one year are included in Deferred Charges and Other Noncurrent Assets on the balance sheets. The purchases and sales of RECs are reported in the Operating Activities section of the statements of cash flows. RECs that are consumed to meet applicable state renewable portfolio standards are recorded in Fuel and Other Consumables Used for Electric Generation at an average cost on the statements of income. The net margin on sales of RECs affects the determination of deferred fuel and REC costs. Property, Plant and Equipment Regulated Electric utility property, plant and equipment for rate-regulated operations are stated at original cost. Additions, major replacements and betterments are added to the plant accounts. Under the group composite method of depreciation, continuous interim routine replacements of items such as boiler tubes, pumps, motors, etc. result in original cost retirements, less salvage, being charged to accumulated depreciation. The group composite method of depreciation assumes that on average, asset components are retired at the end of their useful lives and thus there is no gain or loss. The equipment in each primary electric plant account is identified as a separate group. The depreciation rates that are established take into account the past history of interim capital replacements and the amount of removal cost incurred and salvage received. These rates and the related lives are subject to periodic review. Removal costs accrued are typically recorded as regulatory liabilities when the revenue received for removal costs accrued exceeds actual removal costs incurred. The asset removal costs liability is relieved as removal costs are incurred. A regulatory asset balance will occur if actual removal costs incurred exceed accumulated removal costs accrued. The costs of labor, materials and overhead incurred to operate and maintain plant and equipment are included in operating expenses. Nuclear fuel, including nuclear fuel in the fabrication phase, is included in Other Property, Plant and Equipment on the balance sheets. Long-lived assets are required to be tested for impairment when it is determined that the carrying value of the assets may no longer be recoverable or when the assets meet the held-for-sale criteria under the accounting guidance for “Impairment or Disposal of Long-Lived Assets.” When it becomes probable that an asset in-service or an asset under construction will be abandoned and regulatory cost recovery has been disallowed or is not probable, the cost of that asset shall be removed from plant-in-service or CWIP and charged to expense. The fair value of an asset is the amount at which that asset could be bought or sold in a current transaction between willing parties, as opposed to a forced or liquidation sale. Quoted market prices in active markets are the best evidence of fair value and are used as the basis for the measurement, if available. In the absence of quoted prices for identical or similar assets in active markets, fair value is estimated using various internal and external valuation methods including cash flow analysis and appraisals. Nonregulated Nonregulated operations generally follow the policies of rate-regulated operations listed above but with the following exceptions. Property, plant and equipment of nonregulated operations are stated at original cost (or as adjusted for any applicable impairments) plus the original cost of property acquired or constructed since the acquisition, less disposals. Normal and routine retirements from the plant accounts, net of salvage, are charged to accumulated depreciation for most nonregulated operations under the group composite method of depreciation. A gain or loss would be recorded if the retirement is not considered an interim routine replacement. Removal costs are charged to expense. Allowance for Funds Used During Construction and Interest Capitalization For regulated operations, AFUDC represents the estimated cost of borrowed and equity funds used to finance construction projects that is capitalized and recovered through depreciation over the service life of regulated electric utility plant. The Registrants record the equity component of AFUDC in Allowance for Equity Funds Used During Construction and the debt component of AFUDC as a reduction to Interest Expense on the statements of income. For nonregulated operations, including certain generating assets, interest is capitalized during construction in accordance with the accounting guidance for “Capitalization of Interest.” Valuation of Nonderivative Financial Instruments The book values of Cash and Cash Equivalents, Advances to/from Affiliates, Accounts Receivable, Accounts Payable and Short-term Debt approximate fair value because of the short-term maturity of these instruments. Fair Value Measurements of Assets and Liabilities (Applies to all Registrants except AEPTCo) The accounting guidance for “Fair Value Measurements and Disclosures” establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). Where observable inputs are available for substantially the full term of the asset or liability, the instrument is categorized in Level 2. When quoted market prices are not available, pricing may be completed using comparable securities, dealer values, operating data and general market conditions to determine fair value. Valuation models utilize various inputs such as commodity, interest rate and, to a lesser degree, volatility and credit that include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, market corroborated inputs (i.e. inputs derived principally from, or correlated to, observable market data) and other observable inputs for the asset or liability. For commercial activities, exchange-traded derivatives, namely futures contracts, are generally fair valued based on unadjusted quoted prices in active markets and are classified as Level 1. Level 2 inputs primarily consist of OTC broker quotes in moderately active or less active markets, as well as exchange-traded derivatives where there is insufficient market liquidity to warrant inclusion in Level 1. Management verifies price curves using these broker quotes and classifies these fair values within Level 2 when substantially all of the fair value can be corroborated. Management typically obtains multiple broker quotes, which are nonbinding in nature but are based on recent trades in the marketplace. When multiple broker quotes are obtained, the quoted bid and ask prices are averaged. In certain circumstances, a broker quote may be discarded if it is a clear outlier. Management uses a historical correlation analysis between the broker quoted location and the illiquid locations. If the points are highly correlated, these locations are included within Level 2 as well. Certain OTC and bilaterally executed derivative instruments are executed in less active markets with a lower availability of pricing information. Illiquid transactions, complex structured transactions, FTRs and counterparty credit risk may require nonmarket-based inputs. Some of these inputs may be internally developed or extrapolated and utilized to estimate fair value. When such inputs have a significant impact on the measurement of fair value, the instrument is categorized as Level 3. The main driver of contracts being classified as Level 3 is the inability to substantiate energy price curves in the market. A portion of the Level 3 instruments have been economically hedged which limits potential earnings volatility. AEP utilizes its trustee’s external pricing service to estimate the fair value of the underlying investments held in the benefit plan and nuclear trusts. AEP’s investment managers review and validate the prices utilized by the trustee to determine fair value. AEP’s management performs its own valuation testing to verify the fair values of the securities. AEP receives audit reports of the trustee’s operating controls and valuation processes. Assets in the benefits and nuclear trusts, cash and cash equivalents, other temporary investments and restricted cash for securitized funding are classified using the following methods. Equities are classified as Level 1 holdings if they are actively traded on exchanges. Items classified as Level 1 are investments in money market funds, fixed income and equity mutual funds and equity securities. They are valued based on observable inputs, primarily unadjusted quoted prices in active markets for identical assets. Items classified as Level 2 are primarily investments in individual fixed income securities. Fixed income securities generally do not trade on exchanges and do not have an official closing price but their valuation inputs are based on observable market data. Pricing vendors calculate bond valuations using financial models and matrices. The models use observable inputs including yields on benchmark securities, quotes by securities brokers, rating agency actions, discounts or premiums on securities compared to par prices, changes in yields for U.S. Treasury securities, corporate actions by bond issuers, prepayment schedules and histories, economic events and, for certain securities, adjustments to yields to reflect changes in the rate of inflation. Other securities with model-derived valuation inputs that are observable are also classified as Level 2 investments. Investments with unobservable valuation inputs are classified as Level 3 investments. Investments classified as Other are valued using Net Asset Value as a practical expedient. Items classified as Other are primarily cash equivalent funds, common collective trusts, commingled funds, structured products, private equity, real estate, infrastructure and alternative credit investments. These investments do not have a readily determinable fair value or they contain redemption restrictions which may include the right to suspend redemptions under certain circumstances. Redemption restrictions may also prevent certain investments from being redeemed at the reporting date for the underlying value. Deferred Fuel Costs (Applies to all Registrants except AEP Texas and AEPTCo) The cost of fuel and related emission allowances and emission control chemicals/consumables is charged to Fuel and Other Consumables Used for Electric Generation expense when the fuel is burned or the allowance or consumable is utilized. The cost of fuel also includes the cost of nuclear fuel burned which is computed primarily using the units-of-production method. In regulated jurisdictions with an active FAC, fuel cost over-recoveries (the excess of fuel-related revenues over applicable fuel costs incurred) are generally deferred as current regulatory liabilities and under-recoveries (the excess of applicable fuel costs incurred over fuel-related revenues) are generally deferred as current regulatory assets. Fuel cost over-recovery and under-recovery balances are classified as noncurrent when there is a commission-approved plan to delay refunds or recoveries beyond a one year period. These deferrals are amortized when refunded or when billed to customers in later months with the state regulatory commissions’ review and approval. The amount of an over-recovery or under-recovery can also be affected by actions of the state regulatory commissions. On a routine basis, state regulatory commissions review and/or audit the Registrants’ fuel procurement policies and practices, the fuel cost calculations and FAC deferrals. FAC deferrals are adjusted when costs are no longer probable of recovery or when refunds of fuel reserves are probable. The Registrants share the majority of their Off-system Sales margins to customers either through an active FAC or other rate mechanisms. Where the FAC or Off-system Sales sharing mechanism is capped, frozen or non-existent, changes in fuel costs or sharing of off-system sales impact earnings. Revenue Recognition Regulatory Accounting The Registrants’ financial statements reflect the actions of regulators that can result in the recognition of revenues and expenses in different time periods than enterprises that are not rate-regulated. Regulatory assets (deferred expenses or alternative revenues recognized in accordance with the guidance for “Regulated Operations”) and regulatory liabilities (deferred revenue reductions or refunds) are recorded to reflect the economic effects of regulation in the same accounting period by matching expenses with their recovery through regulated revenues and by matching revenue with its passage to customers in cost-based regulated rates. When regulatory assets are probable of recovery through regulated rates, assets are recorded on the balance sheets. Regulatory assets are reviewed for probability of recovery at each balance sheet date or whenever new events occur. Examples of new events include the issuance of a regulatory commission order or passage of new legislation. If it is determined that recovery of a regulatory asset is no longer probable, the regulatory asset is derecognized as a charge against income. Retail and Wholesale Supply and Delivery of Electricity The Registrants recognize revenues from customers for retail and wholesale electricity sales and electricity transmission and distribution delivery services. The Registrants recognize such revenues on the statements of income as the performance obligations of delivering energy to customers are satisfied. Recognized revenues include both billed and unbilled amounts. In accordance with the applicable state commission’s regulatory treatment, PSO and SWEPCo do not include the fuel portion in unbilled revenue, but rather recognize such revenues when billed to customers. Wholesale transmission revenue is based on FERC-approved formula rate filings made for each calendar year using estimated costs. Revenues initially recognized per the annual rate filing are compared to actual costs, resulting in the subsequent recognition of an over or under-recovered amount, with interest, that is refunded or recovered, respectively, in a future year’s rates. These annual true-ups meet the definition of alternative revenues in accordance with the accounting guidance for “Regulated Operations”, and are recognized by the Registrants in the second quarter of each calendar year following the filing of annual FERC reports. Any portion of the true-ups applicable to an affiliated company is recorded as Accounts Receivable - Affiliated Companies or Accounts Payable - Affiliated Companies on the balance sheets. Any portion of the true-ups applicable to third-parties is recorded as Regulatory Assets or Regulatory Liabilities on the balance sheets. See Note 19 - Revenue from Contracts with Customers for additional information. Gross versus Net Presentation of Certain Electricity Supply and Delivery Activities Most of the power produced at the generation plants is sold to PJM or SPP. The Registrants also purchase power from PJM and SPP to supply power to customers. Generally, these power sales and purchases are reported on a net basis as revenues on the statements of income. However, purchases of power in excess of sales to PJM or SPP, on an hourly net basis, used to serve retail load are recorded gross as Purchased Electricity for Resale on the statements of income. With the exception of certain dedicated load bilateral power supply contracts, the transactions of AEP’s nonregulated subsidiaries are reported as gross purchases or sales. Physical energy purchases arising from non-derivative contracts are accounted for on a gross basis in Purchased Electricity for Resale on the statements of income. Energy purchases arising from non-trading derivative contracts are recorded based on the transaction’s facts and circumstances. Purchases under non-trading derivatives used to serve accrual based obligations are recorded in Purchased Electricity for Resale on the statements of income. All other non-trading derivative purchases are recorded net in revenues. In general, the Registrants record expenses when purchased electricity is received and when expenses are incurred, with the exception of certain power purchase contracts that ar

New Accounting Standards

New Accounting Standards	12 Months Ended
New Accounting Standards	Dec. 31, 2021
New Accounting Pronouncements	2. NEW ACCOUNTING STANDARDS The disclosures in this note apply to all Registrants unless indicated otherwise. During the FASB’s standard-setting process and upon issuance of final standards, management reviews the new accounting literature to determine its relevance, if any, to the Registrants’ business. There are no new standards expected to have a material impact on the Registrants’ financial statements.

Comprehensive Income

Comprehensive Income	12 Months Ended
Comprehensive Income	Dec. 31, 2021
Comprehensive Income	COMPREHENSIVE INCOME The disclosures in this note apply to all Registrants except for AEPTCo. AEPTCo does not have any components of other comprehensive income for any period presented in the financial statements. Presentation of Comprehensive Income The following tables provide the components of changes in AOCI and details of reclassifications from AOCI for the years ended December 31, 2021, 2020 and 2019. The amortization of pension and OPEB AOCI components are included in the computation of net periodic pension and OPEB costs. See Note 8 - Benefit Plans for additional information. AEP Cash Flow Hedges Pension and OPEB For the Year Ended December 31, 2021 Commodity Interest Rate Amortization of Deferred Costs Changes in Funded Status Total (in millions) Balance in AOCI as of December 31, 2020 $ (60.6) $ (47.5) $ 123.7 $ (100.7) $ (85.1) Change in Fair Value Recognized in AOCI 488.2 21.1 (a) — 27.5 536.8 Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (b) 0.7 — — — 0.7 Purchased Electricity for Resale (b) (334.8) — — — (334.8) Interest Expense (b) — 6.5 — — 6.5 Amortization of Prior Service Cost (Credit) — — (19.4) — (19.4) Amortization of Actuarial (Gains) Losses — — 9.1 — 9.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit (334.1) 6.5 (10.3) — (337.9) Income Tax (Expense) Benefit (70.2) 1.4 (2.2) — (71.0) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (263.9) 5.1 (8.1) — (266.9) Net Current Period Other Comprehensive Income (Loss) 224.3 26.2 (8.1) 27.5 269.9 Balance in AOCI as of December 31, 2021 $ 163.7 $ (21.3) $ 115.6 $ (73.2) $ 184.8 AEP Cash Flow Hedges Pension and OPEB For the Year Ended December 31, 2020 Commodity Interest Rate Amortization of Deferred Costs Changes in Funded Status Total (in millions) Balance in AOCI as of December 31, 2019 $ (103.5) $ (11.5) $ 130.7 $ (163.4) $ (147.7) Change in Fair Value Recognized in AOCI (89.2) (39.9) (a) — 62.7 (66.4) Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (b) (0.4) — — — (0.4) Purchased Electricity for Resale (b) 167.6 — — — 167.6 Interest Expense (b) — 4.9 — — 4.9 Amortization of Prior Service Cost (Credit) — — (19.2) — (19.2) Amortization of Actuarial (Gains) Losses — — 10.3 — 10.3 Reclassifications from AOCI, before Income Tax (Expense) Benefit 167.2 4.9 (8.9) — 163.2 Income Tax (Expense) Benefit 35.1 1.0 (1.9) — 34.2 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 132.1 3.9 (7.0) — 129.0 Net Current Period Other Comprehensive Income (Loss) 42.9 (36.0) (7.0) 62.7 62.6 Balance in AOCI as of December 31, 2020 $ (60.6) $ (47.5) $ 123.7 $ (100.7) $ (85.1) Cash Flow Hedges Pension and OPEB For the Year Ended December 31, 2019 Commodity Interest Rate Amortization of Deferred Costs Changes in Funded Status Total (in millions) Balance in AOCI as of December 31, 2018 $ (23.0) $ (12.6) $ 136.3 $ (221.1) $ (120.4) Change in Fair Value Recognized in AOCI (127.2) (0.2) (a) — 57.7 (69.7) Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (b) (0.2) — — — (0.2) Purchased Electricity for Resale (b) 59.5 — — — 59.5 Interest Expense (b) — 1.5 — — 1.5 Amortization of Prior Service Cost (Credit) — — (19.2) — (19.2) Amortization of Actuarial (Gains) Losses — — 12.1 — 12.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit 59.3 1.5 (7.1) — 53.7 Income Tax (Expense) Benefit 12.6 0.2 (1.5) — 11.3 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 46.7 1.3 (5.6) — 42.4 Net Current Period Other Comprehensive Income (Loss) (80.5) 1.1 (5.6) 57.7 (27.3) Balance in AOCI as of December 31, 2019 $ (103.5) $ (11.5) $ 130.7 $ (163.4) $ (147.7) AEP Texas Pension and OPEB Amortization Changes in Cash Flow Hedge – of Deferred Funded For the Year Ended December 31, 2021 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2020 $ (2.3) $ 5.1 $ (11.7) $ (8.9) Change in Fair Value Recognized in AOCI 0.1 — 1.2 1.3 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.2 — — 1.2 Amortization of Prior Service Cost (Credit) — (0.1) — (0.1) Amortization of Actuarial (Gains) Losses — 0.3 — 0.3 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.2 0.2 — 1.4 Income Tax (Expense) Benefit 0.3 — — 0.3 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.9 0.2 — 1.1 Net Current Period Other Comprehensive Income (Loss) 1.0 0.2 1.2 2.4 Balance in AOCI as of December 31, 2021 $ (1.3) $ 5.3 $ (10.5) $ (6.5) Pension and OPEB Amortization Changes in Cash Flow Hedge – of Deferred Funded For the Year Ended December 31, 2020 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2019 $ (3.4) $ 4.9 $ (14.3) $ (12.8) Change in Fair Value Recognized in AOCI 0.1 — 2.6 2.7 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.3 — — 1.3 Amortization of Prior Service Cost (Credit) — (0.1) — (0.1) Amortization of Actuarial (Gains) Losses — 0.3 — 0.3 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.3 0.2 — 1.5 Income Tax (Expense) Benefit 0.3 — — 0.3 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.0 0.2 — 1.2 Net Current Period Other Comprehensive Income (Loss) 1.1 0.2 2.6 3.9 Balance in AOCI as of December 31, 2020 $ (2.3) $ 5.1 $ (11.7) $ (8.9) Pension and OPEB Amortization Changes in Cash Flow Hedge – of Deferred Funded For the Year Ended December 31, 2019 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2018 $ (4.4) $ 4.7 $ (15.4) $ (15.1) Change in Fair Value Recognized in AOCI — — 1.1 1.1 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.3 — — 1.3 Amortization of Prior Service Cost (Credit) — (0.1) — (0.1) Amortization of Actuarial (Gains) Losses — 0.3 — 0.3 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.3 0.2 — 1.5 Income Tax (Expense) Benefit 0.3 — — 0.3 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.0 0.2 — 1.2 Net Current Period Other Comprehensive Income (Loss) 1.0 0.2 1.1 2.3 Balance in AOCI as of December 31, 2019 $ (3.4) $ 4.9 $ (14.3) $ (12.8) APCo Pension and OPEB Amortization Changes in Cash Flow Hedge – of Deferred Funded For the Year Ended December 31, 2021 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2020 $ (0.8) $ 5.4 $ 2.6 $ 7.2 Change in Fair Value Recognized in AOCI 9.2 — 13.1 22.3 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (1.1) — — (1.1) Amortization of Prior Service Cost (Credit) — (5.3) — (5.3) Reclassifications from AOCI, before Income Tax (Expense) Benefit (1.1) (5.3) — (6.4) Income Tax (Expense) Benefit (0.2) (1.1) — (1.3) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.9) (4.2) — (5.1) Net Current Period Other Comprehensive Income (Loss) 8.3 (4.2) 13.1 17.2 Balance in AOCI as of December 31, 2021 $ 7.5 $ 1.2 $ 15.7 $ 24.4 Pension and OPEB Amortization Changes in Cash Flow Hedges - of Deferred Funded For the Year Ended December 31, 2020 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2019 $ 0.9 $ 9.2 $ (5.1) $ 5.0 Change in Fair Value Recognized in AOCI (0.7) — 7.7 7.0 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (1.3) — — (1.3) Amortization of Prior Service Cost (Credit) — (5.3) — (5.3) Amortization of Actuarial (Gains) Losses — 0.5 — 0.5 Reclassifications from AOCI, before Income Tax (Expense) Benefit (1.3) (4.8) — (6.1) Income Tax (Expense) Benefit (0.3) (1.0) — (1.3) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (1.0) (3.8) — (4.8) Net Current Period Other Comprehensive Income (Loss) (1.7) (3.8) 7.7 2.2 Balance in AOCI as of December 31, 2020 $ (0.8) $ 5.4 $ 2.6 $ 7.2 Pension and OPEB Amortization Changes in Cash Flow Hedges of Deferred Funded For the Year Ended December 31, 2019 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2018 $ 1.8 $ 11.7 $ (18.5) $ (5.0) Change in Fair Value Recognized in AOCI — — 13.4 13.4 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (1.1) — — (1.1) Amortization of Prior Service Cost (Credit) — (5.3) — (5.3) Amortization of Actuarial (Gains) Losses — 2.1 — 2.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit (1.1) (3.2) — (4.3) Income Tax (Expense) Benefit (0.2) (0.7) — (0.9) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.9) (2.5) — (3.4) Net Current Period Other Comprehensive Income (Loss) (0.9) (2.5) 13.4 10.0 Balance in AOCI as of December 31, 2019 $ 0.9 $ 9.2 $ (5.1) $ 5.0 I&M Pension and OPEB Amortization Changes in Cash Flow Hedge – of Deferred Funded For the Year Ended December 31, 2021 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2020 $ (8.3) $ 4.8 $ (3.5) $ (7.0) Change in Fair Value Recognized in AOCI — — 4.2 4.2 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 2.0 — — 2.0 Amortization of Prior Service Cost (Credit) — (0.8) — (0.8) Amortization of Actuarial (Gains) Losses — 0.7 — 0.7 Reclassifications from AOCI, before Income Tax (Expense) Benefit 2.0 (0.1) — 1.9 Income Tax (Expense) Benefit 0.4 — — 0.4 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.6 (0.1) — 1.5 Net Current Period Other Comprehensive Income (Loss) 1.6 (0.1) 4.2 5.7 Balance in AOCI as of December 31, 2021 $ (6.7) $ 4.7 $ 0.7 $ (1.3) Pension and OPEB Amortization Changes in Cash Flow Hedge – of Deferred Funded For the Year Ended December 31, 2020 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2019 $ (9.9) $ 4.9 $ (6.6) $ (11.6) Change in Fair Value Recognized in AOCI — — 3.1 3.1 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 2.0 — — 2.0 Amortization of Prior Service Cost (Credit) — (0.8) — (0.8) Amortization of Actuarial (Gains) Losses — 0.7 — 0.7 Reclassifications from AOCI, before Income Tax (Expense) Benefit 2.0 (0.1) — 1.9 Income Tax (Expense) Benefit 0.4 — — 0.4 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.6 (0.1) — 1.5 Net Current Period Other Comprehensive Income (Loss) 1.6 (0.1) 3.1 4.6 Balance in AOCI as of December 31, 2020 $ (8.3) $ 4.8 $ (3.5) $ (7.0) Pension and OPEB Amortization Changes in Cash Flow Hedge – of Deferred Funded For the Year Ended December 31, 2019 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2018 $ (11.5) $ 5.1 $ (7.4) $ (13.8) Change in Fair Value Recognized in AOCI — — 0.8 0.8 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 2.0 — — 2.0 Amortization of Prior Service Cost (Credit) — (0.8) — (0.8) Amortization of Actuarial (Gains) Losses — 0.6 — 0.6 Reclassifications from AOCI, before Income Tax (Expense) Benefit 2.0 (0.2) — 1.8 Income Tax (Expense) Benefit 0.4 — — 0.4 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.6 (0.2) — 1.4 Net Current Period Other Comprehensive Income (Loss) 1.6 (0.2) 0.8 2.2 Balance in AOCI as of December 31, 2019 $ (9.9) $ 4.9 $ (6.6) $ (11.6) OPCo Cash Flow Hedge – For the Year Ended December 31, 2021 Interest Rate (in millions) Balance in AOCI as of December 31, 2020 $ — Change in Fair Value Recognized in AOCI — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) — Reclassifications from AOCI, before Income Tax (Expense) Benefit — Income Tax (Expense) Benefit — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit — Net Current Period Other Comprehensive Income (Loss) — Balance in AOCI as of December 31, 2021 $ — Cash Flow Hedge – For the Year Ended December 31, 2020 Interest Rate (in millions) Balance in AOCI as of December 31, 2019 $ — Change in Fair Value Recognized in AOCI — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) — Reclassifications from AOCI, before Income Tax (Expense) Benefit — Income Tax (Expense) Benefit — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit — Net Current Period Other Comprehensive Income (Loss) — Balance in AOCI as of December 31, 2020 $ — Cash Flow Hedge – For the Year Ended December 31, 2019 Interest Rate (in millions) Balance in AOCI as of December 31, 2018 $ 1.0 Change in Fair Value Recognized in AOCI — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (1.3) Reclassifications from AOCI, before Income Tax (Expense) Benefit (1.3) Income Tax (Expense) Benefit (0.3) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (1.0) Net Current Period Other Comprehensive Income (Loss) (1.0) Balance in AOCI as of December 31, 2019 $ — PSO Cash Flow Hedge – For the Year Ended December 31, 2021 Interest Rate (in millions) Balance in AOCI as of December 31, 2020 $ 0.1 Change in Fair Value Recognized in AOCI — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (0.1) Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.1) Income Tax (Expense) Benefit — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.1) Net Current Period Other Comprehensive Income (Loss) (0.1) Balance in AOCI as of December 31, 2021 $ — Cash Flow Hedge – For the Year Ended December 31, 2020 Interest Rate (in millions) Balance in AOCI as of December 31, 2019 $ 1.1 Change in Fair Value Recognized in AOCI — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (1.3) Reclassifications from AOCI, before Income Tax (Expense) Benefit (1.3) Income Tax (Expense) Benefit (0.3) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (1.0) Net Current Period Other Comprehensive Income (Loss) (1.0) Balance in AOCI as of December 31, 2020 $ 0.1 Cash Flow Hedge – For the Year Ended December 31, 2019 Interest Rate (in millions) Balance in AOCI as of December 31, 2018 $ 2.1 Change in Fair Value Recognized in AOCI — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (1.3) Reclassifications from AOCI, before Income Tax (Expense) Benefit (1.3) Income Tax (Expense) Benefit (0.3) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (1.0) Net Current Period Other Comprehensive Income (Loss) (1.0) Balance in AOCI as of December 31, 2019 $ 1.1 SWEPCo Pension and OPEB Amortization Changes in Cash Flow Hedge – of Deferred Funded For the Year Ended December 31, 2021 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2020 $ (0.3) $ (2.8) $ 5.0 $ 1.9 Change in Fair Value Recognized in AOCI — — 4.9 4.9 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.9 — — 1.9 Amortization of Prior Service Cost (Credit) — (2.0) — (2.0) Amortization of Actuarial (Gains) Losses — — — — Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.9 (2.0) — (0.1) Income Tax (Expense) Benefit 0.4 (0.4) — — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.5 (1.6) — (0.1) Net Current Period Other Comprehensive Income (Loss) 1.5 (1.6) 4.9 4.8 Balance in AOCI as of December 31, 2021 $ 1.2 $ (4.4) $ 9.9 $ 6.7 Pension and OPEB Amortization Changes in Cash Flow Hedge – of Deferred Funded For the Year Ended December 31, 2020 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2019 $ (1.8) $ (1.3) $ 1.8 $ (1.3) Change in Fair Value Recognized in AOCI — — 3.2 3.2 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.9 — — 1.9 Amortization of Prior Service Cost (Credit) — (2.0) — (2.0) Amortization of Actuarial (Gains) Losses — 0.1 — 0.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.9 (1.9) — — Income Tax (Expense) Benefit 0.4 (0.4) — — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.5 (1.5) — — Net Current Period Other Comprehensive Income (Loss) 1.5 (1.5) 3.2 3.2 Balance in AOCI as of December 31, 2020 $ (0.3) $ (2.8) $ 5.0 $ 1.9 Pension and OPEB Amortization Changes in Cash Flow Hedge – of Deferred Funded For the Year Ended December 31, 2019 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2018 $ (3.3) $ (0.2) $ (1.9) $ (5.4) Change in Fair Value Recognized in AOCI — — 3.7 3.7 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.9 — — 1.9 Amortization of Prior Service Cost (Credit) — (2.0) — (2.0) Amortization of Actuarial (Gains) Losses — 0.6 — 0.6 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.9 (1.4) — 0.5 Income Tax (Expense) Benefit 0.4 (0.3) — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.5 (1.1) — 0.4 Net Current Period Other Comprehensive Income (Loss) 1.5 (1.1) 3.7 4.1 Balance in AOCI as of December 31, 2019 $ (1.8) $ (1.3) $ 1.8 $ (1.3) (a) The change in fair value includes $(7) million, $6 million and $4 million related to AEP's investment in joint venture wind farms acquired as part of the purchase of Sempra Renewables LLC for the years ended December 31, 2021, 2020 and 2019, respectively. See “Sempra Renewables LLC” section of Note 17 for additional information. (b) Amounts reclassified to the referenced line item on the statements of income.

Rate Matters

Rate Matters	12 Months Ended
Rate Matters	Dec. 31, 2021
Rate Matters	RATE MATTERS The disclosures in this note apply to all Registrants unless indicated otherwise. The Registrants are involved in rate and regulatory proceedings at the FERC and their state commissions. Rate matters can have a material impact on net income, cash flows and possibly financial condition. The Registrants’ recent significant rate orders and pending rate filings are addressed in this note. AEP Texas Rate Matters (Applies to AEP and AEP Texas) AEP Texas Interim Transmission and Distribution Rates Through December 31, 2021, AEP Texas’ cumulative revenues from interim base rate increases that are subject to review is approximately $298 million. A base rate review could result in a refund to customers if AEP Texas incurs a disallowance of the transmission or distribution investment on which an interim increase was based. Management is unable to determine a range of potential losses, if any, that are reasonably possible of occurring. A revenue decrease, including a refund of interim transmission and distribution rates, could reduce future net income and cash flows and impact financial condition. AEP Texas is required to file for a comprehensive rate review no later than April 5, 2024. APCo and WPCo Rate Matters (Applies to AEP and APCo) 2017-2019 Virginia Triennial Review In November 2020, the Virginia SCC issued an order on APCo’s 2017-2019 Triennial Review filing concluding that APCo earned above its authorized ROE but within its ROE band for the 2017-2019 period, resulting in no refund to customers and no change to APCo base rates on a prospective basis. The Virginia SCC approved a prospective 9.2% ROE for APCo's 2020-2022 triennial review period with the continuation of a 140 basis point band (8.5% bottom, 9.2% midpoint, 9.9% top). In December 2020, an intervenor filed a petition at the Virginia SCC requesting reconsideration of: (a) the failure of the Virginia SCC to apply a threshold earnings test to the approved regulatory asset for APCo’s closed coal-fired generation assets, (b) the Virginia SCC’s use of a 2011 benchmark study to measure the replacement value of capacity for purposes of APCo’s 2017 – 2019 earnings test and (c) the reasonableness and prudency of APCo’s investments in AMI meters. In December 2020, APCo filed a petition at the Virginia SCC requesting reconsideration of: (a) certain issues related to APCo’s going-forward rates and (b) the Virginia SCC’s decision to deny APCo tariff changes that align rates with underlying costs. For APCo’s going-forward rates, APCo requested that the Virginia SCC clarify its final order and clarify whether APCo’s current rates will allow it to earn a fair return. If the Virginia SCC’s order did conclude on APCo’s ability to earn a fair return through existing base rates, APCo further requested that the Virginia SCC clarify whether it has the authority to also permit an increase in base rates. In March 2021, an intervenor filed its assignments of error with the Virginia Supreme Court related to the appeal of the November 2020 order in which it stated the Virginia SCC erred: (a) in determining that Virginia law did not apply to its determination to permit amortization for recovery of costs associated with retired coal-fired generation assets, (b) in establishing a new regulatory asset for a cost incurred outside of the triennial review period due to its failure to apply a threshold earnings test before approving deferred cost recovery and (c) in misapplying the requirement that APCo bear the burden of demonstrating that power purchases made by APCo from its affiliate, OVEC, were priced at the lower of OVEC’s cost or the market price for nonaffiliated power. In March 2021, APCo filed its assignments of error with the Virginia Supreme Court related to its appeal of the November 2020 order in which it stated the Virginia SCC erred: (a) in finding that costs associated with asset impairments related to early retirement determinations made by APCo for certain generation facilities should not be attributed to the test periods under review and deemed fully recovered in the period recorded, (b) in finding that it was permitted to evaluate the reasonableness of APCo’s decision to record, per books for financial reporting purposes, asset impairments related to early retirement determinations for certain generation facilities, (c) as a result of the errors described in (a) and (b), in denying APCo an increase in rates, (d) in failing to review and make any findings regarding whether APCo’s rates would allow it to earn a fair rate of return going forward, (e) in denying APCo an increase in base rates by failing to ensure that APCo has an opportunity to recover its costs and earn a fair rate of return, thereby resulting in a taking of private property for public use without just compensation and (f) in retroactively adjusting APCo’s depreciation expense for purposes of calculating APCo’s earnings for the 2017-2019 triennial period. In March 2021, the Virginia SCC issued an order confirming certain of its decisions from the November 2020 order and rejecting the various requests for reconsideration from APCo and an intervenor. In confirming its decision to reject an intervenor’s recommendation that APCo’s AMI costs incurred during the triennial period be disallowed, the Virginia SCC clarified that APCo established the need to replace its existing AMR meters, and that based on the uncertainty surrounding the continued manufacturing and support of AMR technology, APCo reasonably chose to replace them with AMI meters. In March 2021, APCo filed a notice of appeal of the reconsideration order with the Virginia Supreme Court. In September 2021, APCo submitted its brief before the Virginia Supreme Court. The brief was in alignment with the assignments of error filed by APCo in March 2021. In October 2021, the Virginia SCC and additional intervenors filed briefs with the Virginia Supreme Court disagreeing with APCo’s assignments of error in its appeal of the Triennial Review decision. Additionally, the Virginia SCC and APCo filed briefs disagreeing with an intervenor’s assignments of error in a separate appeal of the same decision. Oral arguments are scheduled to be held at the Virginia Supreme Court in March 2022. APCo ultimately seeks an increase in base rates through its appeal to the Virginia Supreme Court. Among other issues, this appeal includes APCo’s request for proper treatment of the closed coal-fired plant assets in APCo’s 2017-2019 triennial period, reducing APCo’s earnings below the bottom of its authorized ROE band. If APCo’s appeals regarding treatment of the closed coal plants are granted by the Virginia Supreme Court, it could initially reduce future net income and impact financial condition. A Virginia Supreme Court decision in favor of APCo’s original expensing of the closed coal-fired plant asset balances would likely result in a remand to the Virginia SCC. Upon a subsequent Virginia SCC order, the initial negative impact for the write-off of the closed coal-fired plant asset balances could potentially be offset by an increase in base rates for earning below APCo’s 2017-2019 authorized ROE band. CCR/ELG Compliance Plan Filings In December 2020, APCo submitted filings with the Virginia SCC and WVPSC requesting approvals necessary to implement CCR/ELG compliance plans at the Amos and Mountaineer Plants. Intervenors in Virginia and West Virginia recommended that only the CCR-related investments be constructed at Amos and Mountaineer and, as a consequence, that APCo close these generating facilities at the end of 2028. In August 2021, the Virginia SCC issued an order approving APCo’s request to construct CCR-related investments at the Amos and Mountaineer Plants and approved recovery of CCR-related other operation and maintenance expenses and investments through an active rider. The order denied APCo’s request to construct the ELG investments and denied recovery of previously incurred ELG costs. APCo plans to refile for approval of the ELG investments and previously incurred ELG costs in the first quarter of 2022. Also in August 2021, the WVPSC approved the request to construct CCR/ELG investments at the Amos and Mountaineer Plants and approved recovery of the West Virginia jurisdictional share of these costs through an active rider. In October 2021, due to the Virginia SCC previously rejecting the ELG investments, the WVPSC issued an order directing APCo to proceed with CCR/ELG compliance plans that would allow the plants to continue operating beyond 2028. The October order further states that APCo will not share capacity and energy from the plants with customers from Virginia if those customers are not paying for ELG compliance costs, or for any new capital investment or continuing operations costs incurred, to allow the plants to operate beyond 2028 or prevent downgrades prior to 2028. The WVPSC also ordered that APCo will be given the opportunity to recover, from West Virginia customers, the new capital and operating costs arising solely from the WVPSC's directive to operate the plants beyond 2028 if the WVPSC finds that the costs are reasonably and prudently incurred. In October and November 2021, intervenors filed petitions for reconsideration at the WVPSC requesting clarification on certain aspects of the order, primarily the jurisdictional allocation of future operating expenses and plant costs. APCo expects total Amos and Mountaineer Plant ELG investment, excluding AFUDC, to be approximately $197 million. As of December 31, 2021, APCo’s Virginia jurisdictional share of the net book value, before cost of removal including CWIP and inventory, of the Amos and Mountaineer Plants was approximately $1.5 billion and APCo’s Virginia jurisdictional share of its ELG investment balance in CWIP for these plants was $26 million. If any of the ELG costs are not approved for recovery and/or the retirement dates of the Amos and Mountaineer plants are accelerated to 2028 without commensurate cost recovery, it would reduce future net income and cash flows and impact financial condition. ETT Rate Matters (Applies to AEP) ETT Interim Transmission Rates AEP has a 50% equity ownership interest in ETT. Predominantly all of ETT’s revenues are based on interim rate changes that can be filed twice annually and are subject to review and possible true-up in the next base rate proceeding. Through December 31, 2021, AEP’s share of ETT’s cumulative revenues that are subject to review is approximately $1.4 billion. A base rate review could produce a refund if ETT incurs a disallowance of the transmission investment on which an interim increase was based. A revenue decrease, including a refund of interim transmission rates, could reduce future net income and cash flows and impact financial condition. Management is unable to determine a range of potential losses, if any, that are reasonably possible of occurring. ETT is required to file for a comprehensive rate review no later than February 1, 2023, during which the $1.4 billion of cumulative revenues above will be subject to review. I&M Rate Matters (Applies to AEP and I&M) 2021 Indiana Base Rate Case In July 2021, I&M filed a request with the IURC for a $104 million annual increase in Indiana rates, inclusive of base rates and riders, based upon a proposed 10% ROE. I&M proposed a phased-in annual increase in rates of $73 million effective in May 2022 with the remaining $31 million annual increase in rates to be effective January 2023. The proposed annual increase includes $7 million related to an annual increase in depreciation expense, driven by increased depreciation rates and proposed investments. The request also includes a new AMI rider for proposed meter projects. In November 2021, I&M and intervenors filed an unopposed joint settlement agreement with the IURC. After adjustments to remove the impact of Rockport Plant, Unit 2, the agreement includes a $61 million annual revenue increase based on a 9.7% ROE. The primary differences between I&M’s requested annual rate increase and the agreed upon settlement increase are primarily due to: (a) changes to the capital structure of I&M, (b) decreased depreciation rates and (c) certain changes to I&M’s proposed rate base. Rockport Plant, Unit 2 costs will be recovered through riders until the lease expiration in December 2022. Adjustments to remove Rockport Plant, Unit 2 costs from base rates are consistent with the IURC’s order approving I&M’s proposed purchase of Rockport Plant, Unit 2. See “Rockport Plant Litigation” section of Note 6 for additional information. In February 2022, the IURC issued an order approving the joint settlement agreement with no modifications. The IURC’s order resulted in a phased-in increase in Indiana rates with a $3 million annual increase effective February 2022 and the remaining $58 million annual increase effective in January 2023. KPCo Rate Matters (Applies to AEP) CCR/ELG Compliance Plan Filings KPCo and WPCo each own a 50% interest in the Mitchell Plant. In December 2020 and February 2021, WPCo and KPCo filed requests with the WVPSC and KPSC, respectively, to obtain the regulatory approvals necessary to implement CCR and ELG compliance plans and seek recovery of the estimated $132 million investment for the Mitchell Plant that would allow the plant to continue operating beyond 2028. Within those requests, WPCo and KPCo also filed a $25 million alternative to implement only the CCR-related investments with the WVPSC and KPSC, respectively, which would allow the Mitchell Plant to continue operating only through 2028. In July 2021, the KPSC issued an order approving the CCR only alternative and rejecting the full CCR and ELG compliance plan. In August 2021, the WVPSC approved the full CCR and ELG compliance plan for the WPCo share of the Mitchell Plant. In September 2021, WPCo submitted a filing with the WVPSC to reopen the CCR/ELG case that was approved by the WVPSC in August 2021. Due to the rejection by the KPSC of the KPCo share of the ELG investments, WPCo requested the WVPSC consider approving the construction and recovery of all ELG costs at the plant. In October 2021, the WVPSC affirmed its August 2021 order approving the construction of CCR/ELG investments and directed WPCo to proceed with CCR/ELG compliance plans that would allow the plant to continue operating beyond 2028. The WVPSC’s order further states WPCo will not share capacity and energy from the plant with KPCo customers if those customers are not paying for ELG compliance costs, or for any new capital investment or continuing operations costs incurred, to allow the plant to operate beyond 2028 or prevent downgrades prior to 2028. The WVPSC also ordered that WPCo will be given the opportunity to recover, from its customers, the new capital and operating costs arising solely from the WVPSC's directive to operate the plant beyond 2028 if the WVPSC finds that the costs are reasonably and prudently incurred. In October and November 2021, intervenors filed petitions for reconsideration at the WVPSC requesting clarification on certain aspects of the order, primarily the jurisdictional allocation of future operating expenses and plant costs. In November 2021, AEP made filings with the KPSC, WVPSC and FERC seeking approval for a new proposed Mitchell Plant Operations and Maintenance Agreement and Mitchell Plant Ownership Agreement between KPCo and WPCo pursuant to which WPCo would replace KPCo as the operator of the Mitchell Plant. In February 2022, AEP filed a motion to withdraw its filing with the FERC, noting that AEP intends to re-file its request after the KPSC and WVPSC reviews have been completed. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. As of December 31, 2021, KPCo’s share of the Mitchell Plant’s ELG investment balance in CWIP was $3 million. As of December 31, 2021, the net book value of KPCo’s share of the Mitchell Plant, before cost of removal including CWIP and inventory, was $586 million. If any of the ELG costs are not approved for recovery and/or the retirement date of the Mitchell Plant is accelerated to 2028 without commensurate cost recovery, it would reduce future net income and cash flows and impact financial condition. OPCo Rate Matters (Applies to AEP and OPCo) 2020 Ohio Base Rate Case In June 2020, OPCo filed a request with the PUCO for a $42 million annual increase in base rates based upon a proposed 10.15% ROE net of existing riders. In March 2021, OPCo, the PUCO staff and various intervenors filed a joint stipulation and settlement agreement with the PUCO. The agreement includes a $68 million annual decrease in base rates based on an ROE of 9.7%. The difference between OPCo’s requested annual base rate increase and the agreed upon decrease is primarily due to a reduction in the requested ROE, the removal of proposed future energy efficiency costs and a decrease in vegetation management expenses moved to recovery in riders. Additionally, the agreement includes: (a) an increased fixed monthly residential customer charge, (b) the discontinuation of rate decoupling and (c) the continuation of the DIR with annual revenue caps of $57 million in 2021, $91 million in 2022, $116 million in 2023 and $51 million for the first five months of 2024. Annual revenue caps for the DIR can be increased if OPCo achieves certain reliability standards. In November 2021, the PUCO approved the joint stipulation and settlement agreement and rates went into effect in December 2021. OVEC Cost Recovery Audits In December 2021, as part of OVEC cost recovery audits pending before the PUCO, intervenors filed positions claiming that costs incurred by OPCo during the 2018-2019 audit period were imprudent and should be disallowed. Management disagrees with these claims and is unable to predict the impact, if any, these disputes may have on future results of operations, financial condition and cash flows. See "OVEC" section of Note 17 for additional information on AEP and OPCo’s investment in OVEC. PSO Rate Matters (Applies to AEP and PSO) 2021 Oklahoma Base Rate Case In April 2021, PSO filed a request with the OCC for a $172 million net annual increase in Oklahoma base rates based upon a 10% ROE. The proposed net annual increase includes: (a) a $57 million annual depreciation expense increase, of which $45 million is related to the accelerated depreciation recovery of the Oklaunion Power Station and Northeastern Plant, Unit 3 through 2026 and (b) $31 million related to increased SPP expenses. PSO also requested the continuation of its SPP Transmission Tariff that tracks transmission costs as well as continuation and expansion of its Distribution and Safety Reliability Rider to recover projects in its proposed grid transformation and revitalization plan, which includes $100 million annual capital spend over a 5 year period. In August 2021, PSO updated its request for a net annual revenue increase to appropriately reflect certain cost reductions and annualized rider revenues transitioning into base rates. PSO’s updated request filed with the OCC is for a $128 million net annual increase in Oklahoma base rates based upon a 10% ROE. In September 2021, PSO, OCC staff and certain intervenors filed a contested joint stipulation and settlement agreement with the OCC that included a net annual revenue increase of $51 million based upon a 9.4% ROE. The agreement also included: (a) recovery of, with a debt return on, the Oklaunion Power Station regulatory asset through 2046 and continued recovery of Northeastern Plant, Unit 3 through 2040, (b) updated depreciation rates for plant in service, excluding coal production plant, (c) approval to defer a weighted average cost of capital carrying charge on PSO’s deferred tax asset associated with net operating loss on a stand-alone tax basis beginning in November 2021 and, contingent upon receipt of a supportive private letter ruling from the IRS, approval to collect the deferral through a rider over a 20-month period, (d) modification of the SPP transmission tariff to reduce the scope of tracked transmission expense and (e) modification of the Distribution Reliability and Safety Rider to limit recovery to previously approved projects not in service as of June 2021. PSO implemented an interim annual base rate increase of $51 million starting with the November 2021 billing cycle. In December 2021, the OCC approved the joint stipulation and settlement agreement without modifications. Effective February 2022, interim rates were terminated and updated rates and tariffs went into effect in accordance with the final order. February 2021 Severe Winter Weather Impacts in SPP In February 2021, severe winter weather had a significant impact in SPP, resulting in the declaration of Energy Emergency Alert Levels 2 and 3 for the first time in SPP’s history. The winter storm increased the demand for natural gas and restricted the available natural gas supply resulting in significantly increased market prices for natural gas power plants to meet reliability needs for the SPP electric system. For the time period of February 9, 2021, to February 20, 2021, PSO’s natural gas expenses and purchases of electricity still to be recovered from customers are $679 million as of December 31, 2021. In April 2021, the OCC approved a waiver for PSO allowing the deferral of the extraordinary fuel and purchases of electricity, including a carrying charge at an interim rate of 0.75%, over a longer time period than what the FAC traditionally allows. In January 2022, PSO, OCC staff and certain intervenors filed a joint stipulation and settlement agreement with the OCC to approve PSO’s securitization of the extraordinary fuel and purchases of electricity. The agreement includes a determination that all of PSO’s extraordinary fuel and purchases of electricity were prudent and reasonable and a 0.75% carrying charge, subject to true-up based on actual financing costs. In February 2022, the OCC approved the joint stipulation and settlement agreement in its financing order. SWEPCo Rate Matters (Applies to AEP and SWEPCo) 2012 Texas Base Rate Case In 2012, SWEPCo filed a request with the PUCT to increase annual base rates primarily due to the completion of the Turk Plant. In 2013, the PUCT issued an order affirming the prudence of the Turk Plant but determined that the Turk Plant’s Texas jurisdictional capital cost cap established in a previous Certificate of Convenience and Necessity case also limited SWEPCo’s recovery of AFUDC in addition to limits on its recovery of cash construction costs. Upon rehearing in 2014, the PUCT reversed its initial ruling and determined that AFUDC was excluded from the Turk Plant’s Texas jurisdictional capital cost cap. As a result, SWEPCo reversed $114 million of a previously recorded regulatory disallowance in 2013. In 2017, the Texas District Court upheld the PUCT’s 2014 order and intervenors filed appeals with the Texas Third Court of Appeals. In July 2018, the Texas Third Court of Appeals reversed the PUCT’s judgment affirming the prudence of the Turk Plant and remanded the issue back to the PUCT. In January 2019, SWEPCo and the PUCT filed petitions for review with the Texas Supreme Court. In March 2021, the Texas Supreme Court issued an opinion reversing the July 2018 judgment of the Texas Third Court of Appeals and agreeing with the PUCT’s judgment affirming the prudence of the Turk Plant. In addition, the Texas Supreme Court remanded the AFUDC dispute back to the Texas Third Court of Appeals. No parties filed a motion for rehearing with the Texas Supreme Court. In August 2021, the Texas Third Court of Appeals reversed the Texas District Court judgement affirming the PUCT’s order on AFUDC, concluding that the language of the PUCT’s original 2008 order intended to include AFUDC in the Texas jurisdictional capital cost cap, and remanded the case to the PUCT for future proceedings. SWEPCo disagrees with the Court of Appeals decision and submitted a Petition for Review with the Texas Supreme Court in November 2021. The Texas Supreme Court requested responses to the Petition for Review, which are due by the end of March 2022. If SWEPCo is ultimately unable to recover capitalized Turk Plant costs, including AFUDC in excess of the Texas jurisdictional capital cost cap, it would be expected to result in a pretax net disallowance ranging from $80 million to $100 million. In addition, if AFUDC is ultimately determined to be included in the Texas jurisdictional capital cost cap, SWEPCo estimates it may be required to make customer refunds ranging from $0 to $160 million related to revenues collected from February 2013 through December 2021 and such determination may reduce SWEPCo’s future revenues by approximately $15 million on an annual basis. 2016 Texas Base Rate Case In 2016, SWEPCo filed a request with the PUCT for a net increase in Texas annual revenues of $69 million based upon a 10% ROE. In January 2018, the PUCT issued a final order approving a net increase in Texas annual revenues of $50 million based upon a ROE of 9.6%, effective May 2017. The final order also included: (a) approval to recover the Texas jurisdictional share of environmental investments placed in- service, as of June 30, 2016, at various plants, including Welsh Plant, Units 1 and 3, (b) approval of recovery of, but no return on, the Texas jurisdictional share of the net book value of Welsh Plant, Unit 2, (c) approval of $2 million in additional vegetation management expenses and (d) the rejection of SWEPCo’s proposed transmission cost recovery mechanism. As a result of the final order, in 2017 SWEPCo: (a) recorded an impairment charge of $19 million, which included $7 million associated with the lack of return on Welsh Plant, Unit 2 and $12 million related to other disallowed plant investments, (b) recognized $32 million of additional revenues, for the period of May 2017 through December 2017, that was surcharged to customers in 2018 and (c) recognized an additional $7 million of expenses consisting primarily of depreciation expense and vegetation management expense, offset by the deferral of rate case expense. SWEPCo implemented new rates in February 2018 billings. The $32 million of additional 2017 revenues was collected during 2018. In March 2018, the PUCT clarified and corrected portions of the final order, without changing the overall decision or amounts of the rate change. The order has been appealed by various intervenors. The appeal will move forward following the conclusion of the 2012 Texas Base Rate Case. If certain parts of the PUCT order are overturned, it could reduce future net income and cash flows and impact financial condition. 2020 Texas Base Rate Case In October 2020, SWEPCo filed a request with the PUCT for a $105 million annual increase in Texas base rates based upon a proposed 10.35% ROE. The request would move transmission and distribution interim revenues recovered through riders into base rates. Eliminating these riders would result in a net annual requested base rate increase of $90 million primarily due to increased investments. The proposed net annual increase: (a) includes $5 million related to vegetation management to maintain and improve the reliability of SWEPCo’s Texas jurisdictional distribution system, (b) requests a $10 million annual depreciation increase and (c) seeks $2 million annually to establish a storm catastrophe reserve. In addition, SWEPCo also requested recovery of the Texas jurisdictional share of the Dolet Hills Power Station of $45 million which was retired in December 2021. SWEPCo subsequently filed a request with the PUCT lowering the requested annual increase in Texas base rates to $100 million which would result in an $85 million net annual base rate increase after moving the proposed riders to rate base. In January 2022, the PUCT issued a final order approving an annual revenue increase of $39 million based upon a 9.25% ROE. The order also includes: (a) rates implemented retroactively back to March 18, 2021, (b) $5 million of the proposed increase related to vegetation management, (c) $2 million annually to establish a storm catastrophe reserve (d) the creation of a rider that would recover the Dolet Hills Power Station as if it were in rate base until its retirement at the end of 2021 and starting in 2022 the remaining net book value would be recovered as a regulatory asset through 2046. As a result of the final order, SWEPCo recorded a disallowance of $12 million associated with the lack of return on the Dolet Hills Power Station. In February 2022, SWEPCo filed a motion for rehearing with the PUCT challenging several errors in the order, which include challenges of the approved ROE, the denial of a reasonable return or carrying costs on the Dolet Hills Power Station and the calculation of the Texas jurisdictional share of the storm catastrophe reserve. 2020 Louisiana Base Rate Case In December 2020, SWEPCo filed a request with the LPSC for a $134 million annual increase in Louisiana base rates based upon a proposed 10.35% ROE. SWEPCo subsequently revised the requested annual increase to $114 million to reflect removing hurricane storm restoration costs from the base case filing. The hurricane costs have been requested in a separate storm filing. See “2021 Louisiana Storm Cost Filing” below for more information. The base case filing would extend the formula rate plan for five years and includes modifications to the formula rate plan to allow for forward-looking transmission costs, reflects the impact of net operating losses associated with the acceleration of certain tax benefits and incorporates future federal corporate income tax changes. The proposed net annual increase requests a $32 million annual depreciation increase to recover Louisiana’s share of the Dolet Hills Power Station, Pirkey Power Plant and Welsh Plant, all of which are expected to be retired early. In July 2021, the LPSC staff filed testimony supporting a $6 million annual increase in base rates based upon a ROE of 9.1% while other intervenors recommended a ROE ranging from 9.35% to 9.8%. The primary differences between SWEPCo’s requested annual increase in base rates and the LPSC staff’s recommendation include: (a) a reduction in depreciation expense, (b) recovery of Dolet Hills Power Station and Pirkey Power Plant in a separate rider mechanism, (c) the rejection of SWEPCo’s proposed adjustment to include a stand-alone net operating loss carryforward deferred tax asset in rate base and (d) a reduction in the proposed ROE. In September 2021, SWEPCo filed rebuttal testimony supporting a revised requested annual increase in base rates of $95 million. The primary differences in the rebuttal testimony from the previous revised request of $114 million are modifications to the proposed recovery of the Dolet Hills Power Station and revisions to various proposed amortizations. LPSC staff and intervenor responses to SWEPCo’s rebuttal testimony were filed in October 2021. The procedural schedule for the case is on hold due to ongoing settlement discussions. If any of these costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. 2021 Arkansas Base Rate Case In July 2021, SWEPCo filed a request with the APSC for an $85 million annual increase in Arkansas base rates based upon a proposed 10.35% ROE with a capital structure of 48.7% debt and 51.3% common equity. The proposed annual increase includes: (a) a $41 million revenue requirement for the North Central Wind Facilities, (b) a $14 million annual depreciation increase primarily due to recovery of the Dolet Hills Power Station through 2026 and Pirkey Plant and Welsh Plant, Units 1 and 3 through 2037 and (c) a $6 million increase due to SPP costs. SWEPCo requested that rates become effective in June 2022. APSC staff filed testimony supporting a $47 million annual increase in base rates based upon a ROE of 9.3% while other intervenors recommended a ROE ranging from 8.75% to 9.25%. The primary differences between SWEPCo’s requested annual increase in base rates and the APSC staff’s recommendation include: (a) recovery of the Dolet Hills Power Station through 2046 with no debt or equity return, (b) a reduction in the proposed ROE with a capital structure of 55.5% debt and 44.5% common equity and (c) lower depreciation rates. The APSC staff also recommended future generating facility retirements be treated similar to the Dolet Hills Power Station recommendation of recovery with no debt or equity return. Also, an intervenor recommended no debt or equity return on the Pirkey Powe

Effects of Regulation

Effects of Regulation	12 Months Ended
Effects of Regulation	Dec. 31, 2021
Effects of Regulation	EFFECTS OF REGULATION The disclosures in this note apply to all Registrants unless indicated otherwise. Coal-Fired Generation Plants (Applies to AEP, PSO and SWEPCo) Compliance with extensive environmental regulations requires significant capital investment in environmental monitoring, installation of pollution control equipment, emission fees, disposal costs and permits. Management continuously evaluates cost estimates of complying with these regulations which has resulted in, and in the future may result in, a decision to retire coal-fired generating facilities earlier than their currently estimated useful lives. Management is seeking or will seek regulatory recovery, as necessary, for any net book value remaining when the plants are retired. To the extent the net book value of these generation assets are not deemed recoverable, it could materially reduce future net income and cash flows and impact financial condition. Regulated Generating Units that have been Retired PSO The Oklaunion Power Station was retired in September 2020 and sold to a nonaffiliated third-party in October 2020. As part of the 2021 Oklahoma Base Rate Case, PSO received approval from the OCC to recover the Oklaunion Power Station as a regulatory asset through 2046. See “2021 Oklahoma Base Rate Case” section of Note 4 for additional information. SWEPCo In April 2016, Welsh Plant, Unit 2 was retired. As part of the 2016 Texas Base Rate Case, the PUCT authorized recovery of SWEPCo’s Texas jurisdictional share of Welsh Plant, Unit 2, but denied SWEPCo the ability to earn a return on this investment resulting in a disallowance of $7 million in 2017. See “2016 Texas Base Rate Case” section of Note 4 for additional information. As part of the 2019 Arkansas Base Rate Case, SWEPCo received approval from the APSC to recover the Arkansas jurisdictional share of Welsh Plant, Unit 2. In December 2020, SWEPCo filed a request with the LPSC to recover the Louisiana jurisdictional share of Welsh Plant, Unit 2. See “2020 Louisiana Base Rate Case” section of Note 4 for additional information. As of December 31, 2021, SWEPCo has a regulatory asset for plant retirement costs pending approval recorded on its balance sheet of $35 million related to the Louisiana jurisdictional share of Welsh Plant, Unit 2. In December 2021, the Dolet Hills Power Station was retired. As part of the 2020 Texas Base Rate Case, the PUCT authorized recovery of SWEPCo’s Texas jurisdictional share of the Dolet Hills Power Station, but denied SWEPCo the ability to earn a return on this investment resulting in a disallowance of $12 million in December 2021. SWEPCo has also requested recovery of the Dolet Hills Power Station in the Arkansas and Louisiana jurisdictions through base rate cases. See “2020 Texas Base Rate Case”, “2020 Louisiana Base Rate Case” and “2021 Arkansas Base Rate Case” sections of Note 4 for additional information. The Dolet Hills Power Station is currently being recovered through 2026 in the Louisiana jurisdiction and through 2046 in the Arkansas and Texas jurisdictions. As of December 31, 2021, SWEPCo has a regulatory asset for the Dolet Hills Power Station pending approval recorded on its balance sheet of $72 million related to the Arkansas and Louisiana jurisdictional shares. Regulated Generating Units to be Retired PSO In 2014, PSO received final approval from the Federal EPA to close Northeastern Plant, Unit 3, in 2026. The plant was originally scheduled to close in 2040. As a result of the early retirement date, PSO revised the useful life of Northeastern Plant, Unit 3, to the projected retirement date of 2026 and the incremental depreciation is being deferred as a regulatory asset. As part of the 2021 Oklahoma Base Rate Case, PSO will continue to recover Northeastern Plant, Unit 3 through 2040. See “2021 Oklahoma Base Rate Case” section of Note 4 for additional information. SWEPCo In November 2020, management announced plans to retire Pirkey Power Plant in 2023 and that it will cease using coal at the Welsh Plant in 2028. As a result of the announcement, SWEPCo began recording a regulatory asset for accelerated depreciation. The table below summarizes the net book value including CWIP, before cost of removal and materials and supplies, as of December 31, 2021, of generating facilities planned for early retirement: Plant Net Book Value Accelerated Depreciation Regulatory Asset Cost of Removal Projected Current Authorized Annual (dollars in millions) Northeastern Plant, Unit 3 $ 167.2 $ 128.1 $ 20.0 (b) 2026 (c) $ 14.9 Pirkey Power Plant 120.0 87.0 39.3 2023 (d) 13.5 Welsh Plant, Units 1 and 3 475.2 45.9 58.4 (e) 2028 (f) 36.4 (a) Represents the amount of annual depreciation that has been collected from customers over the prior 12-month period. (b) Includes Northeastern Plant, Unit 4, which was retired in 2016. Removal of Northeastern Plant, Unit 4, will be performed with Northeastern Plant, Unit 3, after retirement. (c) Northeastern Plant, Unit 3 is currently being recovered through 2040. (d) Pirkey Power Plant is currently being recovered through 2025 in the Louisiana jurisdiction and through 2045 in the Arkansas and Texas jurisdictions. (e) Includes Welsh Plant, Unit 2, which was retired in 2016. Removal of Welsh Plant, Unit 2, will be performed with Welsh Plant, Units 1 and 3, after retirement. (f) Unit 1 is being recovered through 2027 in the Louisiana jurisdiction and through 2037 in the Arkansas and Texas jurisdictions. Unit 3 is being recovered through 2032 in the Louisiana jurisdiction and through 2042 in the Arkansas and Texas jurisdictions. Dolet Hills Power Station and Related Fuel Operations (Applies to AEP and SWEPCo) In 2020, management of SWEPCo and CLECO determined DHLC would not proceed developing additional Oxbow Lignite Company (Oxbow) mining areas for future lignite extraction and ceased extraction of lignite at the mine in May 2020. In April 2020, SWEPCo and CLECO jointly filed a notification letter to the LPSC providing notice of the cessation of lignite mining. In December 2021, the Dolet Hills Power Station was retired. The Dolet Hills Power Station non-fuel costs are recoverable by SWEPCo through base rates. As of December 31, 2021, SWEPCo’s share of the net investment in the Dolet Hills Power Station is $108 million, including materials and supplies, net of cost of removal collected in rates. Fuel costs incurred by the Dolet Hills Power Station are recoverable by SWEPCo through active fuel clauses. As of December 31, 2021, SWEPCo had a net under-recovered fuel balance of $144 million, excluding impacts of the February 2021 severe winter weather event, which includes fuel consumed at the Dolet Hills Power Station. Additional reclamation and other land-related costs incurred by DHLC and Oxbow will be billed to SWEPCo and included in existing fuel clauses. In June 2020, SWEPCo filed a fuel reconciliation with the PUCT for its retail operations in Texas, including Dolet Hills, for the reconciliation period of March 1, 2017 to December 31, 2019. See “2020 Texas Fuel Reconciliation” below for additional information. In March 2021, the LPSC issued an order allowing SWEPCo to recover up to $20 million of fuel costs in 2021 and defer approximately $30 million of additional costs with a recovery period to be determined at a later date. In November 2021, the LPSC issued a directive which deferred the issues regarding modification of the level and timing of recovery of the Dolet Hills Power Station from SWEPCo’s pending rate case to a separate existing docket. In addition, the recovery of the deferred fuel costs are planned to be addressed. In March 2021, the APSC approved fuel rates that provide recovery of the Arkansas share of the 2021 Dolet Hills Power Station fuel costs over five years through the existing fuel clause. In the Arkansas base case, Staff proposed an extension of the recovery period to 25 years. See “2021 Arkansas Base Rate Case” section of Note 4 for additional information. If any of these costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. Pirkey Power Plant and Related Fuel Operations (Applies to AEP and SWEPCo) In 2020, management announced plans to retire the Pirkey Power Plant in 2023. The Pirkey Power Plant non-fuel costs are recoverable by SWEPCo through base rates and fuel costs are recovered through active fuel clauses. As of December 31, 2021, SWEPCo’s share of the net investment in the Pirkey Power Plant is $207 million, including CWIP, before cost of removal. Sabine is a mining operator providing mining services to the Pirkey Power Plant. Under the provisions of the mining agreement, SWEPCo is required to pay, as part of the cost of lignite delivered, an amount equal to mining costs plus a management fee. SWEPCo expects fuel deliveries, including billings of all fixed and operating costs, from Sabine to cease during the first quarter of 2023. Under the fuel agreements, SWEPCo’s fuel inventory and unbilled fuel costs from mining related activities were $91 million as of December 31, 2021. Also, as of December 31, 2021, SWEPCo had a net under-recovered fuel balance of $144 million, excluding impacts of the February 2021 severe winter weather event, which includes fuel consumed at the Pirkey Power Plant. Additional operational, reclamation and other land-related costs incurred by Sabine will be billed to SWEPCo and included in existing fuel clauses. If any of these costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. 2020 Texas Fuel Reconciliation (Applies to AEP and SWEPCo) In June 2020, SWEPCo filed a fuel reconciliation with the PUCT for its retail operations in Texas for the reconciliation period of March 1, 2017 to December 31, 2019. The fuel reconciliation included total fuel costs of $1.7 billion ($616 million of which is related to the Texas jurisdiction). In January 2021, various parties filed testimony recommending fuel cost disallowances totaling $125 million relating to the Texas jurisdiction. Also in January 2021, SWEPCo filed rebuttal testimony disputing the recommended disallowances. In February 2021, SWEPCo and various parties reached a settlement in principle which resulted in a $10 million reduction in recoverable fuel costs for the reconciliation period, which was recognized in SWEPCo’s 2020 financial statements. In November 2021, the settlement was approved by the PUCT. Regulatory Assets and Liabilities Regulatory assets and liabilities are comprised of the following items: AEP December 31, Remaining Recovery Period 2021 (a) 2020 Current Regulatory Assets (in millions) Under-recovered Fuel Costs - earns a return $ 409.4 $ 41.4 1 year Under-recovered Fuel Costs - does not earn a return 175.7 49.3 1 year Unrecovered Winter Storm Fuel Costs - earns a return (b) 62.7 — 1 year Total Current Regulatory Assets $ 647.8 $ 90.7 Noncurrent Regulatory Assets Regulatory assets pending final regulatory approval: Regulatory Assets Currently Earning a Return Unrecovered Winter Storm Fuel Costs $ 367.5 $ — Pirkey Power Plant Accelerated Depreciation 87.0 12.2 Dolet Hills Power Station Accelerated Depreciation 72.3 71.2 Welsh Plant, Units 1 and 3 Accelerated Depreciation 45.9 3.6 Plant Retirement Costs - Unrecovered Plant, Louisiana 35.2 35.2 Dolet Hills Power Station Fuel Costs - Louisiana 30.9 — Kentucky Deferred Purchased Power Expenses — 41.3 Oklaunion Power Station Accelerated Depreciation — 34.4 Other Regulatory Assets Pending Final Regulatory Approval 9.2 22.8 Total Regulatory Assets Currently Earning a Return 648.0 220.7 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 256.9 134.2 Plant Retirement Costs - Asset Retirement Obligation Costs 25.9 25.9 COVID-19 11.2 24.9 Other Regulatory Assets Pending Final Regulatory Approval 43.9 36.5 Total Regulatory Assets Currently Not Earning a Return 337.9 221.5 Total Regulatory Assets Pending Final Regulatory Approval 985.9 442.2 Regulatory assets approved for recovery: Regulatory Assets Currently Earning a Return Unrecovered Winter Storm Fuel Costs 679.3 — (c) Plant Retirement Costs - Unrecovered Plant (d) 522.2 713.1 25 years Rockport Plant Dry Sorbent Injection System and Selective Catalytic Reduction 66.6 34.4 7 years Meter Replacement Costs 44.9 55.5 6 years Ohio Distribution Decoupling 41.6 46.6 2 years Environmental Control Projects 36.2 38.6 19 years Cook Plant Uprate Project 27.7 30.2 12 years Storm-Related Costs 17.4 11.5 3 years Plant Retirement Costs - Asset Retirement Obligation Costs — 107.1 Other Regulatory Assets Approved for Recovery 99.2 94.4 various Total Regulatory Assets Currently Earning a Return 1,535.1 1,131.4 Regulatory Assets Currently Not Earning a Return Pension and OPEB Funded Status 677.0 1,088.6 12 years Plant Retirement Costs - Asset Retirement Obligation Costs 293.2 212.7 21 years Unamortized Loss on Reacquired Debt 111.2 120.0 27 years Unrealized Loss on Forward Commitments 100.8 111.3 11 years Plant Retirement Costs - Unrecovered Plant, Texas 51.9 16.1 25 years Peak Demand Reduction/Energy Efficiency 40.8 27.0 5 years Virginia Transmission Rate Adjustment Clause 37.2 18.8 2 years Cook Plant Nuclear Refueling Outage Levelization 32.0 39.5 3 years Texas Transmission Cost Recovery Factor 30.6 4.6 2 years Vegetation Management 29.3 67.8 4 years Postemployment Benefits 29.1 29.1 3 years PJM/SPP Annual Formula Rate True-up 17.6 33.0 2 years Fuel and Purchased Power Adjustment Rider 12.1 24.0 2 years OVEC Purchased Power — 27.4 Other Regulatory Assets Approved for Recovery 158.5 133.5 various Total Regulatory Assets Currently Not Earning a Return 1,621.3 1,953.4 Total Regulatory Assets Approved for Recovery 3,156.4 3,084.8 Total Noncurrent Regulatory Assets $ 4,142.3 $ 3,527.0 (a) 2021 amounts exclude $485 million of regulatory assets classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (b) Unrecovered Winter Storm Fuel Costs are pending final regulatory approval as of December 31, 2021. The current asset balance represents amounts expected to be recovered in the Arkansas and Louisiana jurisdictions over the next 12 months. See “February 2021 Severe Winter Weather Impacts in SPP” section of SWEPCo Rate Matters in Note 4 for additional information. (c) In February 2022, the OCC approved PSO’s securitization of the Unrecovered Winter Storm Fuel Costs. The timing of securitization is to be determined. See ”February 2021 Severe Winter Weather Impacts in SPP” section of PSO Rate Matters in Note 4 for additional information. (d) Northeastern Plant, Unit 3 is approved for recovery through 2040, but expected to retire in 2026. PSO records a regulatory asset for accelerated depreciation. See “Regulated Generating Units to be Retired” section above for additional information. AEP December 31, Remaining 2021 (a) 2020 Refund Period Current Regulatory Liabilities (in millions) Over-recovered Fuel Costs - pays a return $ — $ 27.6 Over-recovered Fuel Costs - does not pay a return 1.5 25.0 1 year Total Current Regulatory Liabilities $ 1.5 $ 52.6 Noncurrent Regulatory Liabilities and Regulatory liabilities pending final regulatory determination: Regulatory Liabilities Currently Paying a Return Other Regulatory Liabilities Pending Final Regulatory Determination $ — $ 2.5 Total Regulatory Liabilities Currently Paying a Return — 2.5 Regulatory Liabilities Currently Not Paying a Return Other Regulatory Liabilities Pending Final Regulatory Determination 0.2 1.5 Total Regulatory Liabilities Currently Not Paying a Return 0.2 1.5 Income Tax Related Regulatory Liabilities (b) Excess ADIT Associated with Certain Depreciable Property — 291.6 Excess ADIT that is Not Subject to Rate Normalization Requirements (c) (d) 262.2 193.3 Total Income Tax Related Regulatory Liabilities 262.2 484.9 Total Regulatory Liabilities Pending Final Regulatory Determination 262.4 488.9 Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs 3,172.1 3,061.9 (e) Deferred Investment Tax Credits 2.1 4.1 32 years Other Regulatory Liabilities Approved for Payment 33.1 25.2 various Total Regulatory Liabilities Currently Paying a Return 3,207.3 3,091.2 Regulatory Liabilities Currently Not Paying a Return Excess Nuclear Decommissioning Funding 1,939.7 1,476.6 (f) Deferred Investment Tax Credits 248.5 216.7 35 years Spent Nuclear Fuel 49.5 43.1 (f) PJM Transmission Enhancement Refund 42.9 56.2 4 years 2017-2019 Virginia Triennial Revenue Provision 41.6 44.2 27 years Unrealized Gain on Forward Commitments 37.2 11.7 3 years Peak Demand Reduction/Energy Efficiency 28.6 26.3 2 years Transition and Restoration Charges - Texas 26.3 48.2 8 years Other Regulatory Liabilities Approved for Payment 90.9 82.9 various Total Regulatory Liabilities Currently Not Paying a Return 2,505.2 2,005.9 Income Tax Related Regulatory Liabilities (b) Excess ADIT Associated with Certain Depreciable Property 3,556.7 3,485.7 (g) Excess ADIT that is Not Subject to Rate Normalization Requirements 386.5 714.9 7 years Income Taxes Subject to Flow Through (1,231.8) (1,407.9) 52 years Total Income Tax Related Regulatory Liabilities 2,711.4 2,792.7 Total Regulatory Liabilities Approved for Payment 8,423.9 7,889.8 Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits $ 8,686.3 $ 8,378.7 (a) 2021 amounts exclude $148 million of regulatory liabilities classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (b) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (c) 2021 and 2020 amounts include approximately $173 million and $173 million, respectively, related to AEP Transmission Holdco’s investment in ETT and Transource Energy. AEP Transmission Holdco expects to amortize the balance commensurate with the return of Excess ADIT to ETT and Transource Energy’s customers. (d) 2021 amount includes $70 million for Excess ADIT as a result of changes in various state income tax rates. See the “Federal and State Tax Legislation” section of Note 12 for additional information. (e) Relieved as removal costs are incurred. (f) Relieved when plant is decommissioned. (g) Refunded using ARAM. AEP Texas December 31, Remaining Regulatory Assets: 2021 2020 (in millions) Noncurrent Regulatory Assets Regulatory assets pending final regulatory approval: Regulatory Assets Currently Earning a Return Advanced Metering System $ — $ 16.3 Total Regulatory Assets Currently Earning a Return — 16.3 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 22.4 0.8 Vegetation Management Program 5.2 3.8 Texas Retail Electric Provider Bad Debt Expense 4.1 — COVID-19 2.1 10.5 Other Regulatory Assets Pending Final Regulatory Approval 7.4 1.5 Total Regulatory Assets Currently Not Earning a Return 41.2 16.6 Total Regulatory Assets Pending Final Regulatory Approval 41.2 32.9 Regulatory assets approved for recovery: Regulatory Assets Currently Earning a Return Meter Replacement Costs 22.7 29.3 5 years Advanced Metering System 10.6 — 1 year Other Regulatory Assets Approved for Recovery 2.1 — various Total Regulatory Assets Currently Earning a Return 35.4 29.3 Regulatory Assets Currently Not Earning a Return Pension and OPEB Funded Status 119.0 145.0 12 years Texas Transmission Cost Recovery Factor 30.6 4.6 2 years Vegetation Management Program 17.4 22.4 4 years Peak Demand Reduction/Energy Efficiency 14.5 7.7 2 years Storm-Related Costs 12.8 17.1 3 years Other Regulatory Assets Approved for Recovery 4.3 7.8 various Total Regulatory Assets Currently Not Earning a Return 198.6 204.6 Total Regulatory Assets Approved for Recovery 234.0 233.9 Total Noncurrent Regulatory Assets $ 275.2 $ 266.8 AEP Texas December 31, Remaining Regulatory Liabilities: 2021 2020 (in millions) Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits Regulatory liabilities pending final regulatory determination: Regulatory Liabilities Currently Paying a Return Other Regulatory Liabilities Pending Final Regulatory Determination $ — $ 2.5 Total Regulatory Liabilities Currently Paying a Return — 2.5 Income Tax Related Regulatory Liabilities (a) Excess ADIT that is Not Subject to Rate Normalization Requirements 13.0 (8.2) Total Income Tax Related Regulatory Liabilities 13.0 (8.2) Total Regulatory Liabilities Pending Final Regulatory Determination 13.0 (5.7) Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs 744.7 718.3 (b) Other Regulatory Liabilities Approved for Payment 4.8 5.3 various Total Regulatory Liabilities Currently Paying a Return 749.5 723.6 Regulatory Liabilities Currently Not Paying a Return Transition and Restoration Charges 26.3 48.2 8 years Deferred Investment Tax Credits 6.8 8.5 12 years Other Regulatory Liabilities Approved for Payment 1.1 1.2 various Total Regulatory Liabilities Currently Not Paying a Return 34.2 57.9 Income Tax Related Regulatory Liabilities (a) Excess ADIT Associated with Certain Depreciable Property 498.8 506.0 (c) Excess ADIT that is Not Subject to Rate Normalization Requirements — 41.7 Income Taxes Subject to Flow Through (53.5) (52.7) 35 years Total Income Tax Related Regulatory Liabilities 445.3 495.0 Total Regulatory Liabilities Approved for Payment 1,229.0 1,276.5 Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits $ 1,242.0 $ 1,270.8 (a) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (b) Relieved as removal costs are incurred. (c) Refunded using ARAM. AEPTCo December 31, Remaining Regulatory Assets: 2021 2020 (in millions) Noncurrent Regulatory Assets Regulatory assets approved for recovery: Regulatory Assets Currently Not Earning a Return PJM/SPP Annual Formula Rate True-up $ 8.5 $ 15.1 2 years Total Regulatory Assets Approved for Recovery 8.5 15.1 Total Noncurrent Regulatory Assets $ 8.5 $ 15.1 AEPTCo December 31, Remaining Regulatory Liabilities: 2021 (a) 2020 (in millions) Noncurrent Regulatory Liabilities Regulatory liabilities pending final regulatory determination: Income Tax Related Regulatory Liabilities (b) Excess ADIT that is Not Subject to Rate Normalization Requirements (c) $ 8.7 $ — Total Regulatory Liabilities Pending Final Regulatory Determination 8.7 — Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs 271.4 198.6 (d) Total Regulatory Liabilities Currently Paying a Return 271.4 198.6 Income Tax Related Regulatory Liabilities (b) Excess ADIT Associated with Certain Depreciable Property 522.6 531.5 (e) Excess ADIT that is Not Subject to Rate Normalization Requirements (26.2) (30.6) 7 years Income Taxes Subject to Flow Through (132.4) (117.7) 36 years Total Income Tax Related Regulatory Liabilities 364.0 383.2 Total Regulatory Liabilities Approved for Payment 635.4 581.8 Total Noncurrent Regulatory Liabilities $ 644.1 $ 581.8 (a) 2021 amounts exclude $8 million of regulatory liabilities classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (b) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (c) Amount represents regulatory liabilities for Excess ADIT as a result of changes in various state income tax rates. See the “Federal and State Tax Legislation” section of Note 12 for additional information. (d) Relieved as removal costs are incurred. (e) Refunded using ARAM. APCo December 31, Remaining Regulatory Assets: 2021 2020 (in millions) Current Regulatory Assets Under-recovered Fuel Costs - earns a return $ 127.2 $ 3.3 1 year Under-recovered Fuel Costs - does not earn a return 74.1 2.0 1 year Total Current Regulatory Assets $ 201.3 $ 5.3 Noncurrent Regulatory Assets Regulatory assets pending final regulatory approval: Regulatory Assets Currently Earning a Return COVID-19 - Virginia $ 6.8 $ 3.7 Total Regulatory Assets Currently Earning a Return 6.8 3.7 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 68.8 3.4 Plant Retirement Costs - Asset Retirement Obligation Costs 25.9 25.9 Environmental Expense Deferral - Virginia — 9.3 Other Regulatory Assets Pending Final Regulatory Approval 3.6 1.5 Total Regulatory Assets Currently Not Earning a Return 98.3 40.1 Total Regulatory Assets Pending Final Regulatory Approval 105.1 43.8 Regulatory assets approved for recovery: Regulatory Assets Currently Earning a Return Plant Retirement Costs - Unrecovered Plant 110.0 122.4 22 years Other Regulatory Assets Approved for Recovery 0.4 1.0 various Total Regulatory Assets Currently Earning a Return 110.4 123.4 Regulatory Assets Currently Not Earning a Return Plant Retirement Costs - Asset Retirement Obligation Costs 293.1 202.7 15 years Unamortized Loss on Reacquired Debt 78.2 82.1 24 years Pension and OPEB Funded Status 62.7 114.4 12 years Virginia Transmission Rate Adjustment Clause 37.2 18.8 2 years Peak Demand Reduction/Energy Efficiency 17.8 16.8 5 years Environmental Compliance Costs 13.7 — 2 years Postemployment Benefits 13.3 13.5 3 years Vegetation Management Program - West Virginia 11.9 45.4 2 years PJM Annual Formula Rate True-up 3.5 12.7 2 years Other Regulatory Assets Approved for Recovery 10.7 12.7 various Total Regulatory Assets Currently Not Earning a Return 542.1 519.1 Total Regulatory Assets Approved for Recovery 652.5 642.5 Total Noncurrent Regulatory Assets $ 757.6 $ 686.3 APCo December 31, Remaining Regulatory Liabilities: 2021 2020 (in millions) Noncurrent Regulatory Liabilities and Regulatory liabilities pending final regulatory determination: Income Tax Related Regulatory Liabilities (a) Excess ADIT that is Not Subject to Rate Normalization Requirements (b) $ 4.5 $ — Total Regulatory Liabilities Pending Final Regulatory Determination 4.5 — Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs 703.3 678.9 (c) Deferred Investment Tax Credits 0.3 0.3 32 years Total Regulatory Liabilities Currently Paying a Return 703.6 679.2 Regulatory Liabilities Currently Not Paying a Return 2017-2019 Virginia Triennial Revenue Provision 41.6 44.2 27 years Unrealized Gain on Forward Commitments 28.2 5.5 3 years PJM Transmission Enhancement Refund 13.0 16.3 4 years Other Regulatory Liabilities Approved for Payment 15.0 6.8 various Total Regulatory Liabilities Currently Not Paying a Return 97.8 72.8 Income Tax Related Regulatory Liabilities (a) Excess ADIT Associated with Certain Depreciable Property 663.6 690.0 (d) Excess ADIT that is Not Subject to Rate Normalization Requirements 83.6 139.1 7 years Income Taxes Subject to Flow Through (314.3) (356.4) 23 years Total Income Tax Related Regulatory Liabilities 432.9 472.7 Total Regulatory Liabilities Approved for Payment 1,234.3 1,224.7 Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits $ 1,238.8 $ 1,224.7 (a) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (b) Amount represents regulatory liabilities for Excess ADIT as a result of a change in the state income tax apportionment formula in West Virginia. See the “Federal and State Tax Legislation” section of Note 12 for additional information. (c) Relieved as removal costs are incurred. (d) Refunded using ARAM. I&M December 31, Remaining Regulatory Assets: 2021 2020 (in millions) Current Regulatory Assets Under-recovered Fuel Costs, Michigan - earns a return $ 6.4 $ 5.4 1 year Total Current Regulatory Assets $ 6.4 $ 5.4 Noncurrent Regulatory Assets Regulatory assets pending final regulatory approval: Regulatory Assets Currently Earning a Return Other Regulatory Assets Pending Final Regulatory Approval $ 0.1 $ 0.5 Total Regulatory Assets Currently Earning a Return 0.1 0.5 Regulatory Assets Currently Not Earning a Return COVID-19 1.7 3.8 Other Regulatory Assets Pending Final Regulatory Approval 1.9 — Total Regulatory Assets Currently Not Earning a Return (a) 3.6 3.8 Total Regulatory Assets Pending Final Regulatory Approval 3.7 4.3 Regulatory assets approved for recovery: Regulatory Assets Currently Earning a Return Plant Retirement Costs - Unrecovered Plant 170.8 191.5 7 years Rockport Plant Dry Sorbent Injection System and Selective Catalytic Reduction 66.6 34.4 7 years Cook Plant Uprate Project 27.7 30.2 12 years Deferred Cook Plant Life Cycle Management Project Costs 13.1 14.1 13 years Cook Plant Turbine 9.7 11.1 17 years Cook Plant Study Costs - Indiana 9.4 10.1 14 years Other Regulatory Assets Approved for Recovery 6.0 7.0 various Total Regulatory Assets Currently Earning a Return 303.3 298.4 Regulatory Assets Currently Not Earning a Return Cook Plant Nuclear Refueling Outage Levelization 32.0 39.5 3 years PJM Costs and Off-system Sales Margin Sharing - Indiana 15.1 — 2 years Unamortized Loss on Reacquired Debt 14.2 15.7 27 years Storm-Related Costs - Indiana 12.6 0.3 2 years Postemployment Benefits 9.0 4.9 3 years Unrealized Loss on Forward Commitments 7.2 — 3 years Pension and OPEB Funded Status — 25.7 Other Regulatory Assets Approved for Recovery 13.8 16.0 various Total Regulatory Assets Currently Not Earning a Return 103.9 102.1 Total Regulatory Assets Approved for Recovery 407.2 400.5 Total Noncurrent Regulatory Assets $ 410.9 $ 404.8 (a) In February 2022, the IURC issued an order approving Indiana jurisdictional COVID-19 costs and certain other regulatory assets totaling $3 million. See “2021 Indiana Base Rate Case” section of Note 4 for additional information. I&M December 31, Remaining Regulatory Liabilities: 2021 2020 (in millions) Current Regulatory Liabilities Over-recovered Fuel Costs, Indiana - does not pay a return $ 1.5 $ 20.8 1 year Total Current Regulatory Liabilities $ 1.5 $ 20.8 Noncurrent Regulatory Liabilities and Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs $ 179.7 $ 168.2 (a) Other Regulatory Liabilities Approved for Payment 21.9 17.4 various Total Regulatory Liabilities Currently Paying a Return 201.6 185.6 Regulatory Liabilities Currently Not Paying a Return Excess Nuclear Decommissioning Funding 1,939.7 1,476.6 (b) Spent Nuclear Fuel 49.5 43.1 (b) Pension OPEB Funded Status 27.6 — 12 years Deferred Investment Tax Credits 22.4 21.3 29 years Rockport Plant, Unit 2 Selective Catalytic Reduction 10.6 8.9 2 years PJM Transmission Enhancement Refund 7.9 9.9 4 years PJM Costs and Off-system Sales Margin Sharing - Indiana — 13.3 Other Regulatory Liabilities Approved for Payment 6.0 28.4 various Total Regulatory Liabilities Currently Not Paying a Return 2,063.7 1,601.5 Income Tax Related Regulatory Liabilities (c) Excess ADIT Associated with Certain Depreciable Property 433.6 450.6 (d) Excess ADIT that is Not Subject to Rate Normalization Requirements 90.2 136.2 3 years Income Taxes Subject to Flow Through (341.2) (332.0) 20 years Total Income Tax Related Regulatory Liabilities 182.6 254.8 Total Regulatory Liabilities Approved for Payment 2,447.9 2,041.9 Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits $ 2,447.9 $ 2,041.9 (a) Relieved as removal costs are incurred. (b) Relieved when plant is decommissioned. (c) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (d) Refunded using ARAM. OPCo December 31, Remaining Regulatory Assets: 2021 2020 (in millions) Noncurrent Regulatory Assets Regulatory assets pending final regulatory approval: Regulatory Assets Currently Not Earning a Return Storm-Related Costs $ 3.8 $ 4.0 COVID-19 — 4.4 Total Regulatory Assets Pending Final Regulatory Approval 3.8 8.4 Regulatory assets approved for recovery: Regulatory Assets Currently Earning a Return Ohio Distribution Decoupling 41.6 46.6 2 years Ohio Economic Development Rider 10.1 1.3 2 years Ohio Basic Transmission Cost Rider 5.2 12.3 2 years Total Regulatory Assets Currently Earning a Return 56.9 60.2 Regulatory Assets Currently Not Earning a Return Unrealized Loss on Forward Commitments 92.1 110.0 11 years Pension and OPEB Funded Status 83.3 130.7 12 years Smart Grid Costs 19.3 19.2 2 years Ohio Enhanced Service Reliability Plan 9.5 — 2 years PJM Load Service Entity Formula Rate True-up 7.5 — 2 years Postemployment Benefits 6.2 6.7 3 years Distribution Investment Rider 2.1 7.4 2 years OVEC Purchased Power — 27.4 Other Regulatory Assets Approved for Recovery 12.3 15.8 various Total Regulatory Assets Currently Not Earning a Return 232.3 317.2 Total Regulatory Assets Approved for Recovery 289.2 377.4 Total Noncurrent Regula

Commitments, Guarantees and Con

Commitments, Guarantees and Contingencies	12 Months Ended
Commitments, Guarantees and Contingencies	Dec. 31, 2021
Commitments, Guarantees and Contingencies	COMMITMENTS, GUARANTEES AND CONTINGENCIES The disclosures in this note apply to all Registrants unless indicated otherwise. The Registrants are subject to certain claims and legal actions arising in the ordinary course of business. In addition, the Registrants’ business activities are subject to extensive governmental regulation related to public health and the environment. The ultimate outcome of such pending or potential litigation against the Registrants cannot be predicted. Management accrues contingent liabilities only when management concludes that it is both probable that a liability has been incurred at the date of the financial statements and the amount of loss can be reasonably estimated. When management determines that it is not probable, but rather reasonably possible that a liability has been incurred at the date of the financial statements, management discloses such contingencies and the possible loss or range of loss if such estimate can be made. Any estimated range is based on currently available information and involves elements of judgment and significant uncertainties. Any estimated range of possible loss may not represent the maximum possible loss exposure. Circumstances change over time and actual results may vary significantly from estimates. For current proceedings not specifically discussed below, management does not anticipate that the liabilities, if any, arising from such proceedings would have a material effect on the financial statements. COMMITMENTS (Applies to all Registrants except AEP Texas and AEPTCo) The AEP System has substantial commitments for fuel, energy and capacity contracts as part of the normal course of business. Certain contracts contain penalty provisions for early termination. In accordance with the accounting guidance for “Commitments”, the following tables summarize the Registrants’ actual contractual commitments as of December 31, 2021: Contractual Commitments - AEP Less Than 2-3 Years 4-5 Years After Total (in millions) Fuel Purchase Contracts (a)(b)(c) $ 706.4 $ 584.9 $ 167.8 $ 301.8 $ 1,760.9 Energy and Capacity Purchase Contracts 147.8 309.5 291.7 664.4 1,413.4 Total $ 854.2 $ 894.4 $ 459.5 $ 966.2 $ 3,174.3 Contractual Commitments - APCo Less Than 2-3 Years 4-5 Years After Total (in millions) Fuel Purchase Contracts (a)(c) $ 266.9 $ 171.8 $ 18.7 $ 18.4 $ 475.8 Energy and Capacity Purchase Contracts 40.4 81.8 80.4 150.0 352.6 Total $ 307.3 $ 253.6 $ 99.1 $ 168.4 $ 828.4 Contractual Commitments - I&M Less Than 2-3 Years 4-5 Years After Total (in millions) Fuel Purchase Contracts (a) $ 147.7 $ 245.7 $ 149.1 $ 283.3 $ 825.8 Energy and Capacity Purchase Contracts 167.2 212.6 203.3 305.9 889.0 Total $ 314.9 $ 458.3 $ 352.4 $ 589.2 $ 1,714.8 Contractual Commitments - OPCo Less Than 2-3 Years 4-5 Years After Total (in millions) Energy and Capacity Purchase Contracts $ 34.6 $ 69.1 $ 65.4 $ 180.0 $ 349.1 Contractual Commitments - PSO Less Than 2-3 Years 4-5 Years After Total (in millions) Fuel Purchase Contracts (a) $ 48.2 $ 23.0 $ — $ — $ 71.2 Energy and Capacity Purchase Contracts 32.2 67.3 67.9 125.9 293.3 Total $ 80.4 $ 90.3 $ 67.9 $ 125.9 $ 364.5 Contractual Commitments - SWEPCo Less Than 2-3 Years 4-5 Years After Total (in millions) Fuel Purchase Contracts (a) $ 158.8 $ 91.3 $ — $ — $ 250.1 Energy and Capacity Purchase Contracts 4.2 8.4 8.4 — 21.0 Total $ 163.0 $ 99.7 $ 8.4 $ — $ 271.1 (a) Represents contractual commitments to purchase coal, natural gas, uranium and other consumables as fuel for electric generation along with related transportation of the fuel. (b) Includes $22 million of purchase fuel contracts for KPCo commitments that are expected to occur prior to the anticipated closing of the sale transaction in the second quarter of 2022. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (c) In the first quarter of 2022, APCo entered into new fuel purchase contracts related to coal procurement. The new commitments were as follows: $95 million in less than 1 year, $449 million in 2-3 years and $96 million in 4-5 years. These commitments are not included in the tables above. All other new commitments in the first quarter of 2022 were immaterial. GUARANTEES Liabilities for guarantees are recorded in accordance with the accounting guidance for “Guarantees.” There is no collateral held in relation to any guarantees. In the event any guarantee is drawn, there is no recourse to third-parties unless specified below. Letters of Credit (Applies to AEP and AEP Texas) Standby letters of credit are entered into with third-parties. These letters of credit are issued in the ordinary course of business and cover items such as natural gas and electricity risk management contracts, construction contracts, insurance programs, security deposits and debt service reserves. AEP has $4 billion and $1 billion revolving credit facilities due in March 2026 and 2023, respectively, under which up to $1.2 billion may be issued as letters of credit on behalf of subsidiaries. As of December 31, 2021, no letters of credit were issued under the revolving credit facility. An uncommitted facility gives the issuer of the facility the right to accept or decline each request made under the facility. AEP issues letters of credit on behalf of subsidiaries under five uncommitted facilities totaling, as of December 31, 2021, $375 million. Subsequently, in February 2022, the uncommitted facilities total was increased to $400 million. The Registrants’ maximum future payments for letters of credit issued under the uncommitted facilities as of December 31, 2021 were as follows: Company Amount Maturity (in millions) AEP $ 168.5 January 2022 to December 2022 AEP Texas 2.2 July 2022 Guarantees of Equity Method Investees (Applies to AEP) In 2019, AEP acquired Sempra Renewables LLC. The transaction resulted in the acquisition of a 50% ownership interest in five non-consolidated joint ventures and the acquisition of two tax equity partnerships. Parent has issued guarantees over the performance of the joint ventures. If a joint venture were to default on payments or performance, Parent would be required to make payments on behalf of the joint venture. As of December 31, 2021, the maximum potential amount of future payments associated with these guarantees was $142 million, with the last guarantee expiring in December 2037. The non-contingent liability recorded associated with these guarantees was $28 million, with an additional $2 million expected credit loss liability for the contingent portion of the guarantees. Management considered historical losses, economic conditions, and reasonable and supportable forecasts in the calculation of the expected credit loss. As the joint ventures generate cash flows through PPAs, the measurement of the contingent portion of the guarantee liability is based upon assessments of the credit quality and default probabilities of the respective PPA counterparties. See “Acquisitions” section of Note 7 for additional information. Indemnifications and Other Guarantees Contracts The Registrants enter into certain types of contracts which require indemnifications. Typically these contracts include, but are not limited to, sale agreements, lease agreements, purchase agreements and financing agreements. Generally, these agreements may include, but are not limited to, indemnifications around certain tax, contractual and environmental matters. With respect to sale agreements, exposure generally does not exceed the sale price. As of December 31, 2021, there were no material liabilities recorded for any indemnifications. AEPSC conducts power purchase-and-sale activity on behalf of APCo, I&M, KPCo and WPCo, who are jointly and severally liable for activity conducted on their behalf. AEPSC also conducts power purchase-and-sale activity on behalf of PSO and SWEPCo, who are jointly and severally liable for activity conducted on their behalf. Lease Obligations Certain Registrants lease equipment under master lease agreements. See “Master Lease Agreements” and “AEPRO Boat and Barge Leases” sections of Note 13 for additional information. ENVIRONMENTAL CONTINGENCIES (Applies to All Registrants except AEPTCo) The Comprehensive Environmental Response Compensation and Liability Act (Superfund) and State Remediation By-products from the generation of electricity include materials such as ash, slag, sludge, low-level radioactive waste and SNF. Coal combustion by-products, which constitute the overwhelming percentage of these materials, are typically treated and deposited in captive disposal facilities or are beneficially utilized. In addition, the generation plants and transmission and distribution facilities have used asbestos, polychlorinated biphenyls and other hazardous and non-hazardous materials. The Registrants currently incur costs to dispose of these substances safely. Superfund addresses clean-up of hazardous substances that are released to the environment. The Federal EPA administers the clean-up programs. Several states enacted similar laws. As of December 31, 2021, APCo, OPCo and SWEPCo are named as a Potentially Responsible Party (PRP) for one, three and one sites, respectively, by the Federal EPA for which alleged liability is unresolved. There are 11 additional sites for which APCo, I&M, KPCo, OPCo and SWEPCo received information requests which could lead to PRP designation. I&M has also been named potentially liable at three sites under state law. In those instances where a PRP or defendant has been named, disposal or recycling activities were in accordance with the then-applicable laws and regulations. Superfund does not recognize compliance as a defense, but imposes strict liability on parties who fall within its broad statutory categories. Liability has been resolved for a number of sites with no significant effect on net income. Management evaluates the potential liability for each Superfund site separately, but several general statements can be made about potential future liability. Allegations that materials were disposed at a particular site are often unsubstantiated and the quantity of materials deposited at a site can be small and often non-hazardous. Although Superfund liability has been interpreted by the courts as joint and several, typically many parties are named as PRPs for each site and several of the parties are financially sound enterprises. As of December 31, 2021, management’s estimates do not anticipate material clean-up costs for identified Superfund sites. NUCLEAR CONTINGENCIES (APPLIES TO AEP AND I&M) I&M owns and operates the two-unit 2,296 MW Cook Plant under licenses granted by the NRC. I&M has a significant future financial commitment to dispose of SNF and to safely decommission and decontaminate the plant. The licenses to operate the two nuclear units at the Cook Plant expire in 2034 and 2037. The operation of a nuclear facility also involves special risks, potential liabilities and specific regulatory and safety requirements. By agreement, I&M is partially liable, together with all other electric utility companies that own nuclear generation units, for a nuclear power plant incident at any nuclear plant in the U.S. Should a nuclear incident occur at any nuclear power plant in the U.S., the resultant liability could be substantial. Decommissioning and Low-Level Waste Accumulation Disposal The costs to decommission a nuclear plant are affected by NRC regulations and the SNF disposal program. Decommissioning costs are accrued over the service life of Cook Plant. The most recent decommissioning cost study was performed in 2021. According to that study, the estimated cost of decommissioning and disposal of low-level radioactive waste was $2.2 billion in 2021 non-discounted dollars, with additional ongoing costs of $7 million per year for post decommissioning storage of SNF and an eventual cost of $33 million for the subsequent decommissioning of the SNF storage facility, also in 2021 non-discounted dollars. I&M recovers estimated decommissioning costs for the Cook Plant in its rates. The amounts recovered in rates were $4 million, $4 million and $7 million for the years ended December 31, 2021, 2020 and 2019, respectively. Decommissioning costs recovered from customers are deposited in external trusts. As of December 31, 2021 and 2020, the total decommissioning trust fund balances were $3.5 billion and $3 billion, respectively. Trust fund earnings increase the fund assets and decrease the amount remaining to be recovered from customers. The decommissioning costs (including unrealized gains and losses, interest and trust funds expenses) increase or decrease the recorded liability. I&M continues to work with regulators and customers to recover the remaining estimated costs of decommissioning the Cook Plant. However, future net income and cash flows would be reduced and financial condition could be impacted if the cost of SNF disposal and decommissioning continues to increase and cannot be recovered. Spent Nuclear Fuel Disposal The federal government is responsible for permanent SNF disposal and assesses fees to nuclear plant owners for SNF disposal. A fee of one-mill per KWh for fuel consumed after April 6, 1983 at the Cook Plant was collected from customers and remitted to the DOE through May 14, 2014. In May 2014, pursuant to court order from the U.S Court of Appeals for the District of Columbia Circuit, the DOE adjusted the fee to $0. As of December 31, 2021 and 2020, fees and related interest of $281 million and $281 million, respectively, for fuel consumed prior to April 7, 1983 were recorded as Long-term Debt and funds collected from customers along with related earnings totaling $329 million and $324 million, respectively, to pay the fee were recorded as part of Spent Nuclear Fuel and Decommissioning Trusts on the balance sheets. I&M has not paid the government the pre-April 1983 fees due to continued delays and uncertainties related to the federal disposal program. In 2011, I&M signed a settlement agreement with the federal government which permits I&M to make annual filings to recover certain SNF storage costs incurred as a result of the government’s delay in accepting SNF for permanent storage. Under the settlement agreement, I&M received $14 million, $24 million and $8 million in 2021, 2020 and 2019, respectively, to recover costs and will be eligible to receive additional payment of annual claims for allowed costs that are incurred through December 31, 2022. The proceeds reduced costs for dry cask storage. As of December 31, 2021 and 2020, I&M deferred $3 million and $14 million, respectively, in Prepayments and Other Current Assets and $21 million and $1 million, respectively, in Deferred Charges and Other Noncurrent Assets on the balance sheets for dry cask storage and related operation and maintenance costs for recovery under this agreement. See “Fair Value Measurements of Trust Assets for Decommissioning and SNF Disposal” section of Note 11 for additional information. Nuclear Insurance I&M carries nuclear property insurance of $2.7 billion to cover a nuclear incident at Cook Plant including coverage for decontamination and stabilization, as well as premature decommissioning caused by a nuclear incident. Insurance coverage for a nonnuclear property incident at Cook Plant is $500 million. Additional insurance provides coverage for a weekly indemnity payment resulting from an insured accidental outage. I&M utilizes industry mutual insurers for the placement of this insurance coverage. Coverage from these industry mutual insurance programs require a contingent financial obligation of up to $42 million for I&M, which is assessable if the insurer’s financial resources would be inadequate to pay for industry losses. The Price-Anderson Act, extended through December 31, 2025, establishes insurance protection for public nuclear liability arising from a nuclear incident of $13.5 billion and applies to any incident at a licensed reactor in the U.S. Commercially available insurance, which must be carried for each licensed reactor, provides $450 million of primary coverage. In the event of a nuclear incident at any nuclear plant in the U.S., the remainder of the liability would be provided by a deferred premium assessment of $275 million per nuclear incident on Cook Plant’s reactors payable in annual installments of $41 million. The number of incidents for which payments could be required is not limited. In the event of an incident of a catastrophic nature, I&M is covered for public nuclear liability for the first $450 million through commercially available insurance. The next level of liability coverage of up to $13.1 billion would be covered by claim premium assessments made under the Price-Anderson Act. In the event nuclear losses or liabilities are underinsured or exceed accumulated funds, I&M would seek recovery of those amounts from customers through a rate increase. If recovery from customers is not possible, it could reduce future net income and cash flows and impact financial condition. OPERATIONAL CONTINGENCIES Insurance and Potential Losses The Registrants maintain insurance coverage normal and customary for electric utilities, subject to various deductibles. The Registrants also maintain property and casualty insurance that may cover certain physical damage or third-party injuries caused by cyber security incidents. Insurance coverage includes all risks of physical loss or damage to nonnuclear assets, subject to insurance policy conditions and exclusions. Covered property generally includes power plants, substations, facilities and inventories. Excluded property generally includes transmission and distribution lines, poles and towers. The insurance programs also generally provide coverage against loss arising from certain claims made by third-parties and are in excess of retentions absorbed by the Registrants. Coverage is generally provided by a combination of the protected cell of EIS and/or various industry mutual and/or commercial insurance carriers. See “Nuclear Contingencies” section above for additional information. Some potential losses or liabilities may not be insurable or the amount of insurance carried may not be sufficient to meet potential losses and liabilities, including, but not limited to, liabilities relating to a cyber security incident or damage to the Cook Plant and costs of replacement power in the event of an incident at the Cook Plant. Future losses or liabilities, if they occur, which are not completely insured, unless recovered from customers, could reduce future net income and cash flows and impact financial condition. Rockport Plant Litigation (Applies to AEP and I&M) In 2013, the Wilmington Trust Company filed suit in the U.S. District Court for the Southern District of New York against AEGCo and I&M alleging that it would be unlawfully burdened by the terms of the modified NSR consent decree after the Rockport Plant, Unit 2 lease expiration in December 2022. The terms of the consent decree allow the installation of environmental emission control equipment, repowering, refueling or retirement of the unit. The plaintiffs sought a judgment declaring that the defendants breached the lease, must satisfy obligations related to installation of emission control equipment and indemnify the plaintiffs. After the litigation proceeded at the district court and appellate court, in April 2021, I&M and AEGCo reached an agreement to acquire 100% of the interests in Rockport Plant, Unit 2 for $116 million from certain financial institutions that own the unit through trusts established by Wilmington Trust, the nonaffiliated owner trustee of the ownership interests in the unit, with closing to occur as of the end of the Rockport Plant, Unit 2 lease in December 2022. The agreement is subject to customary closing conditions, including regulatory approvals and as of the closing will result in a final settlement of, and release of claims in, the lease litigation. As a result, in May 2021, at the parties’ request, the district court entered a stipulation and order dismissing the case without prejudice to plaintiffs asserting their claims in a re-filed action or a new action. The required regulatory approvals at the IURC and FERC have been obtained that would allow the closing to occur as of the end of the lease in December 2022. The IURC order approved a settlement agreement addressing the future use of Rockport Plant, Unit 2 as a capacity and energy resource and associated adjustments to I&M’s Indiana retail rates, along with certain other matters. Management believes its financial statements appropriately reflect the resolution of the litigation. See “Rockport Lease section of Note 13 for additional information. Claims Challenging Transition of American Electric Power System Retirement Plan to Cash Balance Formula Four participants in The American Electric Power System Retirement Plan (the Plan) filed a class action complaint in December 2021 in the U.S. District Court for the Southern District of Ohio against AEPSC and the Plan. When the Plan’s benefit formula was changed in the year 2000, AEP provided a special provision for employees hired before January 1, 2001, allowing them to continue benefit accruals under the then benefit formula for a full 10 years alongside of the new cash balance benefit formula then being implemented. Employees who were hired on or after January 1, 2001 accrued benefits only under the new cash balance benefit formula. The Plaintiffs assert a number of claims on behalf of themselves and the purported class, including that: (a) the Plan violates the requirements under the Employee Retirement Income Security Act (ERISA) intended to preclude back-loading the accrual of benefits to the end of a participant’s career, (b) the Plan violates the age discrimination prohibitions of ERISA and the Age Discrimination in Employment Act and (c) AEP failed to provide required notice regarding the changes to the Plan. Among other relief, the Complaint seeks reformation of the Plan to provide additional benefits and the recovery of plan benefits for former employees under such reformed plan. The Plaintiffs previously had submitted claims for additional plan benefits to AEP, which were denied. On February 15, 2022, AEPSC and the Plan filed a motion to dismiss the complaint for failure to state a claim. AEP will continue to defend against the claims. Management is unable to determine a range of potential losses that is reasonably possible of occurring. Litigation Related to Ohio House Bill 6 (HB 6) (Applies to AEP and OPCo) In 2019, Ohio adopted and implemented HB 6 which benefits OPCo by authorizing rate recovery for certain costs including renewable energy contracts and OVEC’s coal-fired generating units. OPCo engaged in lobbying efforts and provided testimony during the legislative process in connection with HB 6. In July 2020, an investigation led by the U.S. Attorney’s Office resulted in a federal grand jury indictment of an Ohio legislator and associates in connection with an alleged racketeering conspiracy involving the adoption of HB 6. After AEP learned of the criminal allegations against the Ohio legislator and others relating to HB 6, AEP, with assistance from outside advisors, conducted a review of the circumstances surrounding the passage of the bill. Management does not believe that AEP was involved in any wrongful conduct in connection with the passage of HB 6. In August 2020, an AEP shareholder filed a putative class action lawsuit in the United States District Court for the Southern District of Ohio against AEP and certain of its officers for alleged violations of securities laws. The amended complaint alleged misrepresentations or omissions by AEP regarding: (a) its alleged participation in or connection to public corruption with respect to the passage of HB 6 and (b) its regulatory, legislative, political contribution, 501(c)(4) organization contribution and lobbying activities in Ohio. The complaint sought monetary damages, among other forms of relief. In December 2021, the District Court issued an opinion and order dismissing the securities litigation complaint with prejudice, determining that the complaint fails to plead any actionable misrepresentations or omissions. The plaintiffs did not appeal the ruling. In January 2021, an AEP shareholder filed a derivative action in the United States District Court for the Southern District of Ohio purporting to assert claims on behalf of AEP against certain AEP officers and directors. In February 2021, a second AEP shareholder filed a similar derivative action in the Court of Common Pleas of Franklin County, Ohio. In April 2021, a third AEP shareholder filed a similar derivative action in the U.S. District Court for the Southern District of Ohio and a fourth AEP shareholder filed a similar derivative action in the Supreme Court for the State of New York, Nassau County. These derivative complaints allege the officers and directors made misrepresentations and omissions similar to those alleged in the putative securities class action lawsuit filed against AEP. The derivative complaints together assert claims for: (a) breach of fiduciary duty, (b) waste of corporate assets, (c) unjust enrichment, (d) breach of duty for insider trading and (e) contribution for violations of sections 10(b) and 21D of the Securities Exchange Act of 1934; and seek monetary damages and changes to AEP’s corporate governance and internal policies among other forms of relief. The New York state court derivative action is stayed. The Ohio state court derivative action was stayed until February 18, 2022, and the parties to that case filed a stipulation seeking to extend the stay. The two derivative actions pending in federal court have been consolidated, and the parties to the consolidated action have filed a joint motion for the court to enter a scheduling order pursuant to which plaintiffs will file an amended complaint and the parties will then propose a briefing schedule for defendants’ motion to dismiss the amended complaint. The defendants will continue to defend against the claims. Management is unable to determine a range of potential losses that is reasonably possible of occurring. In March 2021, AEP received a litigation demand letter from counsel representing a purported AEP shareholder. The litigation demand letter is directed to the Board of Directors of AEP and contains factual allegations involving HB 6 that are generally consistent with those in the derivative litigation filed in state and federal court. The letter demands, among other things, that the AEP Board undertake an independent investigation into alleged legal violations by directors and officers, and that, following such investigation, AEP commence a civil action for breaches of fiduciary duty and related claims and take appropriate disciplinary action against those individuals who allegedly harmed the company. The shareholder that sent the letter has agreed that AEP and the AEP Board may defer consideration of the litigation demand until the resolution of the motion to dismiss the securities litigation. The AEP Board will act in response to the letter as appropriate. Management is unable to determine a range of potential losses that is reasonably possible of occurring. In May 2021, AEP received a subpoena from the SEC’s Division of Enforcement seeking various documents, including documents relating to the benefits to AEP from the passage of HB 6 and documents relating to AEP’s financial processes and controls. AEP is cooperating fully with the SEC’s subpoena. Although the outcome of the SEC’s investigation cannot be predicted, management does not believe the results of this inquiry will have a material impact on our financial condition, results of operations, or cash flows.

Acquisitions, Assets and Liabil

Acquisitions, Assets and Liabilities Held for Sale, Dispositions and Impairments	12 Months Ended
	Dec. 31, 2021
Mergers, Acquisitions and Dispositions Disclosures	ACQUISITIONS, ASSETS AND LIABILITIES HELD FOR SALE, DISPOSITIONS, AND IMPAIRMENTS The disclosures in this note apply to AEP unless indicated otherwise. ACQUISITIONS 2021 Dry Lake Solar Project (Generation & Marketing Segment) (Applies to AEP) In November 2020, AEP signed a Purchase and Sale Agreement with a nonaffiliate to acquire a 75% ownership interest in the entity that owns the 100 MW Dry Lake Solar Project (collectively referred to as Dry Lake) located in southern Nevada for approximately $114 million. In March 2021, AEP closed the transaction and the solar project was placed in-service in May 2021. Approximately $103 million of the purchase price was paid upon closing of the transaction and the remaining $11 million was paid when the project was placed in-service. In accordance with the accounting guidance for “Business Combinations,” management determined that the acquisition of Dry Lake represents an asset acquisition. Additionally, and in accordance with the accounting guidance for “Consolidation,” management concluded that Dry Lake is a VIE and that AEP is the primary beneficiary based on its power as managing member to direct the activities that most significantly impact Dry Lake’s economic performance. As the primary beneficiary of Dry Lake, AEP consolidates Dry Lake into its financial statements. As a result, to account for the initial consolidation of Dry Lake, management applied the acquisition method by allocating the purchase price based on the relative fair value of the assets acquired and noncontrolling interest assumed. The fair value of the primary assets acquired and the noncontrolling interest assumed was determined using the market approach. The key input assumptions were the transaction price paid for AEP’s interest in Dry Lake and recent third-party market transactions for similar solar generation facilities. See Note 17 - Variable Interest Entities and Equity Method Investments for additional information. North Central Wind Energy Facilities (Vertically Integrated Utilities Segment) (Applies to AEP, PSO and SWEPCo) In 2020, PSO and SWEPCo received regulatory approvals to acquire the NCWF, comprised of three Oklahoma wind facilities totaling 1,484 MWs, on a fixed cost turn-key basis at completion. PSO and SWEPCo will own undivided interests of 45.5% and 54.5% of the NCWF, respectively. In total, the three wind facilities will cost approximately $2 billion and consist of Traverse (998 MW), Maverick (287 MW) and Sundance (199 MW). Output from the NCWF will serve retail load in PSO’s Oklahoma service territory and both retail and FERC wholesale load in SWEPCo’s service territories in Arkansas and Louisiana. The Oklahoma and Louisiana portions of the NCWF revenue requirement, net of PTC benefit, are recoverable through authorized riders beginning at commercial operation and until such time as amounts are reflected in base rates. Recovery of the Arkansas portion of the NCWF revenue requirement is requested in SWEPCo’s pending 2021 Arkansas Base Rate Case. The NCWF are subject to various regulatory performance requirements. If these performance requirements are not met, PSO and SWEPCo would recognize a regulatory liability to refund retail customers. As of December 31, 2021 PSO and SWEPCo have not incurred a material regulatory liability related to performance requirements for NCWF. In April 2021, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Sundance during its development and construction for $270 million, the first of the three NCWF acquisitions. Immediately following the acquisition, PSO and SWEPCo liquidated the entity and simultaneously distributed the Sundance assets in proportion to their undivided ownership interests. Sundance was placed in-service in April 2021. In September 2021, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Maverick during its development and construction for $383 million, the second of the three NCWF acquisitions. Immediately following the acquisition, PSO and SWEPCo liquidated the entity and simultaneously distributed the Maverick assets in proportion to their undivided ownership interests. Maverick was placed in-service in September 2021. In accordance with the guidance for “Business Combinations,” management determined that the acquisitions of Sundance and Maverick represent asset acquisitions. As of December 31, 2021, PSO and SWEPCo had approximately $316 million and $378 million, of gross Property, Plant and Equipment on the balance sheets, respectively, related to the Sundance and Maverick NCWF projects. On an ongoing basis, management further determined that PSO and SWEPCo should apply the joint plant accounting model to account for their respective undivided interests in the assets, liabilities, revenues and expenses of Sundance and Maverick. The Purchase and Sale Agreement (PSA) includes collective interests in numerous land contracts, as originally executed between the nonaffiliated party and the respective owners of the properties as defined in the contracts. These contracts provide for easement and access rights to the land that Sundance and Maverick were built upon. These interests as lessee in each of the land contracts were transferred to Sundance and Maverick (and subsequently to PSO and SWEPCo) as a part of the closing of the PSA. As of December 31, 2021, the Noncurrent Obligations Under Operating Leases for Sundance are $13 million and $15 million on the balance sheets for PSO and SWEPCo, respectively, and the Noncurrent Obligations Under Operating Leases for Maverick are $18 million and $22 million on the balance sheets for PSO and SWEPCo, respectively. 2020 Desert Sky Wind Farm and Trent Wind Farm (Generation & Marketing Segment) (Applies to AEP) In August 2020, AEP exercised its call right which required the nonaffiliated member of Desert Sky Wind Farm LLC and Trent Wind Farm LLC (collectively the LLCs) to sell its noncontrolling interest to AEP. The exercise price for the call right was determined using a discounted cash flow model with agreed input assumptions as well as updates to certain assumptions reasonably expected based on the actual results of the LLCs. As a result, the LLCs are wholly-owned by AEP and management has concluded that the LLCs are no longer VIEs. AEP paid $57 million in cash, derecognized $63 million of Redeemable Noncontrolling Interest within Mezzanine Equity and recorded an increase of $6 million of Paid-In Capital on the balance sheets. See Note 17 - Variable Interest Entities and Equity Method Investments for additional information. Santa Rita East (Generation & Marketing Segment) (Applies to AEP) In November 2020, AEP acquired an additional 10% interest in Santa Rita East for approximately $44 million resulting in AEP having a total interest of 85%. The acquisition of the incremental ownership interest was accounted for as an equity transaction in accordance with the accounting guidance for "Consolidation" and reduced Noncontrolling Interests on the balance sheets by approximately $44 million. See Note 17 - Variable Interest Entities and Equity Method Investments for additional information. 2019 Sempra Renewables LLC (Generation & Marketing Segment) (Applies to AEP) In April 2019, AEP acquired Sempra Renewables LLC and its ownership interests in 724 MWs of wind generation and battery assets valued at approximately $1.1 billion. This acquisition is part of AEP’s strategy to grow its renewable generation portfolio and to diversify generation resources. AEP paid $580 million in cash and acquired a 50% ownership interest in five non-consolidated joint ventures with net assets valued at $404 million as of the acquisition date (which includes $364 million of existing debt obligations). Additionally, the transaction included the acquisition of two tax equity partnerships and the associated recognition of noncontrolling tax equity interest of $135 million. Purchase Price Allocation of Sempra Renewables LLC at Acquisition Date - April 22nd, 2019 Assets: Liabilities and Equity: Net Purchase Price (in millions) Current Assets $ 8.8 Current Liabilities $ 12.9 Property, Plant and Equipment 238.1 Asset Retirement Obligations 5.7 Investment in Joint Ventures 404.0 Total Liabilities 18.6 Other Noncurrent Assets 82.9 Noncontrolling Interest 134.8 Total Assets $ 733.8 Liabilities and Noncontrolling Interest $ 153.4 $ 580.4 Management allocated the purchase price based upon the fair value of the assets acquired and noncontrolling interests assumed. The fair value of the primary assets acquired and the noncontrolling interests assumed was determined using a discounted cash flow method under the income approach. The key input assumptions utilized in the determination of the fair value of these assets were the pricing and terms of the existing PPAs, forecasted market power prices, expected wind farm net capacity and discount rates reflecting risk inherent in the future cash flows and future power prices. Estimating forecasted market power prices involved determining the cost of constructing and operating a new wind plant over an assumed life in the same geographic region as of the acquisition date using third-party market participant assumptions. The expected wind farm net capacity was developed by evaluating each wind farm’s historical and expected generation against historical generation of comparable wind farms in the same locations. Discount rates were evaluated by considering the cost of capital of comparable businesses. Additional key input assumptions for the fair value of the noncontrolling interests include the terms of the limited liability company agreements that dictate the sharing of the tax attributes and cash flows associated with the tax equity partnerships. Upon closing of the purchase, Sempra Renewables LLC was legally renamed AEP Wind Holdings LLC. AEP Wind Holdings LLC develops, owns and operates, or holds interests in wind generation facilities in the United States. The operating wind generation portfolio includes seven wind farms. Five wind farms are jointly-owned with BP Wind Energy, and two wind farms are consolidated by AEP and are tax equity partnerships with nonaffiliated noncontrolling interests. All seven wind farms have long-term PPAs for 100% of their energy production. The PPAs with I&M, OPCo and SWEPCo were executed prior to the acquisition of the wind farms and will be accounted for in accordance with the accounting guidance for “Related Parties.” See “Sempra Renewables LLC PPAs” section of Note 16 for additional information. The acquired business contributed revenues and net income to AEP that were not material for the period April 22, 2019 to December 31, 2019. The pro-forma revenue and net income related to the acquisition of Sempra Renewables LLC were not material for the year ended December 31, 2019. See Note 17 - Variable Interest Entities and Equity Method Investments for additional information related to the purchased wind farms. Santa Rita East (Generation & Marketing Segment) (Applies to AEP) In July 2019, AEP acquired a 75% interest, or 227 MWs, in Santa Rita East for approximately $356 million. In accordance with the accounting guidance for “Business Combinations,” management determined that the acquisition of Santa Rita East represents an asset acquisition. Additionally, and in accordance with the accounting guidance for “Consolidation,” management concluded that Santa Rita East is a VIE. As a result, to account for the initial consolidation of Santa Rita East, management applied the acquisition method by allocating the purchase price based on the relative fair value of the assets acquired and noncontrolling interest assumed. The fair value of the primary assets acquired and the noncontrolling interest assumed was determined using the market approach. The key input assumptions were the transaction price paid for AEP’s interest in Santa Rita East and recent third-party market transactions for similar wind farms. See “Santa Rita East” section of Note 17 for additional information. ASSETS AND LIABILITIES HELD FOR SALE 2021 Disposition of KPCo and KTCo (Vertically Integrated Utilities and AEP Transmission Holdco Segments) (Applies to AEP and AEPTCo) In October 2021, AEP entered into a Stock Purchase Agreement to sell KPCo and KTCo to Liberty Utilities Co., a subsidiary of Algonquin Power & Utilities Corp. (Liberty), for approximately a $2.85 billion enterprise value. The sale is subject to regulatory approvals from the FERC and KPSC. Clearance under the Hart-Scott-Rodino Antitrust Improvements Act of 1976 and clearance from the Committee on Foreign Investment in the United States has been received. KPCo currently operates and owns a 50% interest in the 1,560 MW coal-fired Mitchell Power Plant (Mitchell Plant) with the remaining 50% owned by WPCo. The Stock Purchase Agreement is further contingent upon the issuance by the KPSC, WVPSC and FERC of orders regarding a new proposed Mitchell Plant Operations and Maintenance Agreement and Mitchell Plant Ownership Agreement between KPCo and WPCo pursuant to which WPCo would replace KPCo as the operator of the Mitchell Plant and KPCo employees at the Mitchell Plant would become employees of WPCo. Under the proposed Ownership Agreement, WPCo is obligated to purchase KPCo’s 50% interest in the Mitchell Plant on December 31, 2028 unless KPCo and WPCo have agreed to retire the Mitchell Plant earlier or, absent such agreement, if WPCo elects prior to December 31, 2027 to retire the Mitchell Plant on December 31, 2028. The Ownership Agreement provides that the purchase price for KPCo’s 50% ownership interest in the Mitchell Plant will be determined through the mutual agreement of WPCo and KPCo (subject to approval from the KPSC and WVPSC) or through a fair market valuation determination conducted by independent appraisals, with offsets for estimated decommissioning costs and the cost of ELG investments made by WPCo, if KPCo and WPCo are unable to reach agreement as to the purchase price. In November 2021, AEP made filings with the KPSC, WVPSC, and FERC seeking approval of the new proposed Mitchell Plant Operations and Maintenance Agreement and Mitchell Plant Ownership Agreement. Subsequently, the KPSC and WVPSC intervened in the FERC proceeding and have recommended that FERC dismiss or reject AEP’s request, or defer ruling on AEP’s request until both the retail commissions have rendered decisions. In February 2022, AEP filed a motion to withdraw its filing with the FERC, noting that AEP intends to re-file its request after the KPSC and WVPSC have reviewed the agreements. In the WVPSC proceeding, intervenor testimony is expected in March 2022 and a hearing is scheduled to occur in April 2022. In December 2022, Liberty, KPCo and KTCo sought approval from the FERC under Section 203 of the Federal Power Act for the sale. In February 2022 several intervenors in the case filed protests related to whether the sale will negatively impact the wholesale transmission and generation rates of applicants. An order from the FERC is expected in the matter in April 2022. In January 2022, intervenor testimony was filed with the KPSC, recommending the KPSC either reject the new proposed Mitchell Plant Ownership Agreement or approve the agreement with certain modifications including a revision to the buyout provision that would set WPCo’s Mitchell Plant purchase price at the greater of fair market value or net book value. The intervenor testimony also recommends the KPSC reject the proposed Mitchell Plant Operations and Maintenance Agreement, which the testimony stated should be modified to remove references to the Mitchell Plant Ownership Agreement. In February 2022, AEP filed rebuttal testimony with the KPSC opposing the intervenor testimony filed in January 2022. AEP’s rebuttal testimony also discusses an alternative proposal to the fair market value provision included in the proposed Mitchell Plant Ownership Agreement. Under the alternative proposal, KPCo’s and WPCo’s interest in the Mitchell Plant would be divided by unit if the plant is not retired before the end of 2028 and a mutual agreement cannot be reached on a buyout price. Under the alternative proposal, mutual agreement on the buyout price or unit disposition would need to be finalized by May 2025, with a division of plant ownership by unit effective January 1, 2029, unless otherwise agreed. A hearing on the Mitchell Plant agreements is scheduled with the KPSC in March 2022. In January 2022, KPCo and Liberty filed a joint application requesting the KPSC authorize the transfer of ownership of KPCo to Liberty. In February 2022, certain intervenors filed testimony recommending that the KPSC not approve the transfer of ownership. If, however, the KPSC does approve the transfer, these intervenors recommend that the KPSC require AEP to compensate KPCo customers $578 million for alleged future increased costs and higher rates that the intervenors claim will exist under Liberty’s ownership. AEP disagrees with the recommendation and will file rebuttal testimony in March 2022. Intervenors also recommended imposing certain conditions on Liberty, including conditions related to recovering certain costs, inter-company agreement filing requirements, KPCo’s capital structure and future generation resource planning processes and analyses. In addition, certain intervenors argue that the commission should not approve the new proposed Mitchell Plant Ownership Agreement and Mitchell Plant Operations and Maintenance Agreement, and that deciding the request to transfer ownership of KPCo should be separated from approval of the Mitchell agreements even though such approval is a condition to the transaction closing. AEP also disagrees with this argument. A hearing is scheduled with the KPSC in March 2022 and a final order is expected in the second quarter of 2022. The sale is expected to close in the second quarter of 2022 with Liberty acquiring the assets and assuming the liabilities of KPCo and KTCo, excluding pension and other post-retirement benefit plan assets and liabilities. AEP expects to provide customary transition services to Liberty for a period of time after closing of the transaction. AEP expects to receive approximately $1.45 billion in cash, net of taxes and transaction fees. AEP plans to use the proceeds to eliminate forecasted equity needs in 2022 as the company invests in regulated renewables, transmission and other projects. AEP and AEPTCo expect the sale to have a one-time impact on after tax earnings that is not material. The Income Before Income Tax Expense (Benefit) and Equity Earnings of KPCo and KTCo were not material to AEP and AEPTCo for the years ended December 31, 2021, 2020 and 2019, respectively. The major classes of KPCo and KTCo’s assets and liabilities presented in Assets Held for Sale and Liabilities Held for Sale on the balance sheets of AEP and AEPTCo as of December 31, 2021 are shown in the table below. December 31, 2021 AEP AEPTCo (in millions) ASSETS Accounts Receivable and Accrued Unbilled Revenues $ 33.2 $ 1.5 Fuel, Materials and Supplies 30.6 — Property, Plant and Equipment, Net 2,302.7 165.3 Regulatory Assets 484.7 — Other Classes of Assets that are not Major 68.5 1.1 Assets Held for Sale $ 2,919.7 $ 167.9 LIABILITIES Accounts Payable $ 53.4 $ 1.1 Long-term Debt Due Within One Year 200.0 — Customer Deposits 32.4 — Deferred Income Taxes 441.6 15.4 Long-term Debt 903.1 — Regulatory Liabilities and Deferred Investment Tax Credits 148.1 7.6 Other Classes of Liabilities that are not Major 102.3 3.5 Liabilities Held for Sale $ 1,880.9 $ 27.6 DISPOSITIONS 2021 Disposition of Racine (Generation & Marketing Segment) (Applies to AEP) In February 2021, AEP signed an agreement to sell Racine to a nonaffiliated party. The sale of Racine closed in the fourth quarter of 2021 resulting in an immaterial gain which is recorded in Other Operation on AEP’s statements of income. 2020 Conesville Plant (Generation & Marketing Segment) (Applies to AEP) In June 2020, AEP and a nonaffiliated joint-owner executed an Environmental Liability and Property Transfer and Asset Purchase Agreement with a nonaffiliated third-party related to the merchant Conesville Plant site. The purchaser took ownership of the assets and assumed responsibility for environmental liabilities, including ash pond closure, asbestos abatement and decommissioning and demolition of the Conesville Plant site. In consideration of the transfer of the acquired assets to the purchaser and the purchaser’s assumption of liabilities, AEP will pay a total of approximately $98 million over three years, derecognized $106 million in ARO and recorded an immaterial gain on the transaction which is recorded in Other Operation on the statements of income. AEP paid approximately $26 million at closing in June 2020 and made additional payments totaling $57 million in quarterly installments from October 2020 to December 2021. AEP will make the final $15 million payment by July 2022. Oklaunion Power Station (Transmission and Distribution Segment and Vertically Integrated Utilities Segment) (Applies to AEP, AEP Texas and PSO) In October 2020, AEP Texas, PSO and a nonaffiliated joint-owner executed an Environmental Liability and Property Transfer and Asset Purchase Agreement with a nonaffiliated third-party related to the Oklaunion Power Station site. The purchaser took ownership of the assets and assumed responsibility for environmental liabilities, including ash pond closure, asbestos abatement and decommissioning and demolition of the Oklaunion Power Station site. The sale had an immaterial impact on the financial statements in the fourth quarter of 2020. IMPAIRMENTS 2021 2020 Texas Base Rate Case (Vertically Integrated Utilities Segment) (Applies to AEP and SWEPCo) In January 2022, the PUCT issued a final order adopting the PFD with certain modifications which included a return of investment only for the recovery of the Dolet Hills Power Station. As a result of the final order, SWEPCo recorded a disallowance of $12 million associated with the lack of return on the Dolet Hills Power Station. In February 2022, SWEPCo filed a motion for rehearing with the PUCT challenging the denial of reasonable return or carrying costs on the Dolet Hills Power Station. See “2020 Texas Base Rate Case” section of Note 4 for additional information . 2019 2019 Texas Base Rate Case (Transmission and Distribution Segment) (Applies to AEP and AEP Texas) In December 2019, AEP Texas recorded a pretax impairment of $33 million in Asset Impairments and Other Related Charges on the statements of income due to regulatory disallowances in the 2019 Texas Base Rate Case. Virginia Jurisdictional Book Value of Retired Coal-Fired Plants (Vertically Integrated Utilities Segment) (Applies to AEP and APCo) In December 2019, based on management’s interpretation of Virginia law and more certainty regarding APCo’s triennial revenues, expenses and resulting earnings upon reaching the end of the three-year review period, APCo recorded a pretax expense of $93 million in Asset Impairments and Other Related Charges on the statements of income related to its previously retired coal-fired generation. As a result, management deemed these costs to be substantially recovered by APCo during the triennial review period. See “2017-2019 Virginia Triennial Review” section of Note 4 for additional information. Merchant Generating Assets (Generation & Marketing Segment) Due to a significant increase in the asset retirement costs recorded in December 2019 for the Ash Pond Complex at Conesville Plant, AEP performed an impairment analysis on Conesville Plant in accordance with accounting guidance for impairments of long-lived assets. AEP performed step one and step two of the impairment analysis using a cash flow model for the estimated useful life of Conesville Plant based upon energy and capacity price curves, which were developed internally with both observable Level 2 third-party quotations and unobservable Level 3 inputs, as well as management’s forecasts of operating expenses. The step two analysis resulted in a fair value determination for Conesville Plant of $0 and AEP recorded a $31 million pretax impairment, equal to the net book value of the plant, in Asset Impairments and Other Related Charges on AEP’s statements of income in the fourth quarter of 2019. SUBSEQUENT EVENT Planned Disposition of Competitive Contracted Renewable Assets (Generation & Marketing Segment) In February 2022, AEP management announced the beginning of a process to sell all or a portion of the competitive contracted renewables portfolio included in the Generation & Marketing segment. As of December 31, 2021, the competitive contracted renewable portfolio assets totaled 1.6 gigawatts of generation resources.

Benefit Plans

Benefit Plans	12 Months Ended
Benefit Plans	Dec. 31, 2021
Benefit Plans	BENEFIT PLANS The disclosures in this note apply to all Registrants except AEPTCo unless indicated otherwise. For a discussion of investment strategy, investment limitations, target asset allocations and the classification of investments within the fair value hierarchy, see “Fair Value Measurements of Assets and Liabilities” and “Investments Held in Trust for Future Liabilities” sections of Note 1. AEP sponsors a qualified pension plan and two unfunded non-qualified pension plans. Substantially all AEP employees are covered by the qualified plan or both the qualified and a non-qualified pension plan. AEP also sponsors OPEB plans to provide health and life insurance benefits for retired employees. Due to the Registrant Subsidiaries’ participation in AEP’s benefit plans, the assumptions used by the actuary, with the exception of the rate of compensation increase, and the accounting for the plans by each subsidiary are the same. This section details the assumptions that apply to all Registrants and the rate of compensation increase for each Registrant. The Registrants recognize the funded status associated with defined benefit pension and OPEB plans on the balance sheets. Disclosures about the plans are required by the “Compensation – Retirement Benefits” accounting guidance. The Registrants recognize an asset for a plan’s overfunded status or a liability for a plan’s underfunded status, and recognize, as a component of other comprehensive income, the changes in the funded status of the plan that arise during the year that are not recognized as a component of net periodic benefit cost. The Registrants record a regulatory asset instead of other comprehensive income for qualifying benefit costs of regulated operations that for rate-making purposes are deferred for future recovery. The cumulative funded status adjustment is equal to the remaining unrecognized deferrals for unamortized actuarial losses or gains, prior service costs and transition obligations, such that remaining deferred costs result in an AOCI equity reduction or regulatory asset and deferred gains result in an AOCI equity addition or regulatory liability. Actuarial Assumptions for Benefit Obligations The weighted-average assumptions used in the measurement of the Registrants’ benefit obligations are shown in the following tables: Pension Plans OPEB December 31, Assumption 2021 2020 2021 2020 Discount Rate 2.90 % 2.50 % 2.90 % 2.55 % Interest Crediting Rate 4.00 % 4.00 % NA NA NA Not applicable. Pension Plans December 31, Assumption – Rate of Compensation Increase (a) 2021 2020 AEP 5.10 % 5.00 % AEP Texas 5.10 % 5.05 % APCo 4.85 % 4.85 % I&M 5.00 % 5.00 % OPCo 5.30 % 5.25 % PSO 5.10 % 5.05 % SWEPCo 4.95 % 4.90 % (a) Rates are for base pay only. In addition, an amount is added to reflect target incentive compensation for exempt employees and overtime and incentive pay for nonexempt employees. A duration-based method is used to determine the discount rate for the plans. A hypothetical portfolio of high quality corporate bonds is constructed with cash flows matching the benefit plan liability. The composite yield on the hypothetical bond portfolio is used as the discount rate for the plan. The discount rate is the same for each Registrant. For 2021, the rate of compensation increase assumed varies with the age of the employee, ranging from 3% per year to 11.5% per year, with the average increase shown in the table above. The compensation increase rates reflect variations in each Registrants’ population participating in the pension plan. Actuarial Assumptions for Net Periodic Benefit Costs The weighted-average assumptions used in the measurement of each Registrants’ benefit costs are shown in the following tables: Pension Plans OPEB Year Ended December 31, Assumption 2021 2020 2019 2021 2020 2019 Discount Rate 2.50 % 3.25 % 4.30 % 2.55 % 3.30 % 4.30 % Interest Crediting Rate 4.00 % 4.00 % 4.00 % NA NA NA Expected Return on Plan Assets 4.75 % 5.75 % 6.25 % 4.75 % 5.50 % 6.25 % NA Not applicable. Pension Plans Year Ended December 31, Assumption – Rate of Compensation Increase (a) 2021 2020 2019 AEP 5.10 % 5.00 % 4.95 % AEP Texas 5.10 % 5.05 % 5.00 % APCo 4.85 % 4.85 % 4.75 % I&M 5.00 % 5.00 % 4.95 % OPCo 5.30 % 5.25 % 5.20 % PSO 5.10 % 5.05 % 5.05 % SWEPCo 4.95 % 4.90 % 4.90 % (a) Rates are for base pay only. In addition, an amount is added to reflect target incentive compensation for exempt employees and overtime and incentive pay for nonexempt employees. The expected return on plan assets was determined by evaluating historical returns, the current investment climate (yield on fixed income securities and other recent investment market indicators), rate of inflation, third-party forecasts and current prospects for economic growth. The expected return on plan assets is the same for each Registrant. The health care trend rate assumptions used for OPEB plans measurement purposes are shown below: December 31, Health Care Trend Rates 2021 2020 Initial 6.25 % 6.50 % Ultimate 4.50 % 4.50 % Year Ultimate Reached 2029 2029 Significant Concentrations of Risk within Plan Assets In addition to establishing the target asset allocation of plan assets, the investment policy also places restrictions on securities to limit significant concentrations within plan assets. The investment policy establishes guidelines that govern maximum market exposure, security restrictions, prohibited asset classes, prohibited types of transactions, minimum credit quality, average portfolio credit quality, portfolio duration and concentration limits. The guidelines were established to mitigate the risk of loss due to significant concentrations in any investment. Management monitors the plans to control security diversification and ensure compliance with the investment policy. As of December 31, 2021, the assets were invested in compliance with all investment limits. See “Investments Held in Trust for Future Liabilities” section of Note 1 for limit details. Benefit Plan Obligations, Plan Assets, Funded Status and Amounts Recognized on the Balance Sheets For the year ended December 31, 2021, the pension plans had an actuarial gain primarily due to an increase in the discount rate, partially offset by less favorable demographic experience than expected, resulting from the updated census information as of January 1, 2021. For the year ended December 31, 2021, the OPEB plans had an actuarial gain primarily due to an increase in the discount rate and an update of the projected reimbursements from the Employer Group Waiver Program under Medicare Part D. For the year ended December 31, 2020, the pension plans had an actuarial loss primarily due to a decrease in the discount rate, partially offset by a decrease in the assumed rate used to convert account balances to annuities. For the year ended December 31, 2020, the OPEB plans had an actuarial loss primarily due to a decrease in the discount rate and an update to the health care trend assumption, partially offset by updated projected per capita claims costs due to rate negotiations for Medicare advantage premium rates. The following tables provide a reconciliation of the changes in the plans’ benefit obligations, fair value of plan assets, funded status and the presentation on the balance sheets. The benefit obligation for the defined benefit pension and OPEB plans are the projected benefit obligation and the accumulated benefit obligation, respectively. AEP Pension Plans OPEB 2021 2020 2021 2020 Change in Benefit Obligation (in millions) Benefit Obligation as of January 1, $ 5,544.5 $ 5,236.8 $ 1,210.9 $ 1,225.4 Service Cost 129.2 111.9 9.5 10.0 Interest Cost 137.2 167.9 30.5 39.8 Actuarial (Gain) Loss (173.9) 434.7 (120.1) 39.3 Plan Amendments — — (5.4) (11.4) Benefit Payments (450.0) (406.8) (126.0) (131.0) Participant Contributions — — 41.3 38.2 Medicare Subsidy — — 0.6 0.6 Benefit Obligation as of December 31, $ 5,187.0 $ 5,544.5 $ 1,041.3 $ 1,210.9 Change in Fair Value of Plan Assets Fair Value of Plan Assets as of January 1, $ 5,556.6 $ 5,015.4 $ 1,946.7 $ 1,781.8 Actual Gain on Plan Assets 239.2 832.4 176.5 253.0 Company Contributions (a) 7.1 115.6 5.8 4.7 Participant Contributions — — 41.3 38.2 Benefit Payments (450.0) (406.8) (126.0) (131.0) Fair Value of Plan Assets as of December 31, $ 5,352.9 $ 5,556.6 $ 2,044.3 $ 1,946.7 Funded Status as of December 31, $ 165.9 $ 12.1 $ 1,003.0 $ 735.8 (a) Contributions to the qualified pension plan were $0 and $110 million for the years ended December 31, 2021 and 2020, respectively. Contributions to the non-qualified pension plans were $7 million and $6 million for the years ended December 31, 2021 and 2020, respectively. Pension Plans OPEB December 31, AEP 2021 2020 2021 2020 (in millions) Deferred Charges and Other Noncurrent Assets – Prepaid Benefit Costs $ 244.3 $ 93.5 $ 1,040.8 $ 771.9 Other Current Liabilities – Accrued Short-term Benefit Liability (7.6) (6.7) (2.7) (2.4) Employee Benefits and Pension Obligations – Accrued Long-term Benefit Liability (70.8) (74.7) (35.1) (33.7) Funded Status $ 165.9 $ 12.1 $ 1,003.0 $ 735.8 AEP Texas Pension Plans OPEB 2021 2020 2021 2020 Change in Benefit Obligation (in millions) Benefit Obligation as of January 1, $ 453.2 $ 441.2 $ 96.3 $ 97.8 Service Cost 11.8 10.0 0.7 0.8 Interest Cost 11.2 13.9 2.4 3.2 Actuarial (Gain) Loss (10.9) 28.1 (12.3) 2.4 Plan Amendments — — (0.5) (1.0) Benefit Payments (45.5) (40.0) (9.3) (10.0) Participant Contributions — — 3.2 3.1 Benefit Obligation as of December 31, $ 419.8 $ 453.2 $ 80.5 $ 96.3 Change in Fair Value of Plan Assets Fair Value of Plan Assets as of January 1, $ 474.0 $ 435.1 $ 162.3 $ 148.1 Actual Gain on Plan Assets 16.0 67.2 12.5 21.1 Company Contributions 0.4 11.7 0.1 — Participant Contributions — — 3.2 3.1 Benefit Payments (45.5) (40.0) (9.3) (10.0) Fair Value of Plan Assets as of December 31, $ 444.9 $ 474.0 $ 168.8 $ 162.3 Funded Status as of December 31, $ 25.1 $ 20.8 $ 88.3 $ 66.0 Pension Plans OPEB December 31, AEP Texas 2021 2020 2021 2020 (in millions) Deferred Charges and Other Noncurrent Assets – Prepaid Benefit Costs $ 28.7 $ 24.7 $ 88.3 $ 66.0 Other Current Liabilities – Accrued Short-term Benefit Liability (0.3) (0.4) — — Deferred Credits and Other Noncurrent Liabilities – Accrued Long-term Benefit Liability (3.3) (3.5) — — Funded Status $ 25.1 $ 20.8 $ 88.3 $ 66.0 APCo Pension Plans OPEB 2021 2020 2021 2020 Change in Benefit Obligation (in millions) Benefit Obligation as of January 1, $ 670.8 $ 647.2 $ 198.2 $ 203.5 Service Cost 11.9 10.5 1.0 1.0 Interest Cost 16.4 20.3 4.9 6.6 Actuarial (Gain) Loss (28.5) 40.0 (21.4) 5.6 Plan Amendments — — (0.9) (1.8) Benefit Payments (48.9) (47.2) (21.3) (23.2) Participant Contributions — — 6.6 6.3 Medicare Subsidy — — 0.2 0.2 Benefit Obligation as of December 31, $ 621.7 $ 670.8 $ 167.3 $ 198.2 Change in Fair Value of Plan Assets Fair Value of Plan Assets as of January 1, $ 701.3 $ 637.0 $ 293.0 $ 271.0 Actual Gain on Plan Assets 30.9 104.5 21.9 36.8 Company Contributions — 7.0 2.1 2.1 Participant Contributions — — 6.6 6.3 Benefit Payments (48.9) (47.2) (21.3) (23.2) Fair Value of Plan Assets as of December 31, $ 683.3 $ 701.3 $ 302.3 $ 293.0 Funded Status as of December 31, $ 61.6 $ 30.5 $ 135.0 $ 94.8 Pension Plans OPEB December 31, APCo 2021 2020 2021 2020 (in millions) Employee Benefits and Pension Assets – Prepaid Benefit Costs $ 62.4 $ 31.0 $ 158.1 $ 119.1 Other Current Liabilities – Accrued Short-term Benefit Liability — — (1.8) (1.8) Employee Benefits and Pension Obligations – Accrued Long-term Benefit Liability (0.8) (0.5) (21.3) (22.5) Funded Status $ 61.6 $ 30.5 $ 135.0 $ 94.8 I&M Pension Plans OPEB 2021 2020 2021 2020 Change in Benefit Obligation (in millions) Benefit Obligation as of January 1, $ 653.3 $ 616.1 $ 141.4 $ 142.9 Service Cost 17.5 15.4 1.3 1.4 Interest Cost 16.2 19.7 3.5 4.7 Actuarial (Gain) Loss (29.5) 44.3 (16.8) 5.1 Plan Amendments — — (0.7) (1.6) Benefit Payments (45.4) (42.2) (15.3) (15.9) Participant Contributions — — 5.2 4.8 Benefit Obligation as of December 31, $ 612.1 $ 653.3 $ 118.6 $ 141.4 Change in Fair Value of Plan Assets Fair Value of Plan Assets as of January 1, $ 698.1 $ 630.5 $ 238.2 $ 216.3 Actual Gain on Plan Assets 28.8 103.3 20.6 33.0 Company Contributions — 6.5 — — Participant Contributions — — 5.2 4.8 Benefit Payments (45.4) (42.2) (15.3) (15.9) Fair Value of Plan Assets as of December 31, $ 681.5 $ 698.1 $ 248.7 $ 238.2 Funded Status as of December 31, $ 69.4 $ 44.8 $ 130.1 $ 96.8 Pension Plans OPEB December 31, I&M 2021 2020 2021 2020 (in millions) Deferred Charges and Other Noncurrent Assets – Prepaid Benefit Costs $ 71.4 $ 46.5 $ 130.1 $ 96.8 Other Current Liabilities – Accrued Short-term Benefit Liability (0.1) — — — Deferred Credits and Other Noncurrent Liabilities – Accrued Long-term Benefit Liability (1.9) (1.7) — — Funded Status $ 69.4 $ 44.8 $ 130.1 $ 96.8 OPCo Pension Plans OPEB 2021 2020 2021 2020 Change in Benefit Obligation (in millions) Benefit Obligation as of January 1, $ 510.3 $ 487.8 $ 126.4 $ 130.2 Service Cost 11.4 9.7 0.8 0.9 Interest Cost 12.5 15.4 3.0 4.2 Actuarial (Gain) Loss (24.1) 33.4 (15.6) 3.1 Plan Amendments — — (0.6) (1.3) Benefit Payments (39.4) (36.0) (13.6) (15.0) Participant Contributions — — 4.5 4.3 Benefit Obligation as of December 31, $ 470.7 $ 510.3 $ 104.9 $ 126.4 Change in Fair Value of Plan Assets Fair Value of Plan Assets as of January 1, $ 543.1 $ 499.1 $ 213.0 $ 197.1 Actual Gain on Plan Assets 21.1 79.9 16.1 26.6 Company Contributions — 0.1 — — Participant Contributions — — 4.5 4.3 Benefit Payments (39.4) (36.0) (13.6) (15.0) Fair Value of Plan Assets as of December 31, $ 524.8 $ 543.1 $ 220.0 $ 213.0 Funded Status as of December 31, $ 54.1 $ 32.8 $ 115.1 $ 86.6 Pension Plans OPEB December 31, OPCo 2021 2020 2021 2020 (in millions) Deferred Charges and Other Noncurrent Assets – Prepaid Benefit Costs $ 54.8 $ 33.3 $ 115.1 $ 86.6 Deferred Credits and Other Noncurrent Liabilities – Accrued Long-term Benefit Liability (0.7) (0.5) — — Funded Status $ 54.1 $ 32.8 $ 115.1 $ 86.6 PSO Pension Plans OPEB 2021 2020 2021 2020 Change in Benefit Obligation (in millions) Benefit Obligation as of January 1, $ 279.9 $ 267.5 $ 64.0 $ 64.7 Service Cost 8.0 7.3 0.6 0.7 Interest Cost 6.7 8.5 1.6 2.1 Actuarial (Gain) Loss (17.2) 17.7 (6.8) 1.9 Plan Amendments — — (0.3) (0.7) Benefit Payments (24.8) (21.1) (7.0) (6.8) Participant Contributions — — 2.3 2.1 Benefit Obligation as of December 31, $ 252.6 $ 279.9 $ 54.4 $ 64.0 Change in Fair Value of Plan Assets Fair Value of Plan Assets as of January 1, $ 299.8 $ 276.2 $ 107.8 $ 98.0 Actual Gain on Plan Assets 11.1 44.6 10.9 14.5 Company Contributions 0.1 0.1 — — Participant Contributions — — 2.3 2.1 Benefit Payments (24.8) (21.1) (7.0) (6.8) Fair Value of Plan Assets as of December 31, $ 286.2 $ 299.8 $ 114.0 $ 107.8 Funded Status as of December 31, $ 33.6 $ 19.9 $ 59.6 $ 43.8 Pension Plans OPEB December 31, PSO 2021 2020 2021 2020 (in millions) Employee Benefits and Pension Assets – Prepaid Benefit Costs $ 35.5 $ 21.9 $ 59.6 $ 43.8 Other Current Liabilities – Accrued Short-term Benefit Liability (0.1) (0.1) — — Deferred Credits and Other Noncurrent Liabilities – Accrued Long-term Benefit Liability (1.8) (1.9) — — Funded Status $ 33.6 $ 19.9 $ 59.6 $ 43.8 SWEPCo Pension Plans OPEB 2021 2020 2021 2020 Change in Benefit Obligation (in millions) Benefit Obligation as of January 1, $ 334.5 $ 314.2 $ 77.1 $ 77.4 Service Cost 11.2 9.9 0.8 0.8 Interest Cost 8.5 10.2 1.9 2.5 Actuarial (Gain) Loss (3.5) 27.4 (9.2) 2.5 Plan Amendments — — (0.4) (0.8) Benefit Payments (33.0) (27.2) (7.6) (7.7) Participant Contributions — — 2.6 2.4 Benefit Obligation as of December 31, $ 317.7 $ 334.5 $ 65.2 $ 77.1 Change in Fair Value of Plan Assets Fair Value of Plan Assets as of January 1, $ 326.9 $ 296.9 $ 129.9 $ 117.2 Actual Gain on Plan Assets 14.3 48.2 11.7 18.0 Company Contributions 0.1 9.0 — — Participant Contributions — — 2.6 2.4 Benefit Payments (33.0) (27.2) (7.6) (7.7) Fair Value of Plan Assets as of December 31, $ 308.3 $ 326.9 $ 136.6 $ 129.9 Funded (Underfunded) Status as of December 31, $ (9.4) $ (7.6) $ 71.4 $ 52.8 Pension Plans OPEB December 31, SWEPCo 2021 2020 2021 2020 (in millions) Deferred Charges and Other Noncurrent Assets – Prepaid Benefit Costs $ — $ — $ 71.4 $ 52.8 Other Current Liabilities – Accrued Short-term Benefit Liability (0.1) (0.1) — — Employee Benefits and Pension Obligations – Accrued Long-term Benefit Liability (9.3) (7.5) — — Funded (Underfunded) Status $ (9.4) $ (7.6) $ 71.4 $ 52.8 Amounts Included in Regulatory Assets, Deferred Income Taxes and AOCI The following tables show the components of the plans included in Regulatory Assets, Deferred Income Taxes and AOCI and the items attributable to the change in these components: AEP Pension Plans OPEB December 31, 2021 2020 2021 2020 Components (in millions) Net Actuarial (Gain) Loss $ 894.7 $ 1,179.6 $ (103.6) $ 101.9 Prior Service Cost (Credit) 0.2 0.2 (161.9) (227.3) Recorded as Regulatory Assets $ 878.0 $ 1,182.4 $ (195.1) $ (99.0) Deferred Income Taxes 3.6 (0.5) (14.7) (5.5) Net of Tax AOCI 13.3 (2.1) (55.7) (20.9) AEP Pension Plans OPEB 2021 2020 2021 2020 Components (in millions) Actuarial Gain During the Year $ (183.4) $ (132.9) $ (205.5) $ (118.0) Amortization of Actuarial Loss (101.5) (93.7) — (5.9) Prior Service Credit — — (5.5) (11.4) Amortization of Prior Service Credit — — 70.9 69.8 Change for the Year Ended December 31, $ (284.9) $ (226.6) $ (140.1) $ (65.5) AEP Texas Pension Plans OPEB December 31, 2021 2020 2021 2020 Components (in millions) Net Actuarial (Gain) Loss $ 144.7 $ 160.5 $ (5.2) $ 12.3 Prior Service Credit — — (13.7) (19.3) Recorded as Regulatory Assets $ 136.7 $ 151.3 $ (17.7) $ (6.3) Deferred Income Taxes 1.8 2.0 (0.2) (0.1) Net of Tax AOCI 6.2 7.2 (1.0) (0.6) AEP Texas Pension Plans OPEB 2021 2020 2021 2020 Components (in millions) Actuarial Gain During the Year $ (7.5) $ (16.4) $ (17.5) $ (10.7) Amortization of Actuarial Loss (8.3) (7.8) — (0.5) Prior Service Credit — — (0.4) (1.0) Amortization of Prior Service Credit — — 6.0 5.9 Change for the Year Ended December 31, $ (15.8) $ (24.2) $ (11.9) $ (6.3) APCo Pension Plans OPEB December 31, 2021 2020 2021 2020 Components (in millions) Net Actuarial (Gain) Loss $ 83.9 $ 126.3 $ (18.9) $ 11.1 Prior Service Credit — — (23.8) (33.2) Recorded as Regulatory Assets $ 82.5 $ 124.7 $ (19.8) $ (10.3) Deferred Income Taxes 0.3 0.3 (4.9) (2.5) Net of Tax AOCI 1.1 1.3 (18.0) (9.3) APCo Pension Plans OPEB 2021 2020 2021 2020 Components (in millions) Actuarial Gain During the Year $ (30.4) $ (30.8) $ (30.0) $ (16.8) Amortization of Actuarial Loss (12.0) (11.2) — (0.9) Prior Service Credit — — (0.9) (1.8) Amortization of Prior Service Credit — — 10.3 10.2 Change for the Year Ended December 31, $ (42.4) $ (42.0) $ (20.6) $ (9.3) I&M Pension Plans OPEB December 31, 2021 2020 2021 2020 Components (in millions) Net Actuarial (Gain) Loss $ (1.6) $ 39.5 $ (10.7) $ 15.6 Prior Service Credit — — (22.1) (31.0) Recorded as Regulatory Assets/Liabilities (a) $ 3.1 $ 40.3 $ (30.7) $ (14.6) Deferred Income Taxes (1.0) (0.1) (0.4) (0.2) Net of Tax AOCI (3.7) (0.7) (1.7) (0.6) (a) Recorded as a Regulatory Liability as of December 31, 2021 and recorded as a Regulatory Asset as of December 31, 2020. I&M Pension Plans OPEB 2021 2020 2021 2020 Components (in millions) Actuarial Gain During the Year $ (29.4) $ (25.7) $ (26.3) $ (16.4) Amortization of Actuarial Loss (11.7) (10.8) — (0.7) Prior Service Credit — — (0.7) (1.5) Amortization of Prior Service Credit — — 9.6 9.5 Change for the Year Ended December 31, $ (41.1) $ (36.5) $ (17.4) $ (9.1) OPCo Pension Plans OPEB December 31, 2021 2020 2021 2020 Components (in millions) Net Actuarial (Gain) Loss $ 118.1 $ 150.0 $ (18.5) $ 3.6 Prior Service Credit — — (16.3) (22.9) Recorded as Regulatory Assets $ 118.1 $ 150.0 $ (34.8) $ (19.3) OPCo Pension Plans OPEB 2021 2020 2021 2020 Components (in millions) Actuarial Gain During the Year $ (22.8) $ (20.2) $ (22.1) $ (12.9) Amortization of Actuarial Loss (9.1) (8.5) — (0.7) Prior Service Credit — — (0.6) (1.3) Amortization of Prior Service Credit — — 7.2 7.0 Change for the Year Ended December 31, $ (31.9) $ (28.7) $ (15.5) $ (7.9) PSO Pension Plans OPEB December 31, 2021 2020 2021 2020 Components (in millions) Net Actuarial (Gain) Loss $ 35.0 $ 55.9 $ (2.1) $ 10.5 Prior Service Credit — — (10.0) (14.1) Recorded as Regulatory Assets $ 35.0 $ 55.9 $ (12.1) $ (3.6) PSO Pension Plans OPEB 2021 2020 2021 2020 Components (in millions) Actuarial Gain During the Year $ (16.0) $ (12.4) $ (12.6) $ (7.4) Amortization of Actuarial Loss (4.9) (4.7) — (0.3) Prior Service Credit — — (0.3) (0.7) Amortization of Prior Service Credit — — 4.4 4.4 Change for the Year Ended December 31, $ (20.9) $ (17.1) $ (8.5) $ (4.0) SWEPCo Pension Plans OPEB December 31, 2021 2020 2021 2020 Components (in millions) Net Actuarial (Gain) Loss $ 76.4 $ 86.9 $ (3.5) $ 11.5 Prior Service Credit — — (12.3) (17.2) Recorded as Regulatory Assets $ 76.4 $ 86.9 $ (8.9) $ (3.0) Deferred Income Taxes — — (1.4) (0.5) Net of Tax AOCI — — (5.5) (2.2) SWEPCo Pension Plans OPEB 2021 2020 2021 2020 Components (in millions) Actuarial Gain During the Year $ (4.3) $ (5.2) $ (15.0) $ (9.2) Amortization of Actuarial Loss (6.2) (5.7) — (0.4) Prior Service Credit — — (0.4) (0.8) Amortization of Prior Service Credit — — 5.3 5.2 Change for the Year Ended December 31, $ (10.5) $ (10.9) $ (10.1) $ (5.2) Determination of Pension Expense The determination of pension expense or income is based on a market-related valuation of assets which reduces year-to-year volatility. This market-related valuation recognizes investment gains or losses over a five-year period from the year in which they occur. Investment gains or losses for this purpose are the difference between the expected return calculated using the market-related value of assets and the actual return. Pension and OPEB Assets The fair value tables within Pension and OPEB Assets present the classification of assets for AEP within the fair value hierarchy. All Level 1, 2, 3 and Other amounts can be allocated to the Registrant Subsidiaries using the percentages in the table below: Pension Plan OPEB December 31, Company 2021 2020 2021 2020 AEP Texas 8.3 % 8.5 % 8.3 % 8.3 % APCo 12.8 % 12.6 % 14.8 % 15.1 % I&M 12.7 % 12.6 % 12.2 % 12.2 % OPCo 9.8 % 9.8 % 10.8 % 10.9 % PSO 5.3 % 5.4 % 5.6 % 5.5 % SWEPCo 5.8 % 5.9 % 6.7 % 6.7 % The following table presents the classification of pension plan assets for AEP within the fair value hierarchy as of December 31, 2021: Asset Class Level 1 Level 2 Level 3 Other Total Year End (in millions) Equities (a): Domestic $ 388.9 $ — $ — $ — $ 388.9 7.2 % International 465.7 — — — 465.7 8.7 % Common Collective Trusts (c) — — — 463.9 463.9 8.7 % Subtotal – Equities 854.6 — — 463.9 1,318.5 24.6 % Fixed Income (a): United States Government and Agency Securities 0.1 1,557.6 — — 1,557.7 29.1 % Corporate Debt — 1,295.9 — — 1,295.9 24.2 % Foreign Debt — 259.4 — — 259.4 4.8 % State and Local Government — 57.1 — — 57.1 1.1 % Other – Asset Backed — 1.3 — — 1.3 — % Subtotal – Fixed Income 0.1 3,171.3 — — 3,171.4 59.2 % Infrastructure (c) — — — 92.1 92.1 1.7 % Real Estate (c) — — — 232.6 232.6 4.4 % Alternative Investments (c) — — — 448.8 448.8 8.4 % Cash and Cash Equivalents (c) — 64.3 — 53.4 117.7 2.2 % Other – Pending Transactions and Accrued Income (b) — — — (28.2) (28.2) (0.5) % Total $ 854.7 $ 3,235.6 $ — $ 1,262.6 $ 5,352.9 100.0 % (a) Includes investment securities loaned to borrowers under the securities lending program. See the “Investments Held in Trust for Future Liabilities” section of Note 1 for additional information. (b) Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement. (c) Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share. The following table presents the classification of OPEB plan assets for AEP within the fair value hierarchy as of December 31, 2021: Asset Class Level 1 Level 2 Level 3 Other Total Year End (in millions) Equities: Domestic $ 474.0 $ — $ — $ — $ 474.0 23.2 % International 296.3 — — — 296.3 14.5 % Common Collective Trusts (b) — — — 265.0 265.0 13.0 % Subtotal – Equities 770.3 — — 265.0 1,035.3 50.7 % Fixed Income: Common Collective Trust – Debt (b) — — — 167.7 167.7 8.2 % United States Government and Agency Securities — 222.4 — — 222.4 10.9 % Corporate Debt — 233.2 — — 233.2 11.4 % Foreign Debt — 39.8 — — 39.8 2.0 % State and Local Government 91.9 13.6 — — 105.5 5.1 % Subtotal – Fixed Income 91.9 509.0 — 167.7 768.6 37.6 % Trust Owned Life Insurance: International Equities — 23.4 — — 23.4 1.1 % United States Bonds — 171.3 — — 171.3 8.4 % Subtotal – Trust Owned Life Insurance — 194.7 — — 194.7 9.5 % Cash and Cash Equivalents (b) 33.0 — — 6.7 39.7 1.9 % Other – Pending Transactions and Accrued Income (a) — — — 6.0 6.0 0.3 % Total $ 895.2 $ 703.7 $ — $ 445.4 $ 2,044.3 100.0 % (a) Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement. (b) Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share. The following table presents the classification of pension plan assets for AEP within the fair value hierarchy as of December 31, 2020: Asset Class Level 1 Level 2 Level 3 Other Total Year End (in millions) Equities (a): Domestic $ 542.3 $ — $ — $ — $ 542.3 9.7 % International 676.3 — — — 676.3 12.2 % Common Collective Trusts (c) — — — 650.0 650.0 11.7 % Subtotal – Equities 1,218.6 — — 650.0 1,868.6 33.6 % Fixed Income (a): United States Government and Agency Securities (1.4) 1,134.1 — — 1,132.7 20.4 % Corporate Debt — 1,425.0 — — 1,425.0 25.6 % Foreign Debt — 214.0 — — 214.0 3.9 % State and Local Government — 56.0 — — 56.0 1.0 % Other – Asset Backed — 0.8 — — 0.8 — % Subtotal – Fixed Income (1.4) 2,829.9 — — 2,828.5 50.9 % Infrastructure (c) — — — 91.1 91.1 1.6 % Real Estate (c) — — — 231.6 231.6 4.2 % Alternative Investments (c) — — — 431.8 431.8 7.8 % Cash and Cash Equivalents (c) — 49.3 — 58.2 107.5 1.9 % Other – Pending Transactions and Accrued Income (b) — — — (2.5) (2.5) — % Total $ 1,217.2 $ 2,879.2 $ — $ 1,460.2 $ 5,556.6 100.0 % (a) Includes investment securities loaned to borrowers under the securities lending program. See the “Investments Held in Trust for Future Liabilities” section of Note 1 for additional information. (b) Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement. (c) Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share. The following table presents the classification of OPEB plan assets for AEP within the fair value hierarchy as of December 31, 2020: Asset Class Level 1 Level 2 Level 3 Other Total Year End (in millions) Equities: Domestic $ 399.9 $ — $ — $ — $ 399.9 20.6 % International 290.7 — — — 290.7 14.9 % Common Collective Trusts (b) — — — 264.7 264.7 13.6 % Subtotal – Equities 690.6 — — 264.7 955.3 49.1 % Fixed Income: Common Collective Trust – Debt (b) — — — 186.4 186.4 9.6 % United States Government and Agency Securities (0.2) 199.7 — — 199.5 10.2 % Corporate Debt — 248.7 — — 248.7 12.8 % Foreign Debt — 34.9 — — 34.9 1.8 % State and Local Government 73.9 13.1 — — 87.0 4.5 % Subtotal – Fixed Income 73.7 496.4 — 186.4 756.5 38.9 % Trust Owned Life Insurance: International Equities — 64.8 — — 64.8 3.3 % United States Bonds — 135.9 — — 135.9 7.0 % Subtotal – Trust Owned Life Insurance — 200.7 — — 200.7 10.3 % Cash and Cash Equivalents (b) 26.3 — — 5.7 32.0 1.6 % Other – Pending Transactions and Accrued Income (a) — — — 2.2 2.2 0.1 % Total $ 790.6 $ 697.1 $ — $ 459.0 $ 1,946.7 100.0 % (a) Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement. (b) Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share. Accumulated Benefit Obligation The accumulated benefit obligation for the pension plans is as follows: Accumulated Benefit Obligation AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Qualified Pension Plan $ 4,822.5 $ 391.4 $ 597.0 $ 575.2 $ 440.0 $ 232.1 $ 291.4 Nonqualified Pension Plans 69.7 3.3 0.4 1.2 0.3 1.5 1.3 Total as of December 31, 2021 $ 4,892.2 $ 394.7 $ 597.4 $ 576.4 $ 440.3 $ 233.6 $ 292.7 Accumulated Benefit Obligation AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Qualified Pension Plan $ 5,171.3 $ 424.5 $ 645.8 $ 615.8 $ 479.2 $ 258.3 $ 307.1 Nonqualified Pension Plans 72.9 3.6 0.2 0.8 0.2 1.6 1.4 Total as of December 31, 2020 $ 5,244.2 $ 428.1 $ 646.0 $ 616.6 $ 479.4 $ 259.9 $ 308.5 Obligations in Excess of Fair Values The tables below show the underfunded pension plans that had obligations in excess of plan assets. Projected Benefit Obligation AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Projected Benefit Obligation $ 78.4 $ 3.6 $ 0.8 $ 1.9 $ 0.7 $ 1.9 $ 317.7 Fair Value of Plan Assets — — — — — — 308.3 Underfunded Projected Benefit Obligation as of December 31, 2021 $ (78.4) $ (3.6) $ (0.8) $ (1.9) $ (0.7) $ (1.9) $ (9.4) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Projected Benefit Obligation $ 81.4 $ 3.9 $ 0.5 $ 1.7 $ 0.6 $ 2.0 $ 334.5 Fair Value of Plan Assets — — — — — — 326.9 Underfunded Projected Benefit Obligation as of December 31, 2020 $ (81.4) $ (3.9) $ (0.5) $ (1.7) $ (0.6) $ (2.0) $ (7.6) Accumulated Benefit Obligation AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Accumulated Benefit Obligation $ 69.7 $ 3.3 $ 0.4 $ 1.2 $ 0.3 $ 1.5 $ 1.3 Fair Value of Plan Assets — — — — — — — Underfunded Accumulated Benefit Obligation as of December 31, 2021 $ (69.7) $ (3.3) $ (0.4) $ (1.2) $ (0.3) $ (1.5) $ (1.3) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Accumulated Benefit Obligation $ 72.9 $ 3.6 $ 0.2 $ 0.8 $ 0.2 $ 1.6 $ 1.4 Fair Value of Plan Assets — — — — — — — Underfunded Accumulated Benefit Obligation as of December 31, 2020 $ (72.9) $ (3.6) $ (0.2) $ (0.8) $ (0.2) $ (1.6) $ (1.4) Estimated Future Benefit Payments and Contributions The estimated pension benefit payments and contributions to the trust are at least the minimum amount required by the Employee Retirement Income Security Act plus payment of unfunded non-qualified benefits. For the qualified pension plan, additional discretionary contributions may also be made to maintain the funded status of the plan. For OPEB plans, expected payments include the payment of unfunded benefits. The following table provides the estimated contributions and payments by Registrant for 2022: Company Pension Plans OPEB (in millions) AEP $ 133.6 $ 3.4 AEP Texas 5.9 0.1 APCo 1.4 1.8 I&M 1.1 — PSO 0.1 — SWEPCo 6.5 — The tables below reflect the total benefits expected to be paid from the plan or from the Registrants’ assets. The payments include the participants’ contributions to the plan for their share of the cost. Future benefit payments are dependent on the number of employees retiring, whether the retiring employees elect to receive pension benefits as annuities or as lump sum distributions, future integration of the benefit plans with changes to Medicare and other legislation, future levels of interest rates and variances in actuarial results. The estimated payments for the pension benefits and OPEB are as follows: Pension Plans AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) 2022 $ 378.1 $ 36.3 $ 43.9 $ 41.3 $ 35.1 $ 20.3 $ 24.7 2023 380.8 35.9 45.0 40.9 33.7 21.3 25.4 2024 381.1 35.8 45.5 42.1 32.9 20.5 25.5 2025 373.7 34.9 43.1 42.0 33.0 20.4 25.8 2026 373.6 34.7 43.5 42.2 32.4 20.0 27.3 Years 2027 to 2031, in Total 1,722.9 145.5 202.9 201.8 149.1 87.1 112.4 OPEB Benefit Payments AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) 2022 $ 123.9 $ 9.6 $ 20.5 $ 15.2 $ 13.5 $ 7.1 $ 7.7 2023 115.4 9.1 19.1 14.1 12.5 6.7 7.4 2024 119.4 9.8 19.7 14.7 12.9 7.0 7.9 2025 117.9 9.8 19.2 14.5 12.7 7.0 8.0 2026 116.0 9.8 18.8 14.4 12.3 6.8 7.9 Years 2027 to 2031, in Total 545.1 44.7 87.5 66.8 57.1 29.7 37.1 OPEB Medicare AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) 2022 $ 0.2 $ — $ 0.1 $ — $ — $ — $ — 2023 0.3 — 0.1 — — — — 2024 0.3 — 0.1 — — — — 2025 0.3 — 0.1 — — — — 2026 0.3 — 0.1 — — — — Years 2027 to 2031, in Total 1.5 — 0.5 — — — — Components of Net Periodic Benefit Cost The following tables provide the components of net periodic benefit cost (credit) by Registrant for the plans: AEP Pension Plans OPEB Years Ended December 31, 2021 2020 2019 2021 2020 2019 (in millions) Service Cost $ 129.2

Business Segments

Business Segments	12 Months Ended
Business Segments	Dec. 31, 2021
Business Segments	9. BUSINESS SEGMENTS The disclosures in this note apply to all Registrants unless indicated otherwise. AEP’s Reportable Segments AEP’s primary business is the generation, transmission and distribution of electricity. Within its Vertically Integrated Utilities segment, AEP centrally dispatches generation assets and manages its overall utility operations on an integrated basis because of the substantial impact of cost-based rates and regulatory oversight. Intersegment sales and transfers are generally based on underlying contractual arrangements and agreements. AEP’s reportable segments and their related business activities are outlined below: Vertically Integrated Utilities • Generation, transmission and distribution of electricity for sale to retail and wholesale customers through assets owned and operated by AEGCo, APCo, I&M, KGPCo, KPCo, PSO, SWEPCo and WPCo. Transmission and Distribution Utilities • Transmission and distribution of electricity for sale to retail and wholesale customers through assets owned and operated by AEP Texas and OPCo. • OPCo purchases energy and capacity to serve standard service offer customers and provides transmission and distribution services for all connected load. AEP Transmission Holdco • Development, construction and operation of transmission facilities through investments in AEPTCo. These investments have FERC-approved returns on equity. • Development, construction and operation of transmission facilities through investments in AEP’s transmission-only joint ventures. These investments have PUCT-approved or FERC-approved returns on equity. Generation & Marketing • Contracted renewable energy investments and management services. • Marketing, risk management and retail activities in ERCOT, MISO, PJM and SPP. • Competitive generation in PJM. The remainder of AEP’s activities are presented as Corporate and Other. While not considered a reportable segment, Corporate and Other primarily includes the purchasing of receivables from certain AEP utility subsidiaries, Parent’s guarantee revenue received from affiliates, investment income, interest income and interest expense, income tax expense and other nonallocated costs. The tables below present AEP’s reportable segment income statement information for the years ended December 31, 2021, 2020 and 2019 and reportable segment balance sheet information as of December 31, 2021 and 2020. Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation & Marketing Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) 2021 Revenues from: External Customers $ 9,852.2 $ 4,464.1 $ 351.1 $ 2,108.3 $ 16.3 $ — $ 16,792.0 Other Operating Segments 146.3 28.8 1,175.1 55.4 55.9 (1,461.5) — Total Revenues $ 9,998.5 $ 4,492.9 $ 1,526.2 $ 2,163.7 $ 72.2 $ (1,461.5) $ 16,792.0 Asset Impairments and Other Related Charges $ 11.6 $ — $ — $ — $ — $ — $ 11.6 Depreciation and Amortization 1,747.6 690.3 306.0 80.9 0.9 — 2,825.7 Interest Expense 574.2 300.9 146.3 15.6 180.8 (18.7) 1,199.1 Income Tax Expense (Benefit) (11.2) 77.5 159.6 (48.8) (61.6) — 115.5 Equity Earnings (Loss) of Unconsolidated Subsidiaries 3.4 — 75.0 (10.6) 23.9 — 91.7 Net Income (Loss) $ 1,116.7 $ 543.4 $ 682.0 $ 210.2 $ (64.2) $ — $ 2,488.1 Gross Property Additions $ 2,963.1 $ 1,766.0 $ 1,468.6 $ 232.8 $ 25.5 $ (29.2) $ 6,426.8 Total Property, Plant and Equipment $ 48,368.9 $ 22,700.7 $ 13,213.0 $ 2,105.4 $ 418.4 $ — $ 86,806.4 Accumulated Depreciation and Amortization 15,471.6 4,102.4 801.8 241.0 188.3 — 20,805.1 Total Property, Plant and Equipment – Net $ 32,897.3 $ 18,598.3 $ 12,411.2 $ 1,864.4 $ 230.1 $ — $ 66,001.3 Total Assets (e) $ 46,974.2 $ 21,120.2 $ 13,873.3 $ 4,263.6 $ 5,846.5 (b) $ (4,409.1) (c) $ 87,668.7 Investments in Equity Method Investees $ 33.5 $ 2.5 $ 830.4 $ 487.8 $ 93.3 $ — $ 1,447.5 Long-term Debt Due Within One Year: Nonaffiliated $ 1,022.4 $ 716.1 $ 106.4 $ — $ 308.9 (d) $ — $ 2,153.8 Long-term Debt: Affiliated 65.0 — — — — (65.0) — Nonaffiliated 12,964.4 7,433.2 4,442.7 — 6,460.4 (d) — 31,300.7 Total Long-term Debt $ 14,051.8 $ 8,149.3 $ 4,549.1 $ — $ 6,769.3 $ (65.0) $ 33,454.5 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation & Marketing Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) 2020 Revenues from: External Customers $ 8,753.2 $ 4,238.7 $ 297.4 $ 1,621.0 $ 8.2 $ — $ 14,918.5 Other Operating Segments 126.2 107.2 901.4 104.6 88.6 (1,328.0) — Total Revenues $ 8,879.4 $ 4,345.9 $ 1,198.8 $ 1,725.6 $ 96.8 $ (1,328.0) $ 14,918.5 Depreciation and Amortization $ 1,600.5 $ 751.1 $ 257.6 $ 72.8 $ 0.8 $ — $ 2,682.8 Interest Expense 565.0 289.2 133.2 24.0 196.4 (42.1) 1,165.7 Income Tax Expense (Benefit) (7.0) 29.7 130.8 (108.0) (5.0) — 40.5 Equity Earnings of Unconsolidated Subsidiaries 2.9 — 82.4 3.2 2.6 — 91.1 Net Income (Loss) $ 1,064.5 $ 496.4 $ 508.5 $ 216.9 $ (89.6) $ — $ 2,196.7 Gross Property Additions $ 2,291.2 $ 2,108.1 $ 1,649.3 $ 197.0 $ 16.0 $ (15.3) $ 6,246.3 Total Property, Plant and Equipment $ 49,023.3 $ 21,145.0 $ 11,827.2 $ 1,910.2 $ 407.3 $ — $ 84,313.0 Accumulated Depreciation and Amortization 15,586.2 3,879.3 595.7 166.1 184.1 — 20,411.4 Total Property, Plant and Equipment – Net $ 33,437.1 $ 17,265.7 $ 11,231.5 $ 1,744.1 $ 223.2 $ — $ 63,901.6 Total Assets $ 42,752.7 $ 19,765.9 $ 12,627.3 $ 3,585.9 $ 5,987.1 (b) $ (3,961.7) (c) $ 80,757.2 Investments in Equity Method Investees $ 37.1 $ 2.1 $ 831.3 $ 467.0 $ 68.8 $ — $ 1,406.3 Long-term Debt Due Within One Year: Nonaffiliated $ 1,034.6 $ 588.8 $ 52.3 $ — $ 410.4 (d) $ — $ 2,086.1 Long-term Debt: Affiliated 65.0 — — — — (65.0) — Nonaffiliated 12,375.6 6,661.9 4,075.7 — 5,873.2 (d) — 28,986.4 Total Long-term Debt $ 13,475.2 $ 7,250.7 $ 4,128.0 $ — $ 6,283.6 $ (65.0) $ 31,072.5 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation & Marketing Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) 2019 Revenues from: External Customers $ 9,245.7 $ 4,319.0 $ 260.2 $ 1,721.8 $ 14.7 $ — $ 15,561.4 Other Operating Segments 121.4 163.5 813.0 135.8 81.1 (1,314.8) — Total Revenues $ 9,367.1 $ 4,482.5 $ 1,073.2 $ 1,857.6 $ 95.8 $ (1,314.8) $ 15,561.4 Asset Impairments and Other Related Charges $ 92.9 $ 32.5 $ — $ 31.0 $ — $ — $ 156.4 Depreciation and Amortization 1,447.0 789.5 183.4 69.5 0.6 24.5 (f) 2,514.5 Interest Expense 568.3 243.3 103.3 30.0 193.7 (66.1) (f) 1,072.5 Income Tax Expense (Benefit) (97.7) (25.2) 136.2 (53.8) 27.6 — (12.9) Equity Earnings (Loss) of Unconsolidated Subsidiaries 3.0 — 72.8 (3.8) 0.1 — 72.1 Net Income (Loss) $ 985.6 $ 451.0 $ 520.1 $ 104.1 $ (141.0) $ — $ 1,919.8 Gross Property Additions $ 2,437.4 $ 2,074.3 $ 1,458.9 $ 1,005.1 $ 14.5 $ (20.4) $ 6,969.8 Total Assets $ 41,228.8 $ 18,757.5 $ 11,143.5 $ 3,123.8 $ 5,440.0 (b) $ (3,801.3) (c)(f) $ 75,892.3 Investments in Equity Method Investees $ 41.7 $ 2.5 $ 787.5 $ 459.5 $ 65.4 $ — $ 1,356.6 Long-term Debt Due Within One Year: Affiliated $ 20.0 $ — $ — $ — $ — $ (20.0) $ — Nonaffiliated 704.7 392.2 — — 501.8 (d) — 1,598.7 Long-term Debt: Affiliated 39.0 — — — — (39.0) — Nonaffiliated 12,162.0 6,248.1 3,593.8 — 3,122.9 (d) — 25,126.8 Total Long-term Debt $ 12,925.7 $ 6,640.3 $ 3,593.8 $ — $ 3,624.7 $ (59.0) $ 26,725.5 (a) Corporate and Other primarily includes the purchasing of receivables from certain AEP utility subsidiaries. This segment also includes Parent’s guarantee revenue received from affiliates, investment income, interest income, interest expense and other nonallocated costs. (b) Includes elimination of AEP Parent’s investments in wholly-owned subsidiary companies. (c) Reconciling Adjustments for Total Assets primarily include elimination of intercompany advances to affiliates and intercompany accounts receivable. (d) Amounts reflect the impact of fair value hedge accounting. See “Accounting for Fair Value Hedging Strategies” section of Note 10 for additional information. (e) Amount includes Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (f) Includes eliminations due to an intercompany finance lease. Registrant Subsidiaries’ Reportable Segments (Applies to all Registrant Subsidiaries except AEPTCo) The Registrant Subsidiaries each have one reportable segment, an integrated electricity generation, transmission and distribution business for APCo, I&M, PSO and SWEPCo, and an integrated electricity transmission and distribution business for AEP Texas and OPCo. Other activities are insignificant. The Registrant Subsidiaries’ operations are managed on an integrated basis because of the substantial impact of cost-based rates and regulatory oversight on the business process, cost structures and operating results. AEPTCo’s Reportable Segments AEPTCo Parent is the holding company of seven FERC-regulated transmission-only electric utilities. The seven State Transcos have been identified as operating segments of AEPTCo under the accounting guidance for “Segment Reporting.” The State Transcos business consists of developing, constructing and operating transmission facilities at the request of the RTOs in which they operate and in replacing and upgrading facilities, assets and components of the existing AEP transmission system as needed to maintain reliability standards and provide service to AEP’s wholesale and retail customers. The State Transcos are regulated for rate-making purposes exclusively by the FERC and earn revenues through tariff rates charged for the use of their electric transmission systems. AEPTCo’s Chief Operating Decision Maker makes operating decisions, allocates resources to and assesses performance-based on these operating segments. The seven State Transcos operating segments all have similar economic characteristics and meet all of the criteria under the accounting guidance for “Segment Reporting” to be aggregated into one operating segment. As a result, AEPTCo has one reportable segment. The remainder of AEPTCo’s activity is presented in AEPTCo Parent. While not considered a reportable segment, AEPTCo Parent represents the activity of the holding company which primarily relates to debt financing activity and general corporate activities. The tables below present AEPTCo’s reportable segment income statement information for the years ended December 31, 2021, 2020 and 2019 and reportable segment balance sheet information as of December 31, 2021 and 2020. State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo 2021 (in millions) Revenues from: External Customers $ 315.1 $ — $ — $ 315.1 Sales to AEP Affiliates 1,153.9 — — 1,153.9 Other Revenues 0.3 — — 0.3 Total Revenues $ 1,469.3 $ — $ — $ 1,469.3 Depreciation and Amortization $ 297.3 $ — $ — $ 297.3 Interest Income 0.1 158.1 (157.7) (a) 0.5 Allowance for Equity Funds Used During Construction 67.2 — — 67.2 Interest Expense 141.2 157.7 (157.7) (a) 141.2 Income Tax Expense 144.1 — — 144.1 Net Income $ 591.5 $ 0.2 (b) $ — $ 591.7 Gross Property Additions $ 1,442.7 $ — $ — $ 1,442.7 Total Transmission Property $ 12,708.5 $ — $ — $ 12,708.5 Accumulated Depreciation and Amortization 772.8 — — 772.8 Total Transmission Property - Net $ 11,935.7 $ — $ — $ 11,935.7 Notes Receivable - Affiliated $ — $ 4,343.9 $ (4,343.9) (c) $ — Total Assets (f) $ 12,564.3 $ 4,389.5 (d) $ (4,429.4) (e) $ 12,524.4 Total Long-Term Debt $ 4,390.0 $ 4,343.9 $ (4,390.0) (c) $ 4,343.9 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo 2020 (in millions) Revenues from: External Customers $ 248.8 $ — $ — $ 248.8 Sales to AEP Affiliates 896.3 — — 896.3 Other Revenues 0.6 — — 0.6 Total Revenues $ 1,145.7 $ — $ — $ 1,145.7 Depreciation and Amortization $ 249.0 $ — $ — $ 249.0 Interest Income 0.9 149.6 (148.1) (a) 2.4 Allowance for Equity Funds Used During Construction 74.0 — — 74.0 Interest Expense 127.8 148.1 (148.1) (a) 127.8 Income Tax Expense 106.5 0.2 — 106.7 Net Income $ 422.3 $ 1.1 (b) $ — $ 423.4 Gross Property Additions $ 1,621.9 $ — $ — $ 1,621.9 Total Transmission Property $ 11,345.6 $ — $ — $ 11,345.6 Accumulated Depreciation and Amortization 572.8 — — 572.8 Total Transmission Property - Net $ 10,772.8 $ — $ — $ 10,772.8 Notes Receivable - Affiliated $ — $ 3,948.5 $ (3,948.5) (c) $ — Total Assets $ 11,185.1 $ 4,084.0 (d) $ (4,023.1) (e) $ 11,246.0 Total Long-Term Debt $ 3,990.0 $ 3,948.5 $ (3,990.0) (c) $ 3,948.5 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo 2019 (in millions) Revenues from: External Customers $ 214.6 $ — $ — $ 214.6 Sales to AEP Affiliates 806.7 — — 806.7 Other Revenue 0.1 — — 0.1 Total Revenues $ 1,021.4 $ — $ — $ 1,021.4 Depreciation and Amortization $ 176.0 $ — $ — $ 176.0 Interest Income 1.3 123.8 (122.1) (a) 3.0 Allowance for Equity Funds Used During Construction 84.3 — — 84.3 Interest Expense 97.4 122.1 (122.1) (a) 97.4 Income Tax Expense 117.1 0.3 — 117.4 Net Income $ 438.6 $ 1.1 (b) $ — $ 439.7 Gross Property Additions $ 1,419.5 $ — $ — $ 1,419.5 Total Assets $ 9,865.0 $ 3,519.1 (d) $ (3,493.3) (e) $ 9,890.8 Total Long-Term Debt $ 3,465.0 $ 3,427.3 $ (3,465.0) (c) $ 3,427.3 (a) Elimination of intercompany interest income/interest expense on affiliated debt arrangement. (b) Includes elimination of AEPTCo Parent’s equity earnings in the State Transcos. (c) Elimination of intercompany debt. (d) Includes elimination of AEPTCo Parent’s investments in the State Transcos. (e) Primarily relates to elimination of Notes Receivable from the State Transcos. (f) Amount includes Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.

Derivatives and Hedging

Derivatives and Hedging	12 Months Ended
Derivatives and Hedging	Dec. 31, 2021
Derivatives and Hedging	DERIVATIVES AND HEDGING The disclosures in this note apply to all Registrants unless indicated otherwise. For the periods presented, AEPTCo did not have any derivative and hedging activity. OBJECTIVES FOR UTILIZATION OF DERIVATIVE INSTRUMENTS AEPSC is agent for and transacts on behalf of certain AEP subsidiaries, including the Registrant Subsidiaries. AEPEP is agent for and transacts on behalf of other AEP subsidiaries. The Registrants are exposed to certain market risks as major power producers and participants in the electricity, capacity, natural gas, coal and emission allowance markets. These risks include commodity price risks which may be subject to capacity risk, interest rate risk and credit risk. These risks represent the risk of loss that may impact the Registrants due to changes in the underlying market prices or rates. Management utilizes derivative instruments to manage these risks. STRATEGIES FOR UTILIZATION OF DERIVATIVE INSTRUMENTS TO ACHIEVE OBJECTIVES Risk Management Strategies The strategy surrounding the use of derivative instruments primarily focuses on managing risk exposures, future cash flows and creating value utilizing both economic and formal hedging strategies. The risk management strategies also include the use of derivative instruments for trading purposes which focus on seizing market opportunities to create value driven by expected changes in the market prices of the commodities. To accomplish these objectives, the Registrants primarily employ risk management contracts including physical and financial forward purchase-and-sale contracts and, to a lesser extent, OTC swaps and options. Not all risk management contracts meet the definition of a derivative under the accounting guidance for “Derivatives and Hedging.” Derivative risk management contracts elected normal under the normal purchases and normal sales scope exception are not subject to the requirements of this accounting guidance. The Registrants utilize power, capacity, coal, natural gas, interest rate and, to a lesser extent, heating oil, gasoline and other commodity contracts to manage the risk associated with the energy business. The Registrants utilize interest rate derivative contracts in order to manage the interest rate exposure associated with the commodity portfolio. For disclosure purposes, such risks are grouped as “Commodity,” as these risks are related to energy risk management activities. The Registrants also utilize derivative contracts to manage interest rate risk associated with debt financing. For disclosure purposes, these risks are grouped as “Interest Rate.” The amount of risk taken is determined by the Commercial Operations, Energy Supply and Finance groups in accordance with established risk management policies as approved by the Finance Committee of the Board of Directors. The following tables represent the gross notional volume of the Registrants’ outstanding derivative contracts: December 31, 2021 Primary Risk Unit of AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power MWhs 287.9 — 33.1 13.6 2.7 11.9 3.4 Natural Gas MMBtus 34.1 — — — — 1.3 5.1 Heating Oil and Gasoline Gallons 7.4 1.9 1.1 0.7 1.5 0.8 1.0 Interest Rate USD $ 116.5 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt USD $ 950.0 $ — $ — $ — $ — $ — $ — December 31, 2020 Primary Risk Unit of AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power MWhs 331.3 — 46.9 19.7 3.0 11.9 4.0 Natural Gas MMBtus 26.9 — — — — — 7.9 Heating Oil and Gasoline Gallons 6.9 1.8 1.1 0.6 1.4 0.7 0.9 Interest Rate USD $ 129.8 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt USD $ 1,150.0 $ — $ 200.0 $ — $ — $ — $ — Fair Value Hedging Strategies (Applies to AEP) Parent enters into interest rate derivative transactions as part of an overall strategy to manage the mix of fixed-rate and floating-rate debt. Certain interest rate derivative transactions effectively modify exposure to interest rate risk by converting a portion of fixed-rate debt to a floating-rate. Provided specific criteria are met, these interest rate derivatives may be designated as fair value hedges. Cash Flow Hedging Strategies The Registrants utilize cash flow hedges on certain derivative transactions for the purchase-and-sale of power (“Commodity”) in order to manage the variable price risk related to forecasted purchases and sales. Management monitors the potential impacts of commodity price changes and, where appropriate, enters into derivative transactions to protect profit margins for a portion of future electricity sales and purchases. The Registrants do not hedge all commodity price risk. The Registrants utilize a variety of interest rate derivative transactions in order to manage interest rate risk exposure. The Registrants also utilize interest rate derivative contracts to manage interest rate exposure related to future borrowings of fixed-rate debt. The Registrants do not hedge all interest rate exposure. ACCOUNTING FOR DERIVATIVE INSTRUMENTS AND THE IMPACT ON THE FINANCIAL STATEMENTS The accounting guidance for “Derivatives and Hedging” requires recognition of all qualifying derivative instruments as either assets or liabilities on the balance sheets at fair value. The fair values of derivative instruments accounted for using MTM accounting or hedge accounting are based on exchange prices and broker quotes. If a quoted market price is not available, the estimate of fair value is based on the best information available including valuation models that estimate future energy prices based on existing market and broker quotes and other assumptions. In order to determine the relevant fair values of the derivative instruments, the Registrants apply valuation adjustments for discounting, liquidity and credit quality. Credit risk is the risk that a counterparty will fail to perform on the contract or fail to pay amounts due. Liquidity risk represents the risk that imperfections in the market will cause the price to vary from estimated fair value based upon prevailing market supply and demand conditions. Since energy markets are imperfect and volatile, there are inherent risks related to the underlying assumptions in models used to fair value risk management contracts. Unforeseen events may cause reasonable price curves to differ from actual price curves throughout a contract’s term and at the time a contract settles. Consequently, there could be significant adverse or favorable effects on future net income and cash flows if market prices are not consistent with management’s estimates of current market consensus for forward prices in the current period. This is particularly true for longer term contracts. Cash flows may vary based on market conditions, margin requirements and the timing of settlement of risk management contracts. According to the accounting guidance for “Derivatives and Hedging,” the Registrants reflect the fair values of derivative instruments subject to netting agreements with the same counterparty net of related cash collateral. For certain risk management contracts, the Registrants are required to post or receive cash collateral based on third-party contractual agreements and risk profiles. AEP netted cash collateral received from third-parties against short-term and long-term risk management assets in the amounts of $263 million and $3 million as of December 31, 2021 and 2020, respectively. AEP netted cash collateral paid to third-parties against short-term and long-term risk management liabilities in the amounts of $3 million and $7 million as of December 31, 2021 and 2020, respectively. The netted cash collateral from third-parties against short-term and long-term risk management assets and netted cash collateral paid to third-parties against short-term and long-term risk management liabilities were immaterial for the Registrant Subsidiaries as of December 31, 2021 and 2020. The following tables represent the gross fair value of the Registrants’ derivative activity on the balance sheets: AEP December 31, 2021 Risk Hedging Contracts Gross Amounts Gross Net Amounts of Balance Sheet Location Commodity (a) Commodity (a) Interest Rate (a) (in millions) Current Risk Management Assets (d) $ 513.4 $ 176.0 $ 1.2 $ 690.6 $ (496.2) $ 194.4 Long-term Risk Management Assets 370.5 89.1 — 459.6 (192.6) 267.0 Total Assets 883.9 265.1 1.2 1,150.2 (688.8) 461.4 Current Risk Management Liabilities (e) 395.7 40.9 — 436.6 (361.2) 75.4 Long-term Risk Management Liabilities 243.9 16.7 38.1 298.7 (68.4) 230.3 Total Liabilities 639.6 57.6 38.1 735.3 (429.6) 305.7 Total MTM Derivative Contract Net Assets (Liabilities) $ 244.3 $ 207.5 $ (36.9) $ 414.9 $ (259.2) $ 155.7 December 31, 2020 Risk Hedging Contracts Gross Amounts Gross Net Amounts of Balance Sheet Location Commodity (a) Commodity (a) Interest Rate (a) (in millions) Current Risk Management Assets $ 239.1 $ 21.1 $ 5.0 $ 265.2 $ (170.5) $ 94.7 Long-term Risk Management Assets 275.9 18.0 — 293.9 (51.7) 242.2 Total Assets 515.0 39.1 5.0 559.1 (222.2) 336.9 Current Risk Management Liabilities 193.0 54.4 3.4 250.8 (172.0) 78.8 Long-term Risk Management Liabilities 222.2 60.1 4.1 286.4 (53.6) 232.8 Total Liabilities 415.2 114.5 7.5 537.2 (225.6) 311.6 Total MTM Derivative Contract Net Assets (Liabilities) $ 99.8 $ (75.4) $ (2.5) $ 21.9 $ 3.4 $ 25.3 AEP Texas December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts - in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 0.6 $ (0.6) $ — Long-term Risk Management Assets — — — Total Assets 0.6 (0.6) — Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — — — Total Liabilities — — — Total MTM Derivative Net Assets (Liabilities) $ 0.6 $ (0.6) $ — December 31, 2020 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts - in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 0.4 $ (0.4) $ — Long-term Risk Management Assets — — — Total Assets 0.4 (0.4) — Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — — — Total Liabilities — — — Total MTM Derivative Net Assets (Liabilities) $ 0.4 $ (0.4) $ — APCo December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts - in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 47.5 $ (5.5) $ 42.0 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets 0.2 (0.2) — Total Assets 47.7 (5.7) 42.0 Other Current Liabilities - Current Risk Management Liabilities 7.2 (6.4) 0.8 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities 0.2 (0.2) — Total Liabilities 7.4 (6.6) 0.8 Total MTM Derivative Net Assets $ 40.3 $ 0.9 $ 41.2 December 31, 2020 Risk Gross Amounts of Risk Gross Amounts Net Amounts of Assets/ Management Hedging Management Offset in the Liabilities Presented in Contracts - Contracts Assets/Liabilities Statement of the Statement of Balance Sheet Location Commodity (a) Interest Rate (a) Recognized Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 38.8 $ 2.4 $ 41.2 $ (18.8) $ 22.4 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets 0.7 — 0.7 (0.6) 0.1 Total Assets 39.5 2.4 41.9 (19.4) 22.5 Other Current Liabilities - Current Risk Management Liabilities 19.7 3.4 23.1 (18.5) 4.6 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities 0.6 — 0.6 (0.5) 0.1 Total Liabilities 20.3 3.4 23.7 (19.0) 4.7 Total MTM Derivative Contract Net Assets (Liabilities) $ 19.2 $ (1.0) $ 18.2 $ (0.4) $ 17.8 I&M December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts - in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 11.1 $ (7.8) $ 3.3 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets 0.2 (0.2) — Total Assets 11.3 (8.0) 3.3 Current Risk Management Liabilities 14.8 (9.8) 5.0 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities 0.2 (0.2) — Total Liabilities 15.0 (10.0) 5.0 Total MTM Derivative Contract Net Assets (Liabilities) $ (3.7) $ 2.0 $ (1.7) December 31, 2020 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts - in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 17.2 $ (13.6) $ 3.6 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets 0.5 (0.4) 0.1 Total Assets 17.7 (14.0) 3.7 Current Risk Management Liabilities 12.1 (12.0) 0.1 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities 0.4 (0.3) 0.1 Total Liabilities 12.5 (12.3) 0.2 Total MTM Derivative Contract Net Assets (Liabilities) $ 5.2 $ (1.7) $ 3.5 OPCo December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts - in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 0.5 $ (0.5) $ — Long-term Risk Management Assets — — — Total Assets 0.5 (0.5) — Current Risk Management Liabilities 6.7 — 6.7 Long-term Risk Management Liabilities 85.8 — 85.8 Total Liabilities 92.5 — 92.5 Total MTM Derivative Contract Net Liabilities $ (92.0) $ (0.5) $ (92.5) December 31, 2020 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts - in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 0.3 $ (0.3) $ — Long-term Risk Management Assets — — — Total Assets 0.3 (0.3) — Current Risk Management Liabilities 8.7 — 8.7 Long-term Risk Management Liabilities 101.6 — 101.6 Total Liabilities 110.3 — 110.3 Total MTM Derivative Contract Net Liabilities $ (110.0) $ (0.3) $ (110.3) PSO December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts - in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 12.4 $ (0.3) $ 12.1 Long-term Risk Management Assets — — — Total Assets 12.4 (0.3) 12.1 Current Risk Management Liabilities 3.7 — 3.7 Long-term Risk Management Liabilities — — — Total Liabilities 3.7 — 3.7 Total MTM Derivative Net Assets (Liabilities) $ 8.7 $ (0.3) $ 8.4 December 31, 2020 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts - in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 10.5 $ (0.2) $ 10.3 Long-term Risk Management Assets — — — Total Assets 10.5 (0.2) 10.3 Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — — — Total Liabilities — — — Total MTM Derivative Net Assets (Liabilities) $ 10.5 $ (0.2) $ 10.3 SWEPCo December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts - in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 10.1 $ (0.3) $ 9.8 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets 1.1 — 1.1 Total Assets 11.2 (0.3) 10.9 Current Risk Management Liabilities 2.1 — 2.1 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities — — — Total Liabilities 2.1 — 2.1 Total MTM Derivative Net Assets (Liabilities) $ 9.1 $ (0.3) $ 8.8 December 31, 2020 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts - in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 3.4 $ (0.2) $ 3.2 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets — — — Total Assets 3.4 (0.2) 3.2 Current Risk Management Liabilities 0.7 — 0.7 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities 1.0 — 1.0 Total Liabilities 1.7 — 1.7 Total MTM Derivative Net Assets (Liabilities) $ 1.7 $ (0.2) $ 1.5 (a) Derivative instruments within these categories are disclosed as gross. These instruments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with the accounting guidance for “Derivatives and Hedging.” (b) Amounts include counterparty netting of risk management and hedging contracts and associated cash collateral in accordance with the accounting guidance for “Derivatives and Hedging.” (c) All derivative contracts subject to a master netting arrangement or similar agreement are offset in the statement of financial position. (d) Amount excludes Risk Management Assets of $6 million classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (e) Amount excludes Risk Management Liabilities of $0.1 million classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. The tables below present the Registrants’ amount of gain (loss) recognized on risk management contracts: Year Ended December 31, 2021 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ (0.6) $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 169.1 — — — — — — Electric Generation, Transmission and Distribution Revenues — — (0.5) (0.1) — — — Purchased Electricity for Resale 2.0 — 1.8 — — — — Other Operation 2.8 0.8 0.3 0.3 0.5 0.3 0.4 Maintenance 3.4 1.0 0.5 0.3 0.6 0.4 0.5 Regulatory Assets (a) (9.1) — (2.7) (14.8) 10.0 (3.6) 3.6 Regulatory Liabilities (a) 156.4 0.2 55.9 (3.9) — 48.9 37.0 Total Gain (Loss) on Risk Management Contracts $ 324.0 $ 2.0 $ 55.3 $ (18.2) $ 11.1 $ 46.0 $ 41.5 Year Ended December 31, 2020 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 0.8 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 9.5 — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.4 0.1 — — 0.1 Purchased Electricity for Resale 1.4 — 1.2 0.1 — — — Other Operation (2.0) (0.6) (0.2) (0.2) (0.3) (0.2) (0.3) Maintenance (2.9) (0.8) (0.4) (0.3) (0.5) (0.3) (0.4) Regulatory Assets (a) (4.8) — — (0.1) (6.6) — 1.4 Regulatory Liabilities (a) 114.9 0.4 20.3 12.4 12.4 39.1 20.2 Total Gain (Loss) on Risk Management Contracts $ 116.9 $ (1.0) $ 21.3 $ 12.0 $ 5.0 $ 38.6 $ 21.0 Year Ended December 31, 2019 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 0.7 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 25.1 — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.1 0.5 — — 0.1 Purchased Electricity for Resale 1.9 — 1.6 0.1 — — — Other Operation (0.8) (0.2) (0.1) (0.1) (0.2) (0.1) (0.1) Maintenance (0.8) (0.2) (0.2) (0.1) (0.2) (0.1) (0.1) Regulatory Assets (a) (3.7) 0.7 0.3 0.3 (3.7) 1.2 (1.5) Regulatory Liabilities (a) 102.6 — 2.4 24.5 10.1 34.6 26.6 Total Gain on Risk Management Contracts $ 125.0 $ 0.3 $ 4.1 $ 25.2 $ 6.0 $ 35.6 $ 25.0 (a) Represents realized and unrealized gains and losses subject to regulatory accounting treatment recorded as either current or noncurrent on the balance sheets. Certain qualifying derivative instruments have been designated as normal purchase or normal sale contracts, as provided in the accounting guidance for “Derivatives and Hedging.” Derivative contracts that have been designated as normal purchases or normal sales under that accounting guidance are not subject to MTM accounting treatment and are recognized on the statements of income on an accrual basis. The accounting for the changes in the fair value of a derivative instrument depends on whether it qualifies for and has been designated as part of a hedging relationship and further, on the type of hedging relationship. Depending on the exposure, management designates a hedging instrument as a fair value hedge or a cash flow hedge. For contracts that have not been designated as part of a hedging relationship, the accounting for changes in fair value depends on whether the derivative instrument is held for trading purposes. Unrealized and realized gains and losses on derivative instruments held for trading purposes are included in revenues on a net basis on the statements of income. Unrealized and realized gains and losses on derivative instruments not held for trading purposes are included in revenues or expenses on the statements of income depending on the relevant facts and circumstances. Certain derivatives that economically hedge future commodity risk are recorded in the same line item on the statements of income as that of the associated risk being hedged. However, unrealized and some realized gains and losses in regulated jurisdictions for both trading and non-trading derivative instruments are recorded as regulatory assets (for losses) or regulatory liabilities (for gains) in accordance with the accounting guidance for “Regulated Operations.” Accounting for Fair Value Hedging Strategies (Applies to AEP) For fair value hedges (i.e. hedging the exposure to changes in the fair value of an asset, liability or an identified portion thereof attributable to a particular risk), the gain or loss on the derivative instrument as well as the offsetting gain or loss on the hedged item associated with the hedged risk impacts net income during the period of change. AEP records realized and unrealized gains or losses on interest rate swaps that are designated and qualify for fair value hedge accounting treatment and any offsetting changes in the fair value of the debt being hedged in Interest Expense on the statements of income. The following table shows the impacts recognized on the balance sheets related to the hedged items in fair value hedging relationships: Carrying Amount of the Hedged Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of the Hedged Assets/(Liabilities) December 31, 2021 December 31, 2020 December 31, 2021 December 31, 2020 (in millions) Long-term Debt (a) (b) $ (952.3) $ (995.9) $ (8.5) $ (51.7) (a) Amounts included on the balance sheets within Long-term Debt Due within One Year and Long-term Debt, respectively. (b) Amounts include $(46) million and $(53) million as of December 31, 2021 and 2020, respectively, for the fair value hedge adjustment of hedged debt obligations for which hedge accounting has been discontinued. The pretax effects of fair value hedge accounting on income were as follows: Years Ended December 31, 2021 2020 2019 (in millions) Gain (Loss) on Interest Rate Contracts: Fair Value Hedging Instruments (a) $ (35.5) $ 41.1 $ 31.9 Fair Value Portion of Long-term Debt (a) 35.5 (41.1) (31.9) (a) Gain (Loss) is included in Interest Expense on the statements of income. In June 2020, AEP terminated a $500 million notional amount interest rate swap resulting in the discontinuance of the hedging relationship. A gain of $57 million on the fair value of the hedging instrument was settled in cash and recorded within operating activities on the statement of cash flows. Subsequent to the discontinuation of hedge accounting, the remaining adjustment to the carrying amount of the hedged item of $57 million will be amortized on a straight-line basis through November 2027 in Interest Expense on the statements of income. Accounting for Cash Flow Hedging Strategies (Applies to AEP, APCo, I&M, PSO and SWEPCo) For cash flow hedges (i.e. hedging the exposure to variability in expected future cash flows that is attributable to a particular risk), the Registrants initially report the gain or loss on the derivative instrument as a component of Accumulated Other Comprehensive Income (Loss) on the balance sheets until the period the hedged item affects net income. Realized gains and losses on derivative contracts for the purchase and sale of power designated as cash flow hedges are included in Total Revenues or Purchased Electricity for Resale on the statements of income or in Regulatory Assets or Regulatory Liabilities on the balance sheets, depending on the specific nature of the risk being hedged. During the years ended 2021, 2020 and 2019, AEP applied cash flow hedging to outstanding power derivatives and the Registrant Subsidiaries did not. The Registrants reclassify gains and losses on interest rate derivative hedges related to debt financings from Accumulated Other Comprehensive Income (Loss) on the balance sheets into Interest Expense on the statements of income in those periods in which hedged interest payments occur. During the years ended 2021, 2020 and 2019, AEP applied cash flow hedging to outstanding interest rate derivatives. During the years ended 2021 and 2020, APCo applied cash flow hedging to outstanding interest rate derivatives and the other Registrant Subsidiaries did not. During the year ended 2019, the Registrant Subsidiaries did not apply cash flow hedging to outstanding interest rate derivatives. For details on effective cash flow hedges included in Accumulated Other Comprehensive Income (Loss) on the balance sheets and the reasons for changes in cash flow hedges, see Note 3 - Comprehensive Income. Cash flow hedges included in Accumulated Other Comprehensive Income (Loss) on the balance sheets were: Impact of Cash Flow Hedges on AEP’s Balance Sheets December 31, 2021 December 31, 2020 Commodity Interest Rate Commodity Interest Rate (in millions) AOCI Gain (Loss) Net of Tax $ 163.7 $ (21.3) $ (60.6) $ (47.5) Portion Expected to be Reclassed to Net Income During the Next Twelve Months 106.7 (3.3) (27.1) (5.7) As of December 31, 2021 the maximum length of time that AEP is hedging its exposure to variability in future cash flows related to forecasted transactions is 111 months and 108 months for commodity and interest rate hedges, respectively. Impact of Cash Flow Hedges on the Registrant Subsidiaries’ Balance Sheets December 31, 2021 December 31, 2020 Interest Rate Expected to be Expected to be Reclassified to Reclassified to Net Income During Net Income During AOCI Gain (Loss) the Next AOCI Gain (Loss) the Next Company Net of Tax Twelve Months Net of Tax Twelve Months (in millions) AEP Texas $ (1.3) $ (1.1) $ (2.3) $ (1.1) APCo 7.5 0.8 (0.8) 0.4 I&M (6.7) (1.6) (8.3) (1.6) PSO — — 0.1 0.1 SWEPCo 1.2 0.1 (0.3) (1.5) The actual amounts reclassified from Accumulated Other Comprehensive Income (Loss) to Net Income can differ from the estimate above due to market price changes. Credit Risk Management mitigates credit risk in wholesale marketing and trading activities by assessing the creditworthiness of potential counterparties before entering into transactions with them and continuing to evaluate their creditworthiness on an ongoing basis. Management uses credit agency ratings and current market-based qualitative and quantitative data as well as financial statements to assess the financial health of counterparties on an ongoing basis. Master agreements are typically used to facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Collateral requirements in the form of cash, letters of credit, surety bonds and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. Some master agreements include margining, which requires a counterparty to post cash or letters of credit in the event exposure exceeds the established threshold. The threshold represents an unsecured credit limit which may be supported by a parental/affiliate guaranty, as determined in accordance with AEP’s credit policy. In addition, master agreements allow for termination and liquidation of all positions in the event of a default including a failure or inability to post collateral when required. Collateral Triggering Events Credit Downgrade Triggers (Applies to AEP, APCo, I&M, PSO and SWEPCo) A limited number of derivative contracts include collateral triggering events, which include a requirement to maintain certain credit ratings. On an ongoing basis, AEP’s risk management organization assesses the appropriateness of these collateral triggering events in contracts. The Registrants have not experienced a downgrade below a specified credit rating threshold that would require the posting of additional collateral. AEP had derivative contracts with collateral triggering events in a net liability position as of December 31, 2021, with a total exposure of $9 million. The Registrant Subsidiaries had no derivative contracts with collateral triggering events in a net liability position as of December 31, 2021. The Registrants had no derivative contracts with collateral triggering events in a net liability position as of December 31, 2020. Cross-Default Triggers (Applies to AEP, APCo, I&M and SWEPCo) In addition, a majority of non-exchange-traded commodity contracts contain cross-default provisions that, if triggered, would permit the counterparty to declare a default and require settlement of the outstanding payable. These cross-default provisions could be triggered if there was a non-performance event by Parent or the obligor under outstanding debt or a third-party obligation that is $50 million or greater. On an ongoing basis, AEP’s risk management organization assesses the appropriateness of these cross-default provisions in the contracts. The following tables represent: (a) the fair value of these derivative liabilities subject to cross-default provisions prior to consideration of contractual netting arrangements, (b) the amount that the exposure has been reduced by cash collateral posted and (c) if a cross-default provision would have been triggered, the settlement amount that would be required after considering contractual netting arrangements: December 31, 2021 Liabilities for Additional Contracts with Cross Settlement Default Provisions Liability if Cross Prior to Contractual Amount of Cash Default Provision Company Netting Arrangements Collateral Posted is Triggered (in millions) AEP $ 159.5 $ — $ 115.4 APCo 0.5 — 0.3 I&M 0.3 — 0.2 PSO 1.7 — 1.7 SWEPCo 2.7 — 2.7 December 31, 2020 Liabilities for Additional Contracts with Cross Settlement Default Provisions Liability if Cross Prior to Contractual Amount of Cash Default Provision Company Netting Arrangements Collateral Posted is Triggered (in millions) AEP $ 188.4 $ — $ 169.2 APCo 4.3 — 3.5 I&M 0.5 — 0.1 SWEPCo 1.8 — 1.8 Warrants Held in Investee (Applies to AEP) AEP holds an investment in ChargePoint, which completed an initial public offering (IPO) in February 2021 via a reverse merger with a public special purpose acquisition company. Before the IPO, AEP’s interests in ChargePoint consisted of a noncontrolling equity interest of preferred shares, which were accounted for at their historical cost of $8 million as of December 31, 2020, and common share warrants. After the IPO, AEP’s interests in ChargePoint consisted of a noncontrolling equity interest of common shares, which were accounted for at their fair value of $29 million as of December 31, 2021, and common share warrants. AEP recorded an unrealized gain of $26 million associated with the common shares for the twelve months ended December 31, 2021 presented in Other Income (Expense) on AEP’s statements of income. Management has determined the common share warrants are derivative instruments based on the accounting guidance for “Derivatives and Hedging”. As of December 31, 2021 and 2020, the warrants were valued at $15 million and $32 million, respectively, and were recorded in Deferred Charges and Other Noncurrent Assets on AEP’s balance sheets. AEP recognized an unrealized loss of $17 million and an unrealized gain of $32 million associated with the warrants for the years ended December 31, 20

Fair Value Measurements

Fair Value Measurements	12 Months Ended
Fair Value Measurements	Dec. 31, 2021
Fair Value Measurements	FAIR VALUE MEASUREMENTS The disclosures in this note apply to all Registrants except AEPTCo unless indicated otherwise. Fair Value Measurements of Long-term Debt (Applies to all Registrants) The fair values of Long-term Debt are based on quoted market prices, without credit enhancements, for the same or similar issues and the current interest rates offered for instruments with similar maturities classified as Level 2 measurement inputs. These instruments are not marked-to-market. The estimates presented are not necessarily indicative of the amounts that could be realized in a current market exchange. The fair value of AEP’s Equity Units (Level 1) are valued based on publicly-traded securities issued by AEP. The book values and fair values of Long-term Debt are summarized in the following table: December 31, 2021 2020 Company Book Value Fair Value Book Value Fair Value (in millions) AEP (a)(b)(c) $ 33,454.5 $ 37,564.7 $ 31,072.5 $ 37,457.0 AEP Texas 5,180.8 5,663.8 4,820.4 5,682.6 AEPTCo 4,343.9 4,968.2 3,948.5 4,984.3 APCo 4,938.9 6,037.1 4,834.1 6,391.8 I&M 3,195.0 3,748.0 3,029.9 3,775.3 OPCo 2,968.5 3,437.5 2,430.2 3,154.9 PSO 1,913.5 2,163.7 1,373.8 1,732.1 SWEPCo 3,395.2 3,792.9 2,636.4 3,210.1 (a) The fair value amounts include debt related to AEP’s Equity Units and had a fair value of $1.7 billion and $1.7 billion as of December 31, 2021 and 2020, respectively. See “Equity Units” section of Note 14 for additional information. (b) The 2021 book value amount excludes Long-term Debt of $1.1 billion classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (c) The 2021 fair value amount excludes Long-term Debt of $1.2 billion related to KPCo. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. Fair Value Measurements of Other Temporary Investments (Applies to AEP) Other Temporary Investments include marketable securities that management intends to hold for less than one year and investments by AEP’s protected cell of EIS. See “Other Temporary Investments” section of Note 1 for additional information. The following is a summary of Other Temporary Investments and Restricted Cash: December 31, 2021 Gross Gross Unrealized Unrealized Fair Other Temporary Investments and Restricted Cash Cost Gains Losses Value (in millions) Restricted Cash (a) $ 48.0 $ — $ — $ 48.0 Other Cash Deposits 10.0 — — 10.0 Fixed Income Securities – Mutual Funds (b) 154.3 0.5 — 154.8 Equity Securities – Mutual Funds 19.7 35.9 — 55.6 Total Other Temporary Investments and Restricted Cash $ 232.0 $ 36.4 $ — $ 268.4 December 31, 2020 Gross Gross Unrealized Unrealized Fair Other Temporary Investments and Restricted Cash Cost Gains Losses Value (in millions) Restricted Cash (a) $ 45.6 $ — $ — $ 45.6 Other Cash Deposits 22.7 — — 22.7 Fixed Income Securities – Mutual Funds (b) 120.7 2.8 — 123.5 Equity Securities – Mutual Funds 25.9 28.7 — 54.6 Total Other Temporary Investments and Restricted Cash $ 214.9 $ 31.5 $ — $ 246.4 (a) Primarily represents amounts held for the repayment of debt. (b) Primarily short and intermediate maturities which may be sold and do not contain maturity dates. The following table provides the activity for fixed income and equity securities within Other Temporary Investments: Years Ended December 31, 2021 2020 2019 (in millions) Proceeds from Investment Sales $ 15.0 $ 50.9 $ 21.2 Purchases of Investments 26.9 41.6 45.0 Gross Realized Gains on Investment Sales 3.6 3.8 — Gross Realized Losses on Investment Sales — 0.2 0.4 Fair Value Measurements of Trust Assets for Decommissioning and SNF Disposal (Applies to AEP and I&M) Securities held in trust funds for decommissioning nuclear facilities and for the disposal of SNF are recorded at fair value. See “Nuclear Trust Funds” section of Note 1 for additional information. The following is a summary of nuclear trust fund investments: December 31, 2021 2020 Gross Other-Than- Gross Other-Than- Fair Unrealized Temporary Fair Unrealized Temporary Value Gains Impairments Value Gains Impairments (in millions) Cash and Cash Equivalents $ 84.7 $ — $ — $ 25.8 $ — $ — Fixed Income Securities: United States Government 1,156.4 66.3 (7.9) 1,025.6 98.5 (7.1) Corporate Debt 76.7 6.7 (2.1) 86.3 9.6 (1.7) State and Local Government 7.3 0.4 (0.1) 114.3 0.9 (0.4) Subtotal Fixed Income Securities 1,240.4 73.4 (10.1) 1,226.2 109.0 (9.2) Equity Securities - Domestic (a) 2,541.9 1,901.3 — 2,054.7 1,400.8 — Spent Nuclear Fuel and Decommissioning Trusts $ 3,867.0 $ 1,974.7 $ (10.1) $ 3,306.7 $ 1,509.8 $ (9.2) (a) Amount reported as Gross Unrealized Gains includes unrealized gains of $1.9 billion and $1.4 billion and unrealized losses of $4 million and $9 million as of December 31, 2021 and 2020, respectively. The following table provides the securities activity within the decommissioning and SNF trusts: Years Ended December 31, 2021 2020 2019 (in millions) Proceeds from Investment Sales $ 1,886.4 $ 1,593.4 $ 1,473.0 Purchases of Investments 1,928.2 1,637.2 1,531.0 Gross Realized Gains on Investment Sales 103.2 26.4 76.5 Gross Realized Losses on Investment Sales 16.5 26.1 24.3 The base cost of fixed income securities was $1.2 billion and $1.1 billion as of December 31, 2021 and 2020, respectively. The base cost of equity securities was $641 million and $654 million as of December 31, 2021 and 2020, respectively. The fair value of fixed income securities held in the nuclear trust funds, summarized by contractual maturities, as of December 31, 2021 was as follows: Fair Value of Fixed Income Securities (in millions) Within 1 year $ 302.4 After 1 year through 5 years 431.2 After 5 years through 10 years 227.7 After 10 years 279.1 Total $ 1,240.4 Fair Value Measurements of Financial Assets and Liabilities For a discussion of fair value accounting and the classification of assets and liabilities within the fair value hierarchy, see the “Fair Value Measurements of Assets and Liabilities” section of Note 1. The following tables set forth, by level within the fair value hierarchy, the Registrants’ financial assets and liabilities that were accounted for at fair value on a recurring basis. As required by the accounting guidance for “Fair Value Measurements and Disclosures,” financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. Management’s assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. There have not been any significant changes in management’s valuation techniques. AEP December 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments and Restricted Cash Restricted Cash $ 48.0 $ — $ — $ — $ 48.0 Other Cash Deposits (a) — — — 10.0 10.0 Fixed Income Securities – Mutual Funds 154.8 — — — 154.8 Equity Securities – Mutual Funds (b) 55.6 — — — 55.6 Total Other Temporary Investments and Restricted Cash 258.4 — — 10.0 268.4 Risk Management Assets Risk Management Commodity Contracts (c) (d) (i) 7.4 648.5 226.3 (642.4) 239.8 Cash Flow Hedges: Commodity Hedges (c) — 242.9 19.2 (41.7) 220.4 Fair Value Hedges — 1.2 — — 1.2 Total Risk Management Assets 7.4 892.6 245.5 (684.1) 461.4 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 77.7 — — 7.0 84.7 Fixed Income Securities: United States Government — 1,156.4 — — 1,156.4 Corporate Debt — 76.7 — — 76.7 State and Local Government — 7.3 — — 7.3 Subtotal Fixed Income Securities — 1,240.4 — — 1,240.4 Equity Securities – Domestic (b) 2,541.9 — — — 2,541.9 Total Spent Nuclear Fuel and Decommissioning Trusts 2,619.6 1,240.4 — 7.0 3,867.0 Other Investments (h) 28.8 14.9 — — 43.7 Total Assets $ 2,914.2 $ 2,147.9 $ 245.5 $ (667.1) $ 4,640.5 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (d) (j) $ 5.3 $ 485.0 $ 147.6 $ (383.2) $ 254.7 Cash Flow Hedges: Commodity Hedges (c) — 54.0 0.6 (41.7) 12.9 Fair Value Hedges — 38.1 — — 38.1 Total Risk Management Liabilities $ 5.3 $ 577.1 $ 148.2 $ (424.9) $ 305.7 AEP December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments and Restricted Cash Restricted Cash $ 45.6 $ — $ — $ — $ 45.6 Other Cash Deposits (a) 12.2 — — 10.5 22.7 Fixed Income Securities – Mutual Funds 123.5 — — — 123.5 Equity Securities – Mutual Funds (b) 54.6 — — — 54.6 Total Other Temporary Investments and Restricted Cash 235.9 — — 10.5 246.4 Risk Management Assets Risk Management Commodity Contracts (c) (f) 0.9 258.8 252.4 (190.0) 322.1 Cash Flow Hedges: Commodity Hedges (c) — 34.4 3.9 (28.5) 9.8 Interest Rate Hedges — 2.4 — — 2.4 Fair Value Hedges — 2.6 — — 2.6 Total Risk Management Assets 0.9 298.2 256.3 (218.5) 336.9 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 16.8 — — 9.0 25.8 Fixed Income Securities: United States Government — 1,025.6 — — 1,025.6 Corporate Debt — 86.3 — — 86.3 State and Local Government — 114.3 — — 114.3 Subtotal Fixed Income Securities — 1,226.2 — — 1,226.2 Equity Securities – Domestic (b) 2,054.7 — — — 2,054.7 Total Spent Nuclear Fuel and Decommissioning Trusts 2,071.5 1,226.2 — 9.0 3,306.7 Other Investments (h) — — 31.8 — 31.8 Total Assets $ 2,308.3 $ 1,524.4 $ 288.1 $ (199.0) $ 3,921.8 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (f) $ 0.9 $ 244.2 $ 167.2 $ (193.4) $ 218.9 Cash Flow Hedges: Commodity Hedges (c) — 106.1 7.6 (28.5) 85.2 Interest Rate Hedges — 3.4 — — 3.4 Fair Value Hedges — 4.1 — — 4.1 Total Risk Management Liabilities $ 0.9 $ 357.8 $ 174.8 $ (221.9) $ 311.6 AEP Texas December 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 30.4 $ — $ — $ — $ 30.4 Risk Management Assets Risk Management Commodity Contracts (c) — 0.6 — (0.6) — Total Assets $ 30.4 $ 0.6 $ — $ (0.6) $ 30.4 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 28.7 $ — $ — $ — $ 28.7 Risk Management Assets Risk Management Commodity Contracts (c) — 0.4 — (0.4) — Total Assets $ 28.7 $ 0.4 $ — $ (0.4) $ 28.7 APCo December 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 17.6 $ — $ — $ — $ 17.6 Risk Management Assets Risk Management Commodity Contracts (c) (g) — 5.8 42.0 (5.8) 42.0 Total Assets $ 17.6 $ 5.8 $ 42.0 $ (5.8) $ 59.6 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 7.2 $ 0.3 $ (6.7) $ 0.8 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 16.9 $ — $ — $ — $ 16.9 Risk Management Assets Risk Management Commodity Contracts (c) (g) — 19.4 19.9 (19.2) 20.1 Cash Flow Hedges: Interest Rate Hedges — 2.4 — — 2.4 Total Risk Management Assets — 21.8 19.9 (19.2) 22.5 Total Assets $ 16.9 $ 21.8 $ 19.9 $ (19.2) $ 39.4 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 19.5 $ 0.6 $ (18.8) $ 1.3 Cash Flow Hedges: Interest Rate Hedges — 3.4 — — 3.4 Total Risk Management Liabilities $ — $ 22.9 $ 0.6 $ (18.8) $ 4.7 I&M December 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 3.8 $ 7.6 $ (8.1) $ 3.3 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 77.7 — — 7.0 84.7 Fixed Income Securities: United States Government — 1,156.4 — — 1,156.4 Corporate Debt — 76.7 — — 76.7 State and Local Government — 7.3 — — 7.3 Subtotal Fixed Income Securities — 1,240.4 — — 1,240.4 Equity Securities - Domestic (b) 2,541.9 — — — 2,541.9 Total Spent Nuclear Fuel and Decommissioning Trusts 2,619.6 1,240.4 — 7.0 3,867.0 Total Assets $ 2,619.6 $ 1,244.2 $ 7.6 $ (1.1) $ 3,870.3 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 6.7 $ 8.3 $ (10.0) $ 5.0 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 15.1 $ 2.5 $ (13.9) $ 3.7 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 16.8 — — 9.0 25.8 Fixed Income Securities: United States Government — 1,025.6 — — 1,025.6 Corporate Debt — 86.3 — — 86.3 State and Local Government — 114.3 — — 114.3 Subtotal Fixed Income Securities — 1,226.2 — — 1,226.2 Equity Securities - Domestic (b) 2,054.7 — — — 2,054.7 Total Spent Nuclear Fuel and Decommissioning Trusts 2,071.5 1,226.2 — 9.0 3,306.7 Total Assets $ 2,071.5 $ 1,241.3 $ 2.5 $ (4.9) $ 3,310.4 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 12.0 $ 0.4 $ (12.2) $ 0.2 OPCo December 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.5 $ — $ (0.5) $ — Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 92.5 $ — $ 92.5 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.3 $ — $ (0.3) $ — Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 110.3 $ — $ 110.3 PSO December 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.3 $ 12.2 $ (0.4) $ 12.1 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 3.7 $ 0.1 $ (0.1) $ 3.7 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.2 $ 10.3 $ (0.2) $ 10.3 SWEPCo December 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.3 $ 11.0 $ (0.4) $ 10.9 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 2.1 $ 0.1 $ (0.1) $ 2.1 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.1 $ 3.3 $ (0.2) $ 3.2 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 1.7 $ — $ 1.7 (a) Amounts in “Other” column primarily represent cash deposits in bank accounts with financial institutions or third-parties. Level 1 and Level 2 amounts primarily represent investments in money market funds. (b) Amounts represent publicly-traded equity securities and equity-based mutual funds. (c) Amounts in “Other” column primarily represent counterparty netting of risk management and hedging contracts and associated cash collateral under the accounting guidance for “Derivatives and Hedging.” (d) The December 31, 2021 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $1 million in 2022 and $1 million in periods 2023-2025; Level 2 matures $42 million in 2022, $109 million in periods 2023-2025, $10 million in periods 2026-2027 and $3 million in periods 2028-2033; Level 3 matures $82 million in 2022, $10 million in periods 2023-2025, $9 million in periods 2026-2027 and $(17) million in periods 2028-2033. Risk management commodity contracts are substantially comprised of power contracts. (e) Amounts in “Other” column primarily represent accrued interest receivables from financial institutions. Level 1 amounts primarily represent investments in money market funds. (f) The December 31, 2020 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 2 matures $3 million in periods 2022-2024, $11 million in periods 2025-2026 and $1 million in periods 2027-2033; Level 3 matures $47 million in 2021, $37 million in periods 2022-2024, $14 million in periods 2025-2026 and $(13) million in periods 2027-2033. Risk management commodity contracts are substantially comprised of power contracts. (g) Substantially comprised of power contracts for the Registrant Subsidiaries. (h) See “Warrants Held in Investee” section of Note 10 for additional information. (i) Amount excludes Risk Management Assets of $6 million classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (j) Amount excludes Risk Management Liabilities of $0.1 million classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. The following tables set forth a reconciliation of changes in the fair value of net trading derivatives classified as Level 3 in the fair value hierarchy: Year Ended December 31, 2021 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of December 31, 2020 $ 113.3 $ 19.3 $ 2.1 $ (110.3) $ 10.3 $ 1.6 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 48.6 8.3 (0.1) 2.4 16.1 9.5 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (45.2) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 24.2 — — — — — Settlements (89.0) (28.0) (2.2) 6.3 (26.4) (15.5) Transfers into Level 3 (d) (e) (3.8) — — — — — Transfers out of Level 3 (e) (34.4) — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 89.4 42.1 (0.5) 9.1 12.1 15.3 Assets and Liabilities Held for Sale related to KPCo (g) (h) (5.8) — — — — — Balance as of December 31, 2021 $ 97.3 $ 41.7 $ (0.7) $ (92.5) $ 12.1 $ 10.9 Year Ended December 31, 2020 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of December 31, 2019 $ 109.9 $ 37.7 $ 5.8 $ (103.6) $ 15.8 $ 1.4 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 39.5 13.2 2.5 (1.6) 11.9 2.8 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) 35.3 — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 13.8 — — — — — Settlements (113.1) (51.6) (8.6) 8.9 (27.6) (6.6) Transfers into Level 3 (d) (e) (3.8) — — — — — Transfers out of Level 3 (e) 5.6 0.7 0.4 — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 26.1 19.3 2.0 (14.0) 10.2 4.0 Balance as of December 31, 2020 $ 113.3 $ 19.3 $ 2.1 $ (110.3) $ 10.3 $ 1.6 Year Ended December 31, 2019 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of December 31, 2018 $ 131.2 $ 57.8 $ 8.9 $ (99.4) $ 9.5 $ 2.3 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 15.8 (13.9) 4.7 (0.9) 13.5 6.0 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (0.1) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) (15.1) — — — — — Settlements (117.6) (42.5) (13.0) 6.6 (23.0) (9.6) Transfers into Level 3 (d) (e) (0.6) (0.5) (0.3) — — — Transfers out of Level 3 (e) 35.6 (0.7) (0.4) — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 60.7 37.5 5.9 (9.9) 15.8 2.7 Balance as of December 31, 2019 $ 109.9 $ 37.7 $ 5.8 $ (103.6) $ 15.8 $ 1.4 (a) Included in revenues on the statements of income. (b) Represents the change in fair value between the beginning of the reporting period and the settlement of the risk management commodity contract. (c) Included in cash flow hedges on the statements of comprehensive income. (d) Represents existing assets or liabilities that were previously categorized as Level 2. (e) Transfers are recognized based on their value at the beginning of the reporting period that the transfer occurred. (f) Relates to the net gains (losses) of those contracts that are not reflected on the statements of income. These changes in fair value are recorded as regulatory liabilities for net gains and as regulatory assets for net losses or accounts payable. (g) Amount excludes Risk Management Assets of $6.4 million classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (h) Amount excludes Risk Management Liabilities of $0.6 million classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. The following tables quantify the significant unobservable inputs used in developing the fair value of Level 3 positions: AEP December 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (c) (in millions) Energy Contracts (g) $ 164.4 $ 135.2 Discounted Cash Flow Forward Market Price (a) $ 10.30 $ 76.70 $ 37.11 Natural Gas Contracts 3.6 — Discounted Cash Flow Forward Market Price (b) 3.11 4.02 3.47 FTRs (e) (f) 77.5 13.0 Discounted Cash Flow Forward Market Price (a) (23.93) 26.38 0.86 Total $ 245.5 $ 148.2 December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (in millions) Energy Contracts $ 213.5 $ 169.7 Discounted Cash Flow Forward Market Price (a) (c) $ 5.33 $ 100.47 $ 32.73 Natural Gas Contracts — 1.7 Discounted Cash Flow Forward Market Price (b) (c) 2.18 2.77 2.40 FTRs 42.8 3.4 Discounted Cash Flow Forward Market Price (a) (c) (15.08) 9.66 0.19 Other Investments 31.8 — Black-Scholes Model Liquidity Adjustment (d) 10 % 20 % 15 % Total $ 288.1 $ 174.8 APCo December 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ — $ 0.3 Discounted Cash Flow Forward Market Price $ 32.20 $ 56.54 $ 44.77 FTRs 42.0 — Discounted Cash Flow Forward Market Price (0.30) 26.38 2.63 Total $ 42.0 $ 0.3 December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ 1.0 $ 0.6 Discounted Cash Flow Forward Market Price $ 10.84 $ 41.09 $ 25.08 FTRs 18.9 — Discounted Cash Flow Forward Market Price 0.04 5.61 1.13 Total $ 19.9 $ 0.6 I&M December 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ — $ 0.2 Discounted Cash Flow Forward Market Price $ 32.20 $ 56.54 $ 44.77 FTRs 7.6 8.1 Discounted Cash Flow Forward Market Price (5.45) 17.78 (0.12) Total $ 7.6 $ 8.3 December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ 0.6 $ 0.3 Discounted Cash Flow Forward Market Price $ 10.84 $ 41.09 $ 25.08 FTRs 1.9 0.1 Discounted Cash Flow Forward Market Price (1.96) 3.69 0.33 Total $ 2.5 $ 0.4 OPCo December 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ — $ 92.5 Discounted Cash Flow Forward Market Price $ 14.26 $ 52.98 $ 30.68 December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ — $ 110.3 Discounted Cash Flow Forward Market Price $ 16.19 $ 46.98 $ 28.30 PSO December 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) FTRs $ 12.2 $ 0.1 Discounted Cash Flow Forward Market Price $ (18.39) $ 1.87 $ (2.57) December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) FTRs $ 10.3 $ — Discounted Cash Flow Forward Market Price $ (6.93) $ 0.48 $ (1.93) SWEPCo December 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (c) (in millions) Natural Gas Contracts $ 3.6 $ — Discounted Cash Flow Forward Market Price (b) $ 3.11 $ 4.02 $ 3.47 FTRs 7.4 0.1 Discounted Cash Flow Forward Market Price (a) (18.39) 1.87 (2.57) Total $ 11.0 $ 0.1 December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (c) (in millions) Natural Gas Contracts $ — $ 1.7 Discounted Cash Flow Forward Market Price (b) $ 2.18 $ 2.77 $ 2.41 FTRs 3.3 — Discounted Cash Flow Forward Market Price (a) (6.93) 0.48 (1.93) Total $ 3.3 $ 1.7 (a) Represents market prices in dollars per MWh. (b) Represents market prices in dollars per MMBtu. (c) The weighted-average is the product of the forward market price of the underlying commodity and volume weighted by term. (d) Represents percentage discount applied to the publically available share price. (e) Amount excludes Risk Management Assets of $6 million classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (f) Amount excludes Risk Management Liabilities of $0.5 million classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (g) Amount excludes Risk Management Liabilities of $0.1 million classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. The following table provides the measurement uncertainty of fair value measurements to increases (decreases) in significant unobservable inputs related to Energy Contracts, Natural Gas Contracts, FTRs and Other Investments for the Registrants as of December 31, 2021 and 2020: Uncertainty of Fair Value Measurements Significant Unobservable Input Position Change in Input Impact on Fair Value Forward Market Price Buy Increase (Decrease) Higher (Lower) Forward Market Price Sell Increase (Decrease) Lower (Higher) Liquidity Adjustment Buy Increase (Decrease) Lower (Higher)

Income Taxes

Income Taxes	12 Months Ended
Income Taxes	Dec. 31, 2021
Income Taxes	INCOME TAXES The disclosures in this note apply to all Registrants unless indicated otherwise. Income Tax Expense (Benefit) The details of the Registrants’ Income Tax Expense (Benefit) as reported are as follows: Year Ended December 31, 2021 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Federal: Current $ (27.8) $ (1.2) $ 69.8 $ 5.0 $ 26.9 $ 6.8 $ (109.6) $ (16.7) Deferred 182.6 40.5 54.1 14.9 (35.5) 25.2 105.6 26.2 Total Federal 154.8 39.3 123.9 19.9 (8.6) 32.0 (4.0) 9.5 State and Local: Current 6.0 3.0 5.8 2.2 (0.6) (3.1) — 0.4 Deferred (a) (45.3) 0.8 14.4 — (1.4) 5.5 8.1 (10.5) Total State and Local (39.3) 3.8 20.2 2.2 (2.0) 2.4 8.1 (10.1) Income Tax Expense (Benefit) $ 115.5 $ 43.1 $ 144.1 $ 22.1 $ (10.6) $ 34.4 $ 4.1 $ (0.6) (a) Benefit at AEP is primarily due to an out of period adjustment related to Deferred Income Taxes and Income Tax Expense (Benefit). Management concluded the misstatement and subsequent correction was not material to prior or current period financial statements. Year Ended December 31, 2020 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Federal: Current $ (138.2) $ 5.2 $ 22.2 $ 21.4 $ 11.3 $ (26.6) $ (11.4) $ (13.6) Deferred 146.9 (15.4) 65.4 (27.1) (20.6) 74.0 8.3 19.6 Total Federal 8.7 (10.2) 87.6 (5.7) (9.3) 47.4 (3.1) 6.0 State and Local: Current (16.7) (0.1) 2.8 9.3 1.9 (5.4) 0.1 (8.2) Deferred 48.5 (0.9) 16.3 0.7 (0.1) 3.2 8.2 11.6 Total State and Local 31.8 (1.0) 19.1 10.0 1.8 (2.2) 8.3 3.4 Income Tax Expense (Benefit) $ 40.5 $ (11.2) $ 106.7 $ 4.3 $ (7.5) $ 45.2 $ 5.2 $ 9.4 Year Ended December 31, 2019 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Federal: Current $ (7.4) $ (31.8) $ 23.7 $ 36.7 $ 48.1 $ (10.0) $ 25.5 $ 6.9 Deferred (71.6) (24.7) 71.7 (126.1) (57.1) 40.6 (26.0) (10.0) Total Federal (79.0) (56.5) 95.4 (89.4) (9.0) 30.6 (0.5) (3.1) State and Local: Current 4.4 2.9 2.4 12.0 (2.4) 1.1 0.2 0.8 Deferred 61.7 — 19.6 (0.6) 0.8 3.2 7.8 (2.4) Total State and Local 66.1 2.9 22.0 11.4 (1.6) 4.3 8.0 (1.6) Income Tax Expense (Benefit) $ (12.9) $ (53.6) $ 117.4 $ (78.0) $ (10.6) $ 34.9 $ 7.5 $ (4.7) The following are reconciliations for the Registrants between the federal income taxes computed by multiplying pretax income by the federal statutory tax rate and the income taxes reported: AEP Years Ended December 31, 2021 2020 2019 (in millions) Net Income $ 2,488.1 $ 2,196.7 $ 1,919.8 Less: Equity Earnings – Dolet Hills (3.4) (2.9) (3.0) Income Tax Expense (Benefit) 115.5 40.5 (12.9) Pretax Income $ 2,600.2 $ 2,234.3 $ 1,903.9 Income Taxes on Pretax Income at Statutory Rate (21%) $ 546.0 $ 469.2 $ 399.8 Increase (Decrease) in Income Taxes Resulting from the Following Items: Reversal of Origination Flow-Through 25.9 26.5 20.4 Investment Tax Credit Amortization (22.0) (18.8) (13.0) Production Tax Credits (98.8) (83.1) (59.6) State and Local Income Taxes, Net 39.4 25.1 52.2 Removal Costs (20.0) (18.6) (22.2) AFUDC (30.6) (32.5) (37.1) Tax Adjustments (a) (55.1) — — Tax Reform Excess ADIT Reversal (255.6) (268.2) (353.2) CARES Act — (48.0) — Other (13.7) (11.1) (0.2) Income Tax Expense (Benefit) $ 115.5 $ 40.5 $ (12.9) Effective Income Tax Rate 4.4 % 1.8 % (0.7) % (a) Represents an out of period adjustment related to Deferred Income Taxes and Income Tax Expense (Benefit). Management concluded the misstatement and subsequent correction was not material to prior or current period financial statements. AEP Texas Years Ended December 31, 2021 2020 2019 (in millions) Net Income $ 289.8 $ 241.0 $ 178.3 Income Tax Expense (Benefit) 43.1 (11.2) (53.6) Pretax Income $ 332.9 $ 229.8 $ 124.7 Income Taxes on Pretax Income at Statutory Rate (21%) $ 69.9 $ 48.3 $ 26.2 Increase (Decrease) in Income Taxes Resulting from the Following Items: State and Local Income Taxes, Net 2.4 (0.8) 2.3 AFUDC (4.5) (4.1) (3.2) Parent Company Loss Benefit (3.2) (4.5) (3.8) Tax Reform Excess ADIT Reversal (21.3) (47.9) (73.4) Other (0.2) (2.2) (1.7) Income Tax Expense (Benefit) $ 43.1 $ (11.2) $ (53.6) Effective Income Tax Rate 12.9 % (4.9) % (43.0) % AEPTCo Years Ended December 31, 2021 2020 2019 (in millions) Net Income $ 591.7 $ 423.4 $ 439.7 Income Tax Expense 144.1 106.7 117.4 Pretax Income $ 735.8 $ 530.1 $ 557.1 Income Taxes on Pretax Income at Statutory Rate (21%) $ 154.5 $ 111.3 $ 117.0 Increase (Decrease) in Income Taxes Resulting from the Following Items: State and Local Income Taxes, Net 19.8 15.1 17.4 AFUDC (14.1) (15.5) (17.7) Parent Company Loss Benefit (18.3) (7.0) (4.2) Other 2.2 2.8 4.9 Income Tax Expense $ 144.1 $ 106.7 $ 117.4 Effective Income Tax Rate 19.6 % 20.1 % 21.1 % APCo Years Ended December 31, 2021 2020 2019 (in millions) Net Income $ 348.9 $ 369.7 $ 306.3 Income Tax Expense (Benefit) 22.1 4.3 (78.0) Pretax Income $ 371.0 $ 374.0 $ 228.3 Income Taxes on Pretax Income at Statutory Rate (21%) $ 77.9 $ 78.5 $ 47.9 Increase (Decrease) in Income Taxes Resulting from the Following Items: Reversal of Origination Flow-Through 11.7 12.7 10.8 State and Local Income Taxes, Net 2.1 7.9 9.0 Removal Costs (7.3) (5.7) (6.4) AFUDC (4.6) (4.5) (5.2) Parent Company Loss Benefit — (6.2) (4.1) Tax Adjustments (a) 4.5 — — Tax Reform Excess ADIT Reversal (60.5) (72.3) (130.4) Federal Return to Provision (1.6) (7.2) (1.0) Other (0.1) 1.1 1.4 Income Tax Expense (Benefit) $ 22.1 $ 4.3 $ (78.0) Effective Income Tax Rate 6.0 % 1.1 % (34.2) % (a) Represents an out of period adjustment related to Deferred Income Taxes and Income Tax Expense (Benefit). Management concluded the misstatement and subsequent correction was not material to prior or current period financial statements. I&M Years Ended December 31, 2021 2020 2019 (in millions) Net Income $ 279.8 $ 284.8 $ 269.4 Income Tax Benefit (10.6) (7.5) (10.6) Pretax Income $ 269.2 $ 277.3 $ 258.8 Income Taxes on Pretax Income at Statutory Rate (21%) $ 56.5 $ 58.2 $ 54.3 Increase (Decrease) in Income Taxes Resulting from the Following Items: Reversal of Origination Flow-Through 3.5 1.6 4.0 Investment Tax Credit Amortization (6.4) (4.5) (3.6) State and Local Income Taxes, Net (1.3) 1.5 (1.2) Removal Costs (9.7) (10.5) (12.8) AFUDC (2.7) (2.4) (4.1) Parent Company Loss Benefit (2.8) (6.4) (3.3) Tax Reform Excess ADIT Reversal (46.3) (46.8) (42.5) Other (1.4) 1.8 (1.4) Income Tax Benefit $ (10.6) $ (7.5) $ (10.6) Effective Income Tax Rate (3.9) % (2.7) % (4.1) % OPCo Years Ended December 31, 2021 2020 2019 (in millions) Net Income $ 253.6 $ 271.4 $ 297.1 Income Tax Expense 34.4 45.2 34.9 Pretax Income $ 288.0 $ 316.6 $ 332.0 Income Taxes on Pretax Income at Statutory Rate (21%) $ 60.5 $ 66.5 $ 69.7 Increase (Decrease) in Income Taxes Resulting from the Following Items: Reversal of Origination Flow-Through 2.2 3.7 (1.4) State and Local Income Taxes, Net — (1.7) 3.4 AFUDC (2.3) (2.6) (3.8) Tax Adjustments (a) 8.9 — — Tax Reform Excess ADIT Reversal (32.6) (27.2) (27.3) Federal Return to Provision (1.2) 6.5 (3.7) Other (1.1) — (2.0) Income Tax Expense $ 34.4 $ 45.2 $ 34.9 Effective Income Tax Rate 11.9 % 14.3 % 10.5 % (a) Represents an out of period adjustment related to Deferred Income Taxes and Income Tax Expense (Benefit). Management concluded the misstatement and subsequent correction was not material to prior or current period financial statements. PSO Years Ended December 31, 2021 2020 2019 (in millions) Net Income $ 141.1 $ 123.0 $ 137.6 Income Tax Expense 4.1 5.2 7.5 Pretax Income $ 145.2 $ 128.2 $ 145.1 Income Taxes on Pretax Income at Statutory Rate (21%) $ 30.5 $ 26.9 $ 30.5 Increase (Decrease) in Income Taxes Resulting from the Following Items: Investment Tax Credit Amortization (1.8) (2.1) (0.5) Production Tax Credits (6.0) — — State and Local Income Taxes, Net 6.4 6.5 6.3 Parent Company Loss Benefit — (0.2) (2.1) Tax Reform Excess ADIT Reversal (25.4) (25.5) (24.5) Other 0.4 (0.4) (2.2) Income Tax Expense $ 4.1 $ 5.2 $ 7.5 Effective Income Tax Rate 2.8 % 4.1 % 5.2 % SWEPCo Years Ended December 31, 2021 2020 2019 (in millions) Net Income $ 242.1 $ 183.7 $ 162.2 Less: Equity Earnings – Dolet Hills (3.4) (2.9) (3.0) Income Tax Expense (Benefit) (0.6) 9.4 (4.7) Pretax Income $ 238.1 $ 190.2 $ 154.5 Income Taxes on Pretax Income at Statutory Rate (21%) $ 50.0 $ 39.9 $ 32.4 Increase (Decrease) in Income Taxes Resulting from the Following Items: Reversal of Origination Flow-Through 1.8 1.9 1.9 Depletion (2.7) (3.4) (3.4) Production Tax Credits (7.2) — — State and Local Income Taxes, Net (8.0) 2.7 (1.3) Parent Company Loss Benefit — (5.6) (1.6) Tax Reform Excess ADIT Reversal (31.1) (21.9) (29.9) Other (3.4) (4.2) (2.8) Income Tax Expense (Benefit) $ (0.6) $ 9.4 $ (4.7) Effective Income Tax Rate (0.3) % 4.9 % (3.0) % Net Deferred Tax Liability The following tables show elements of the net deferred tax liability and significant temporary differences for each Registrant: AEP December 31, 2021 2020 (in millions) Deferred Tax Assets $ 3,277.0 $ 3,259.7 Deferred Tax Liabilities (11,479.5) (11,500.6) Net Deferred Tax Liabilities $ (8,202.5) $ (8,240.9) Property Related Temporary Differences $ (7,020.3) $ (7,340.5) Amounts Due to Customers for Future Income Taxes 1,033.0 1,075.8 Deferred State Income Taxes (1,116.7) (1,317.6) Securitized Assets (128.8) (140.0) Regulatory Assets (645.4) (391.6) Accrued Nuclear Decommissioning (743.2) (626.4) Net Operating Loss Carryforward 285.7 112.9 Tax Credit Carryforward 439.8 323.6 Operating Lease Liability 114.2 183.7 Investment in Partnership (392.1) (362.0) All Other, Net (28.7) 241.2 Net Deferred Tax Liabilities $ (8,202.5) $ (8,240.9) AEP Texas December 31, 2021 2020 (in millions) Deferred Tax Assets $ 173.8 $ 183.6 Deferred Tax Liabilities (1,262.7) (1,200.3) Net Deferred Tax Liabilities $ (1,088.9) $ (1,016.7) Property Related Temporary Differences $ (1,060.2) $ (1,039.6) Amounts Due to Customers for Future Income Taxes 110.0 114.4 Deferred State Income Taxes (32.2) (29.1) Securitized Transition Assets (84.4) (90.2) Regulatory Assets (45.1) (47.4) Operating Lease Liability 15.8 18.0 All Other, Net 7.2 57.2 Net Deferred Tax Liabilities $ (1,088.9) $ (1,016.7) AEPTCo December 31, 2021 2020 (in millions) Deferred Tax Assets $ 158.8 $ 166.5 Deferred Tax Liabilities (1,121.7) (1,073.4) Net Deferred Tax Liabilities $ (962.9) $ (906.9) Property Related Temporary Differences $ (997.0) $ (937.8) Amounts Due to Customers for Future Income Taxes 118.2 118.9 Deferred State Income Taxes (94.5) (98.3) Net Operating Loss Carryforward 8.1 13.2 All Other, Net 2.3 (2.9) Net Deferred Tax Liabilities $ (962.9) $ (906.9) APCo December 31, 2021 2020 (in millions) Deferred Tax Assets $ 495.1 $ 500.6 Deferred Tax Liabilities (2,299.8) (2,250.5) Net Deferred Tax Liabilities $ (1,804.7) $ (1,749.9) Property Related Temporary Differences $ (1,476.5) $ (1,412.0) Amounts Due to Customers for Future Income Taxes 182.1 198.3 Deferred State Income Taxes (288.8) (336.5) Securitized Assets (39.3) (44.7) Regulatory Assets (177.0) (114.8) Operating Lease Liability 14.2 16.7 All Other, Net (19.4) (56.9) Net Deferred Tax Liabilities $ (1,804.7) $ (1,749.9) I&M December 31, 2021 2020 (in millions) Deferred Tax Assets $ 1,072.2 $ 989.5 Deferred Tax Liabilities (2,172.4) (2,053.9) Net Deferred Tax Liabilities $ (1,100.2) $ (1,064.4) Property Related Temporary Differences $ (286.2) $ (409.2) Amounts Due to Customers for Future Income Taxes 135.5 147.9 Deferred State Income Taxes (222.0) (211.1) Regulatory Assets (23.6) (16.5) Accrued Nuclear Decommissioning (743.2) (626.4) Operating Lease Liability 13.5 46.6 All Other, Net 25.8 4.3 Net Deferred Tax Liabilities $ (1,100.2) $ (1,064.4) OPCo December 31, 2021 2020 (in millions) Deferred Tax Assets $ 204.4 $ 210.8 Deferred Tax Liabilities (1,205.3) (1,165.9) Net Deferred Tax Liabilities $ (1,000.9) $ (955.1) Property Related Temporary Differences $ (1,042.0) $ (1,016.0) Amounts Due to Customers for Future Income Taxes 117.7 121.1 Deferred State Income Taxes (58.8) (40.7) Regulatory Assets (39.8) (53.7) Operating Lease Liability 17.2 19.4 All Other, Net 4.8 14.8 Net Deferred Tax Liabilities $ (1,000.9) $ (955.1) PSO December 31, 2021 2020 (in millions) Deferred Tax Assets $ 170.0 $ 239.8 Deferred Tax Liabilities (952.3) (928.3) Net Deferred Tax Liabilities $ (782.3) $ (688.5) Property Related Temporary Differences $ (708.6) $ (661.8) Amounts Due to Customers for Future Income Taxes 111.5 118.5 Deferred State Income Taxes (83.2) (107.7) Regulatory Assets (228.0) (39.1) Net Operating Loss Carryforward 111.4 12.9 All Other, Net 14.6 (11.3) Net Deferred Tax Liabilities $ (782.3) $ (688.5) SWEPCo December 31, 2021 2020 (in millions) Deferred Tax Assets $ 336.4 $ 338.1 Deferred Tax Liabilities (1,424.0) (1,355.7) Net Deferred Tax Liabilities $ (1,087.6) $ (1,017.6) Property Related Temporary Differences $ (989.6) $ (985.1) Amounts Due to Customers for Future Income Taxes 154.8 162.7 Deferred State Income Taxes (234.9) (214.7) Regulatory Assets (101.4) (26.2) Net Operating Loss Carryforward 67.4 33.4 All Other, Net 16.1 12.3 Net Deferred Tax Liabilities $ (1,087.6) $ (1,017.6) AEP System Tax Allocation Agreement AEP and subsidiaries join in the filing of a consolidated federal income tax return. The allocation of the AEP System’s current consolidated federal income tax to the AEP System companies allocates the benefit of current tax loss of the parent company (Parent Company Loss Benefit) to the AEP System subsidiaries with taxable income reducing their current tax expense proportionately. The consolidated NOL of the AEP System is allocated to each company in the consolidated group with taxable losses. With the exception of the allocation of the consolidated AEP System NOL, the loss of the Parent and tax credits, the method of allocation reflects a separate return result for each company in the consolidated group. Federal and State Income Tax Audit Status The statute of limitations for the IRS to examine AEP and subsidiaries originally filed federal return has expired for tax years 2016 and earlier. In the third quarter of 2019, AEP and subsidiaries elected to amend the 2014 through 2017 federal returns. In the first quarter of 2020, the IRS notified AEP that it was beginning an examination of these amended returns, including the net operating loss carryback to 2015 that originated in the 2017 return. As of December 31, 2021, the IRS has not issued any proposed adjustments and the IRS is limited in their proposed adjustments to the amount AEP claimed on the amended returns. AEP has agreed to extend the statute of limitations on the 2017 tax return to December 31, 2022 to allow time for the audit to be completed and the Congressional Joint Committee on Taxation to approve the associated refund claim. AEP and subsidiaries file income tax returns in various state and local jurisdictions. These taxing authorities routinely examine the tax returns, and AEP and subsidiaries are currently under examination in several state and local jurisdictions. The Registrants are no longer subject to state or local examinations by tax authorities for years before 2012. In addition, management is monitoring and continues to evaluate the potential impact of federal legislation and corresponding state conformity. Net Income Tax Operating Loss Carryforward As of December 31, 2021, AEP has no federal net income tax operating loss carryforward from prior years but does expect to generate a tax operating loss of $674 million for tax year 2021. AEP, AEPTCo, APCo, OPCo, PSO and SWEPCo have state net income tax operating loss carryforwards as indicated in the table below: State Net Income Tax Operating Loss Years of Company State/Municipality Carryforward Expiration (in millions) AEP Arkansas $ 161.8 2022 - 2031 AEP Colorado 82.8 2041 AEP Illinois 55.2 2031 - 2041 AEP Indiana 304.4 2039 - 2041 AEP Kentucky 230.4 2030 - 2037 AEP Louisiana 566.7 NA AEP Michigan 65.2 2029 - 2031 AEP New Jersey 36.5 2036 - 2041 AEP New Mexico 32.6 2037 - 2039 AEP Ohio Municipal 1,027.9 2022 - 2026 AEP Oklahoma 1,357.1 2034 - 2037 AEP Pennsylvania 82.7 2030 - 2041 AEP Tennessee 53.0 2030 - 2036 AEP Virginia 20.9 2030 - 2037 AEP West Virginia 99.5 2029 - 2037 AEPTCo Oklahoma 107.8 2034 - 2037 APCo West Virginia 62.9 NA OPCo Ohio Municipal 76.0 2022 - 2026 PSO Oklahoma 1,229.8 2034 - 2037 SWEPCo Arkansas 160.7 2022 - 2031 SWEPCo Louisiana 554.7 NA As of December 31, 2021, AEP recorded a valuation allowance of $25 million, against certain state and municipal net income tax operating loss carryforwards since future taxable income is not expected to be sufficient to realize the remaining state net income tax operating loss tax benefits before the carryforward expires. Management anticipates future taxable income will be sufficient to realize the remaining state net income tax operating loss tax benefits before the carryforward expires for each state. Tax Credit Carryforward Federal and state net income tax operating losses sustained in 2016, 2017 and 2019 resulted in unused federal and state income tax credits. As of December 31, 2021, the Registrants have federal tax credit carryforwards and AEP and PSO have state tax credit carryforwards as indicated in the table below. If these credits are not utilized, federal general business tax credits will expire in the years 2036 through 2041 and state tax credits will remain available indefinitely. Total Federal Total State Tax Credit Tax Credit Company Carryforward Carryforward (in millions) AEP $ 439.8 $ 38.8 AEP Texas 0.3 — AEPTCo 0.1 — APCo 1.3 — I&M 16.9 — OPCo 0.4 — PSO 6.3 38.8 SWEPCo 7.9 — The Registrants anticipate future federal taxable income will be sufficient to realize the tax benefits of the federal tax credits before they expire unused. Valuation Allowance AEP assesses the available positive and negative evidence to estimate whether sufficient future taxable income of the appropriate tax character will be generated to realize the benefits of existing deferred tax assets. When the evaluation of the evidence indicates that it is more-likely-than-not that AEP will not be able to realize the benefits of existing deferred tax assets, a valuation allowance is recorded to reduce existing deferred tax assets to the net realizable amount. Objective evidence evaluated includes whether AEP has a history of recognizing income, future reversals of existing temporary differences and tax planning strategies. Valuation allowance activity for the years ended December 31, 2021, 2020 and 2019 was not material. Uncertain Tax Positions The reconciliations of the beginning and ending amounts of unrecognized tax benefits for AEP are presented below. The amount and activity of unrecognized tax benefits for Registrant Subsidiaries was immaterial for periods presented: AEP 2021 2020 2019 (in millions) Balance as of January 1, $ 13.2 $ 24.1 $ 14.6 Increase – Tax Positions Taken During a Prior Period 1.2 0.6 8.8 Decrease – Tax Positions Taken During a Prior Period (3.2) (14.5) (2.1) Increase – Tax Positions Taken During the Current Year 3.1 3.0 2.8 Decrease – Tax Positions Taken During the Current Year — — — Decrease – Settlements with Taxing Authorities — — — Decrease – Lapse of the Applicable Statute of Limitations — — — Balance as of December 31, $ 14.3 $ 13.2 $ 24.1 Management believes that there will be no significant net increase or decrease in unrecognized benefits within 12 months of the reporting date. The total amount of unrecognized tax benefits that, if recognized, would affect the effective tax rate for AEP as of December 31, 2021, 2020 and 2019 were $14 million, $12 million, and $20 million, respectively. Federal and State Tax Legislation In March 2020, the CARES Act was signed into law. The CARES Act includes tax relief provisions including a 5-year NOL carryback from years 2018-2020. In the third quarter of 2020, AEP requested a $95 million refund of taxes paid in 2014 under the 5-year NOL carryback provision of the CARES Act. AEP carried back a NOL generated on the 2019 Federal income tax return at a 21% federal corporate income tax rate to the 2014 Federal income tax return at a 35% corporate income tax rate. As a result of the change in the corporate income tax rates between the two periods, AEP realized a tax benefit of $48 million during the third quarter of 2020 primarily at the Generation & Marketing segment. AEP received the $95 million refund in the fourth quarter of 2021. In March 2021, the American Rescue Plan Act of 2021 (the “American Rescue Plan”) was signed into law. The American Rescue Plan was a COVID-19 relief package that addressed a variety of topics, including the non-deductibility of certain executive compensation. Specifically, the American Rescue Plan changes the officers subject to IRC Section 162(m) from the CEO, CFO and three top paid officers to the CEO, CFO and eight top paid officers beginning in 2027. IRS Notice 2021-41 was issued in June 2021 by the IRS providing further extension of the continuity safe harbor for PTC and ITC-eligible projects and revising the facts and circumstances rules. For PTC and ITC-eligible projects for which construction began in calendar years 2016 through 2019, the continuity safe harbor is extended to six years. Prior guidance (IRS Notice 2020-41) had only extended the safe harbor for projects beginning in 2016 and 2017 to 5 years. Furthermore, for PTC and ITC-eligible projects for which construction began in 2020, the continuity safe harbor is extended to five years. Under a facts and circumstances analysis, the continuity requirement may be satisfied under either the continuous construction test or the continuous efforts test, regardless of whether the physical work test or the five percent safe harbor is used. In April 2021, West Virginia enacted House Bill (HB) 2026. HB 2026 changes the state income tax apportionment formula from a ratio that includes property, payroll and sales to a single sales factor apportionment regime effective for tax years beginning on or after January 1, 2022. HB 2026 also eliminates the “throw out” rule related to sales of tangible personal property for sales factor apportionment calculation purposes and introduces a market-based sourcing for sales of services and intangible property. During 2021, AEP recorded $23 million in Income Tax Expense as a result of remeasuring West Virginia deferred taxes under the new apportionment methodology. The enacted legislation does not impact AEP Texas, PSO or SWEPCo. In May 2021, Oklahoma enacted HB 2960. HB 2960 reduces the Oklahoma corporate income tax rate from 6% to 4%. During 2021, AEP recorded an immaterial amount of Income Tax Benefit as a result of remeasuring Oklahoma deferred taxes at the lowered statutory tax rate of 4%. The enacted legislation does not impact APCo, I&M or OPCo. In November 2021, Louisiana approved Constitutional Amendment 2, thereby also enacting HB 292. HB 292 reduces the Louisiana corporate income tax rate from 8% to 7.5%. In the fourth quarter of 2021, AEP recorded an immaterial amount of Income Tax Expense as a result of remeasuring Louisiana deferred taxes at the lowered statutory tax rate of 7.5%. The enacted legislation does not impact AEP Texas, APCo, I&M, OPCo or PSO. In December 2021, Arkansas enacted HB 1001. HB 1001 reduces the Arkansas corporate income tax rate from 5.9% to 5.7%, with additional reductions to 5.3% contingent upon future events. In the fourth quarter of 2021, AEP recorded an immaterial amount of Income Tax Expense as a result of remeasuring Arkansas deferred taxes at the lowered statutory tax rate of 5.7%. The enacted legislation does not impact AEP Texas, APCo, I&M, OPCo or PSO.

Leases

Leases	12 Months Ended
	Dec. 31, 2021
Leases	13. LEASES The disclosures in this note apply to all Registrants unless indicated otherwise. The Registrants lease property, plant and equipment including, but not limited to, fleet, information technology and real estate leases. These leases require payments of non-lease components, including related property taxes, operating and maintenance costs. AEP does not separate non-lease components from associated lease components. Many of these leases have purchase or renewal options. Leases not renewed are often replaced by other leases. Options to renew or purchase a lease are included in the measurement of lease assets and liabilities if it is reasonably certain the Registrant will exercise the option. Lease obligations are measured using the discount rate implicit in the lease when that rate is readily determinable. AEP has visibility into the rate implicit in the lease when assets are leased from selected financial institutions under master leasing agreements. When the implicit rate is not readily determinable, the Registrants measure their lease obligation using their estimated secured incremental borrowing rate. Incremental borrowing rates are comprised of an underlying risk-free rate and a secured credit spread relative to the lessee on a matched maturity basis. Operating lease rentals and finance lease amortization costs are generally charged to Other Operation and Maintenance expense in accordance with rate-making treatment for regulated operations. The amortization costs related to the Rockport finance lease are charged to Depreciation and Amortization, see “Rockport Lease” below for additional information. Interest on finance lease liabilities is generally charged to Interest Expense. Lease costs associated with capital projects are included in Property, Plant and Equipment on the balance sheets. For regulated operations with finance leases, a finance lease asset and offsetting liability are recorded at the present value of the remaining lease payments for each reporting period. Finance leases for nonregulated property are accounted for as if the assets were owned and financed. The components of rental costs were as follows: Year Ended December 31, 2021 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Cost $ 275.3 $ 18.4 $ 1.7 $ 19.3 $ 90.2 $ 19.0 $ 8.7 $ 12.1 Finance Lease Cost: Amortization of Right-of-Use Assets 74.7 6.7 — 7.7 12.9 4.9 3.2 11.0 Interest on Lease Liabilities 14.4 1.4 — 2.4 3.0 0.8 0.6 2.5 Total Lease Rental Costs (a) $ 364.4 $ 26.5 $ 1.7 $ 29.4 $ 106.1 $ 24.7 $ 12.5 $ 25.6 Year Ended December 31, 2020 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Cost $ 279.6 $ 17.4 $ 2.6 $ 19.1 $ 101.5 $ 17.1 $ 7.8 $ 9.4 Finance Lease Cost: Amortization of Right-of-Use Assets 61.9 6.3 — 7.4 6.5 4.7 3.5 10.9 Interest on Lease Liabilities 15.4 1.5 — 2.7 3.1 0.9 0.7 2.2 Total Lease Rental Costs (a) $ 356.9 $ 25.2 $ 2.6 $ 29.2 $ 111.1 $ 22.7 $ 12.0 $ 22.5 Year Ended December 31, 2019 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Cost $ 286.0 $ 16.5 $ 2.5 $ 19.5 $ 93.1 $ 18.0 $ 6.8 $ 8.0 Finance Lease Cost: Amortization of Right-of-Use Assets 70.8 5.1 0.1 6.7 5.7 3.5 3.1 11.0 Interest on Lease Liabilities 16.4 1.4 — 2.9 2.9 0.7 0.6 2.9 Total Lease Rental Costs (a) $ 373.2 $ 23.0 $ 2.6 $ 29.1 $ 101.7 $ 22.2 $ 10.5 $ 21.9 (a) Excludes variable and short-term lease costs, which were immaterial. Supplemental information related to leases are shown in the tables below: December 31, 2021 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo Weighted-Average Remaining Lease Term (years): Operating Leases 10.39 5.91 2.95 5.68 5.87 6.69 20.89 20.24 Finance Leases 2.95 5.51 0.00 4.97 2.10 5.54 6.18 4.53 Weighted-Average Discount Rate: Operating Leases 3.35 % 3.53 % 0.90 % 3.42 % 3.46 % 3.56 % 3.35 % 3.34 % Finance Leases 3.26 % 4.31 % — % 7.16 % 3.02 % 4.19 % 4.23 % 4.68 % December 31, 2020 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo Weighted-Average Remaining Lease Term (years): Operating Leases 5.30 6.51 2.01 6.27 3.50 7.44 7.03 7.54 Finance Leases 5.43 6.07 0.00 5.75 5.79 5.90 6.16 4.95 Weighted-Average Discount Rate: Operating Leases 3.44 % 3.60 % 1.51 % 3.48 % 3.42 % 3.60 % 3.39 % 3.45 % Finance Leases 5.68 % 4.39 % — % 7.33 % 8.29 % 4.25 % 4.35 % 4.77 % Year Ended December 31, 2021 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Cash paid for amounts included in the measurement of lease liabilities: Operating Cash Flows Used for Operating Leases $ 279.9 $ 18.0 $ 1.6 $ 19.3 $ 92.9 $ 19.0 $ 8.7 $ 11.6 Operating Cash Flows Used for Finance Leases 14.3 1.4 — 2.4 2.9 0.8 0.6 2.5 Financing Cash Flows Used for Finance Leases 64.0 6.7 — 7.7 6.8 4.9 3.2 10.9 Non-cash Acquisitions Under Operating Leases $ 117.0 $ 4.4 $ 2.1 $ 4.2 $ 2.6 $ 4.2 $ 33.4 $ 42.9 Year Ended December 31, 2020 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Cash paid for amounts included in the measurement of lease liabilities: Operating Cash Flows Used for Operating Leases $ 280.3 $ 17.1 $ 2.6 $ 19.2 $ 102.2 $ 16.9 $ 7.7 $ 9.4 Operating Cash Flows Used for Finance Leases 15.4 1.5 — 2.7 3.1 0.9 0.7 2.2 Financing Cash Flows Used for Finance Leases 61.7 6.3 — 7.4 6.5 4.7 3.5 10.9 Non-cash Acquisitions Under Operating Leases $ 161.7 $ 15.8 $ 1.8 $ 16.2 $ 18.1 $ 18.1 $ 12.3 $ 18.4 The following tables show property, plant and equipment under finance leases and noncurrent assets under operating leases and related obligations recorded on the balance sheets. Unless shown as a separate line on the balance sheets due to materiality, net operating lease assets are included in Deferred Charges and Other Noncurrent Assets, current finance lease obligations are included in Other Current Liabilities and long-term finance lease obligations are included in Deferred Credits and Other Noncurrent Liabilities on the balance sheets. Lease obligations are not recognized on the balance sheets for lease agreements with a lease term of less than twelve months. December 31, 2021 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Property, Plant and Equipment Under Finance Leases: Generation $ 388.8 $ — $ — $ 42.8 $ 156.8 $ — $ 0.6 $ 34.3 Other Property, Plant and Equipment 323.8 50.7 — 20.4 42.1 32.1 23.9 55.7 Total Property, Plant and Equipment 712.6 50.7 — 63.2 198.9 32.1 24.5 90.0 Accumulated Amortization 222.4 19.9 — 27.5 38.2 12.8 9.2 47.8 Net Property, Plant and Equipment Under Finance Leases $ 490.2 (a) $ 30.8 $ — $ 35.7 $ 160.7 $ 19.3 $ 15.3 $ 42.2 Obligations Under Finance Leases: Noncurrent Liability $ 196.1 $ 24.2 $ — $ 28.1 $ 31.7 $ 14.9 $ 12.3 $ 38.9 Liability Due Within One Year 304.6 6.6 — 7.6 130.5 4.4 3.0 10.8 Total Obligations Under Finance Leases $ 500.7 (b) $ 30.8 $ — $ 35.7 $ 162.2 $ 19.3 $ 15.3 $ 49.7 (a) Amount excludes $3 million of Net Property, Plant and Equipment Under Finance Leases classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (b) Amount excludes $3 million of Obligations Under Finance Leases classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. December 31, 2020 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Property, Plant and Equipment Under Finance Leases: Generation $ 138.2 $ — $ — $ 42.8 $ 28.8 $ — $ 0.7 $ 37.7 Other Property, Plant and Equipment 322.8 49.7 — 20.3 40.2 31.4 23.0 52.4 Total Property, Plant and Equipment 461.0 49.7 — 63.1 69.0 31.4 23.7 90.1 Accumulated Amortization 176.8 16.6 — 21.4 27.3 9.8 8.7 36.5 Net Property, Plant and Equipment Under Finance Leases $ 284.2 $ 33.1 $ — $ 41.7 $ 41.7 $ 21.6 $ 15.0 $ 53.6 Obligations Under Finance Leases: Noncurrent Liability $ 231.0 $ 26.8 $ — $ 34.4 $ 35.3 $ 16.9 $ 11.9 $ 44.6 Liability Due Within One Year 58.1 6.3 — 7.3 6.4 4.7 3.1 10.7 Total Obligations Under Finance Leases $ 289.1 $ 33.1 $ — $ 41.7 $ 41.7 $ 21.6 $ 15.0 $ 55.3 December 31, 2021 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Assets $ 578.3 (a) $ 73.6 $ 2.0 $ 66.9 $ 63.5 $ 81.2 $ 68.9 $ 80.1 Obligations Under Operating Leases: Noncurrent Liability $ 492.8 $ 61.3 $ 1.3 $ 52.4 $ 48.9 $ 68.6 $ 62.2 $ 77.7 Liability Due Within One Year 97.6 14.0 0.9 15.1 15.5 13.1 6.9 8.1 Total Obligations Under Operating Leases $ 590.4 (b) $ 75.3 $ 2.2 $ 67.5 $ 64.4 $ 81.7 $ 69.1 $ 85.8 (a) Amount excludes $11 million of Operating Lease Assets classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (b) Amount excludes $11 million of Obligations Under Operating Leases classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. December 31, 2020 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Assets $ 866.4 $ 84.1 $ 1.6 $ 78.8 $ 218.1 $ 92.0 $ 42.6 $ 48.5 Obligations Under Operating Leases: Noncurrent Liability $ 638.4 $ 71.0 $ 0.4 $ 64.4 $ 135.9 $ 79.5 $ 36.2 $ 44.1 Liability Due Within One Year 241.3 14.5 1.2 14.9 85.6 13.1 6.5 7.9 Total Obligations Under Operating Leases $ 879.7 $ 85.5 $ 1.6 $ 79.3 $ 221.5 $ 92.6 $ 42.7 $ 52.0 Future minimum lease payments consisted of the following as of December 31, 2021: Finance Leases AEP (a) AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) 2022 $ 317.3 $ 7.8 $ — $ 9.8 $ 133.7 $ 5.1 $ 3.6 $ 12.6 2023 61.0 7.1 — 9.1 8.6 4.4 3.3 11.8 2024 64.7 5.9 — 8.3 11.6 3.7 2.8 15.9 2025 35.6 4.5 — 7.2 5.9 2.5 2.1 5.6 2026 20.1 3.5 — 2.7 3.5 2.0 1.8 2.3 After 2026 39.2 5.9 — 4.1 10.1 4.0 3.9 6.0 Total Future Minimum Lease Payments 537.9 34.7 — 41.2 173.4 21.7 17.5 54.2 Less: Imputed Interest 37.2 3.9 — 5.5 11.2 2.4 2.2 4.5 Estimated Present Value of Future Minimum Lease Payments $ 500.7 $ 30.8 $ — $ 35.7 $ 162.2 $ 19.3 $ 15.3 $ 49.7 (a) Amount excludes $3 million of Obligations Under Finance Leases classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. Operating Leases AEP (a) AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) 2022 $ 119.6 $ 16.7 $ 0.9 $ 17.5 $ 17.6 $ 16.2 $ 9.2 $ 13.0 2023 102.2 15.5 0.7 14.8 11.7 15.2 8.9 11.8 2024 89.9 14.1 0.4 11.9 10.4 13.8 8.1 10.0 2025 76.7 11.7 0.2 9.1 9.3 12.1 6.9 8.7 2026 64.0 9.5 — 7.2 7.3 11.0 6.0 7.5 After 2026 272.4 16.9 — 14.1 15.0 24.2 62.6 80.4 Total Future Minimum Lease Payments 724.8 84.4 2.2 74.6 71.3 92.5 101.7 131.4 Less: Imputed Interest 134.4 9.1 — 7.1 6.9 10.8 32.6 45.6 Estimated Present Value of Future Minimum Lease Payments $ 590.4 $ 75.3 $ 2.2 $ 67.5 $ 64.4 $ 81.7 $ 69.1 $ 85.8 (a) Amount excludes $11 million of Obligations Under Operating Leases classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. Master Lease Agreements (Applies to all Registrants except AEPTCo) The Registrants lease certain equipment under master lease agreements. Under the lease agreements, the lessor is guaranteed a residual value up to a stated percentage of the equipment cost at the end of the lease term. If the actual fair value of the leased equipment is below the guaranteed residual value at the end of the lease term, the Registrants are committed to pay the difference between the actual fair value and the residual value guarantee. Historically, at the end of the lease term the fair value has been in excess of the amount guaranteed. As of December 31, 2021, the maximum potential loss by the Registrants for these lease agreements assuming the fair value of the equipment is zero at the end of the lease term was as follows: Company Maximum (in millions) AEP $ 47.4 AEP Texas 11.1 APCo 6.2 I&M 4.1 OPCo 7.5 PSO 4.6 SWEPCo 5.2 Rockport Lease (Applies to AEP and I&M) AEGCo and I&M entered into a sale-and-leaseback transaction in 1989 with Wilmington Trust Company (Owner Trustee), an unrelated, unconsolidated trustee for Rockport Plant, Unit 2. The trusts were capitalized with equity from six owner participants with no relationship to AEP or any of its subsidiaries and debt from a syndicate of banks and securities in a private placement to certain institutional investors. The trusts own undivided interests in Rockport Plant, Unit 2 and leases equal portions to AEGCo and I&M. In April 2021, AEGCo and I&M executed an agreement to purchase 100% of the interests in Rockport Plant, Unit 2 effective at the end of the lease term in December 2022. In December 2021, AEGCo and I&M satisfied the necessary regulatory approvals to complete the acquisition. Upon receipt of the regulatory approvals, the addition of the lessee forward purchase obligation resulted in the modified lease changing classification from operating to finance for AEGCo and I&M. The future minimum lease payments as of December 31, 2021, inclusive of the purchase obligation, were as follows: Future Minimum Lease Payments AEP (a) I&M (in millions) 2022 $ 248.7 $ 124.4 Total Future Minimum Lease Payments $ 248.7 $ 124.4 (a) AEP’s future minimum lease payments include equal shares from AEGCo and I&M. The lease modification also created variable interests in the trusts that own the undivided interests in Rockport Plant, Unit 2 for I&M and AEGCo. Neither I&M nor AEGCo are the primary beneficiaries of the trusts because AEGCo nor I&M has the power to direct the most significant activities of the trusts. AEP and I&M’s maximum exposure to loss associated with the trusts is equal to the total future minimum lease payments, inclusive of the purchase obligation, as shown in the table above. AEPRO Boat and Barge Leases (Applies to AEP) In 2015, AEP sold its commercial barge transportation subsidiary, AEPRO, to a nonaffiliated party. Certain boat and barge leases acquired by the nonaffiliated party are subject to an AEP guarantee in favor of the respective lessors, ensuring future payments under such leases with maturities up to 2027. As of December 31, 2021, the maximum potential amount of future payments required under the guaranteed leases was $42 million. Under the terms of certain of the arrangements, upon the lessors exercising their rights after an event of default by the nonaffiliated party, AEP is entitled to enter into new lease arrangements as a lessee that would have substantially the same terms as the existing leases. Alternatively, for the arrangements with one of the lessors, upon an event of default by the nonaffiliated party and the lessor exercising its rights, payment to the lessor would allow AEP to step into the lessor’s rights as well as obtaining title to the assets. Under either situation, AEP would have the ability to utilize the assets in the normal course of barging operations. AEP would also have the right to sell the acquired assets for which it obtained title. As of December 31, 2021, AEP’s boat and barge lease guarantee liability was $2 million, of which $1 million was recorded in Other Current Liabilities and $1 million was recorded in Deferred Credits and Other Noncurrent Liabilities on AEP’s balance sheet. In February 2020, the nonaffiliated party filed Chapter 11 bankruptcy. The party entered into a restructuring support agreement and has announced it expects to continue their operations as normal. In March 2020, the bankruptcy court approved the party’s recapitalization plan. In April 2020, the nonaffiliated party emerged from bankruptcy. Management has determined that it is reasonably possible that enforcement of AEP’s liability for future payments under these leases will be exercised within the next twelve months. In such an event, if AEP is unable to sell or incorporate any of the acquired assets into its fleet operations, it could reduce future net income and cash flows and impact financial condition. Lessor Activity The Registrants’ lessor activity was immaterial as of and for the twelve months ended December 31, 2021 and December 31, 2020, respectively.	[1],[2]

[1]	Amount excludes $11 million of Obligations Under Operating Leases classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[2]	Amount excludes $11 million of Operating Lease Assets classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.

Financing Activities

Financing Activities	12 Months Ended
Financing Activities	Dec. 31, 2021
Financing Activities	14. FINANCING ACTIVITIES The disclosures in this note apply to all Registrants, unless indicated otherwise. Common Stock (Applies to AEP) The following table is a reconciliation of common stock share activity: Shares of AEP Common Stock Issued Held in Treasury Balance, December 31, 2018 513,450,036 20,204,160 Issued 923,595 — Balance, December 31, 2019 514,373,631 20,204,160 Issued 2,434,723 — Balance, December 31, 2020 516,808,354 20,204,160 Issued 7,607,821 — Balance, December 31, 2021 524,416,175 20,204,160 ATM Program In 2020, AEP filed a prospectus supplement and executed an Equity Distribution Agreement, pursuant to which AEP may sell, from time to time, up to an aggregate of $1 billion of its common stock through an ATM offering program, including an equity forward sales component. The compensation paid to the selling agents by AEP may be up to 2% of the gross offering proceeds of the shares. For the year ended December 31, 2021, AEP issued 5,701,825 shares of common stock and received net cash proceeds of $484 million under the ATM program. Long-term Debt The following table details long-term debt outstanding: Weighted-Average Interest Rate Ranges as of Outstanding as of Interest Rate as of December 31, December 31, Company Maturity December 31, 2021 2021 2020 2021 2020 AEP (in millions) Senior Unsecured Notes 2021-2051 3.69% 0.61%-7.00% 0.70%-8.13% $ 27,497.3 $ 25,116.1 Pollution Control Bonds (a) 2021-2036 (b) 2.40% 0.19%-4.55% 0.18%-4.63% 1,804.5 1,936.7 Notes Payable – Nonaffiliated (c) 2021-2032 2.41% 0.79%-6.37% 0.84%-6.37% 211.3 239.1 Securitization Bonds 2023-2029 (d) 2.84% 2.01%-3.77% 2.01%-3.77% 603.5 716.4 Spent Nuclear Fuel Obligation (e) 281.3 281.2 Junior Subordinated Notes (f) 2023-2027 2.81% 1.30%-3.88% 1.30%-3.40% 2,373.0 1,624.1 Other Long-term Debt 2021-2059 1.63% 0.91%-13.72% 0.81%-13.72% 683.6 1,158.9 Total Long-term Debt Outstanding (g) $ 33,454.5 $ 31,072.5 AEP Texas Senior Unsecured Notes 2022-2051 3.67% 2.10%-6.76% 2.10%-6.76% $ 4,135.5 $ 3,687.6 Pollution Control Bonds 2023-2030 (b) 3.42% 0.90%-4.55% 0.90%-4.55% 439.9 439.7 Securitization Bonds 2024-2029 (d) 2.53% 2.06%-2.84% 2.06%-2.84% 404.7 492.6 Other Long-term Debt 2022-2059 1.37% 1.35%-4.50% 1.40%-4.50% 200.7 200.5 Total Long-term Debt Outstanding $ 5,180.8 $ 4,820.4 AEPTCo Senior Unsecured Notes 2021-2051 3.73% 2.75%-5.52% 3.10%-5.52% $ 4,343.9 $ 3,948.5 Total Long-term Debt Outstanding $ 4,343.9 $ 3,948.5 APCo Senior Unsecured Notes 2021-2050 4.70% 2.70%-7.00% 3.30%-7.00% $ 4,083.7 $ 3,937.2 Pollution Control Bonds (a) 2021-2036 (b) 1.67% 0.19%-2.75% 0.19%-4.63% 529.5 546.3 Securitization Bonds 2023-2028 (d) 3.46% 2.01%-3.77% 2.01%-3.77% 198.8 223.8 Other Long-term Debt 2022-2026 1.42% 1.24%-13.72% 1.32%-13.72% 126.9 126.8 Total Long-term Debt Outstanding $ 4,938.9 $ 4,834.1 I&M Senior Unsecured Notes 2023-2051 4.19% 3.20%-6.05% 3.20%-6.05% $ 2,595.5 $ 2,152.2 Pollution Control Bonds (a) 2021-2025 (b) 2.49% 0.75%-3.05% 0.18%-3.05% 188.7 240.5 Notes Payable – Nonaffiliated (c) 2021-2025 0.99% 0.79%-1.24% 0.84%-1.29% 122.2 146.7 Spent Nuclear Fuel Obligation (e) 281.3 281.2 Other Long-term Debt 2021-2025 6.00% 6.00% 1.28%-6.00% 7.3 209.3 Total Long-term Debt Outstanding $ 3,195.0 $ 3,029.9 OPCo Senior Unsecured Notes 2021-2051 3.87% 1.63%-6.60% 2.60%-6.60% $ 2,967.8 $ 2,429.4 Other Long-term Debt 2028 1.15% 1.15% 1.15% 0.7 0.8 Total Long-term Debt Outstanding $ 2,968.5 $ 2,430.2 PSO Senior Unsecured Notes 2021-2051 3.74% 2.20%-6.63% 3.05%-6.63% $ 1,785.5 $ 1,246.3 Other Long-term Debt 2022-2027 1.50% 1.47%-3.00% 1.42%-3.00% 128.0 127.5 Total Long-term Debt Outstanding $ 1,913.5 $ 1,373.8 SWEPCo Senior Unsecured Notes 2022-2051 3.57% 1.65%-6.20% 2.75%-6.20% $ 3,295.1 $ 2,430.8 Notes Payable – Nonaffiliated (c) 2024-2032 5.34% 4.58%-6.37% 4.58%-6.37% 59.1 62.4 Other Long-term Debt 2021-2035 4.68% 4.68% 2.25%-4.68% 41.0 143.2 Total Long-term Debt Outstanding $ 3,395.2 $ 2,636.4 (a) For certain series of Pollution Control Bonds, interest rates are subject to periodic adjustment. Certain series may be purchased on demand at periodic interest adjustment dates. Letters of credit from banks and insurance policies support certain series. Consequently, these bonds have been classified for maturity purposes as Long-term Debt Due Within One Year - Nonaffiliated on the balance sheets. (b) Certain Pollution Control Bonds are subject to redemption earlier than the maturity date. (c) Notes payable represent outstanding promissory notes issued under term loan agreements and credit agreements with a number of banks and other financial institutions. At expiration, all notes then issued and outstanding are due and payable. Interest rates are both fixed and variable. Variable rates generally relate to specified short-term interest rates. (d) Dates represent the scheduled final payment dates for the securitization bonds. The legal maturity date is one to two years later. These bonds have been classified for maturity and repayment purposes based on the scheduled final payment date. (e) Spent Nuclear Fuel Obligation consists of a liability along with accrued interest for disposal of SNF. See “Spent Nuclear Fuel Disposal” section of Note 6 for additional information. (f) See “Equity Units” section below for additional information. (g) 2021 amount excludes $1.1 billion of Total Long-term Debt Outstanding classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. As of December 31, 2021, outstanding long-term debt was payable as follows: AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) 2022 $ 2,153.8 $ 716.0 $ 104.0 $ 480.7 $ 67.0 $ 0.1 $ 125.5 $ 6.2 2023 2,629.9 (a) 278.5 60.0 26.6 289.8 0.1 0.5 6.2 2024 1,462.2 (b) 96.0 95.0 113.5 16.8 0.1 0.6 31.2 2025 1,762.4 324.5 90.0 443.9 195.9 0.1 125.6 6.2 2026 1,497.9 75.0 425.0 30.9 — 0.1 50.6 906.2 After 2026 24,246.7 3,732.0 3,616.0 3,887.4 2,656.3 3,000.2 1,625.3 2,469.3 Principal Amount 33,752.9 5,222.0 4,390.0 4,983.0 3,225.8 3,000.7 1,928.1 3,425.3 Unamortized Discount, Net and Debt Issuance Costs (298.4) (41.2) (46.1) (44.1) (30.8) (32.2) (14.6) (30.1) Total Long-term Debt Outstanding $ 33,454.5 (c) $ 5,180.8 $ 4,343.9 $ 4,938.9 $ 3,195.0 $ 2,968.5 $ 1,913.5 $ 3,395.2 (a) Amount includes $850 million of Junior Subordinated Notes. See “Equity Units” section below for additional information. (b) Amount includes $805 million of Junior Subordinated Notes. See “Equity Units” section below for additional information. (c) Amount excludes $1.1 billion of Total Long-term Debt Outstanding classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. Long-term Debt Subsequent Events In January and February 2022, I&M retired $8 million and $8 million, respectively, of Notes Payable related to DCC Fuel. In February 2022, PSO issued $500 million of variable rate Other Long-term Debt due in 2022. In February 2022, AEP Texas retired $11 million of Securitization Bonds. In February 2022, APCo retired $13 million of Securitization Bonds. Equity Units (Applies to AEP) 2020 Equity Units In August 2020, AEP issued 17 million Equity Units initially in the form of corporate units, at a stated amount of $50 per unit, for a total stated amount of $850 million. Net proceeds from the issuance were approximately $833 million. The proceeds were used to support AEP’s overall capital expenditure plans. Each corporate unit represents a 1/20 undivided beneficial ownership interest in $1,000 principal amount of AEP’s 1.30% Junior Subordinated Notes (notes) due in 2025 and a forward equity purchase contract which settles after three years in 2023. The notes are expected to be remarketed in 2023, at which time the interest rate will reset at the then-current market rate. Investors may choose to remarket their notes to receive the remarketing proceeds and use those funds to settle the forward equity purchase contract, or accept the remarketed debt and use other funds for the equity purchase. If the remarketing is unsuccessful, investors have the right to put their notes to AEP at a price equal to the principal. The Equity Units carry an annual distribution rate of 6.125%, which is comprised of a quarterly coupon rate of interest of 1.30% and a quarterly forward equity purchase contract payment of 4.825%. Each forward equity purchase contract obligates the holder to purchase, and AEP to sell, for $50 a number of shares in common stock in accordance with the conversion ratios set forth below (subject to an anti-dilution adjustment): • If the AEP common stock market price is equal to or greater than $99.95: 0.5003 shares per contract. • If the AEP common stock market price is less than $99.95 but greater than $83.29: a number of shares per contract equal to $50 divided by the applicable market price. The holder receives a variable number of shares at $50. • If the AEP common stock market price is less than or equal to $83.29: 0.6003 shares per contract. A holder’s ownership interest in the notes is pledged to AEP to secure the holder’s obligation under the related forward equity purchase contract. If a holder of the forward equity purchase contract chooses at any time to no longer be a holder of the notes, such holder’s obligation under the forward equity purchase contract must be secured by a U.S. Treasury security which must be equal to the aggregate principal amount of the notes. At the time of issuance, the $850 million of notes were recorded within Long-term Debt on the balance sheets. The present value of the purchase contract payments of $121 million were recorded in Deferred Credits and Other Noncurrent Liabilities with a current portion in Other Current Liabilities at the time of issuance, representing the obligation to make forward equity contract payments, with an offsetting reduction to Paid-in Capital. The difference between the face value and present value of the purchase contract payments will be accreted to Interest Expense on the statements of income over the three year period ending in 2023. The liability recorded for the contract payments is considered non-cash and excluded from the statements of cash flows. Until settlement of the forward equity purchase contract, earnings per-share dilution resulting from the equity unit issuance will be determined under the treasury stock method. The maximum amount of shares AEP will be required to issue to settle the purchase contract is 10,205,100 shares (subject to an anti-dilution adjustment). 2019 Equity Units In March 2019, AEP issued 16.1 million Equity Units initially in the form of corporate units, at a stated amount of $50 per unit, for a total stated amount of $805 million. Net proceeds from the issuance were approximately $785 million. The proceeds were used to support AEP’s overall capital expenditure plans including the acquisition of Sempra Renewables LLC. Each corporate unit represents a 1/20 undivided beneficial ownership interest in $1,000 principal amount of AEP’s 3.40% Junior Subordinated Notes (notes) due in 2024 and a forward equity purchase contract which settles after three years in 2022. In January 2022, AEP successfully remarketed the notes on behalf of holders of the corporate units and did not directly receive any proceeds therefrom. Instead, the holders of the corporate units may use the debt remarketing proceeds towards settling the forward equity purchase contract with AEP in March 2022. The interest rate on the notes was reset to 2.031% with the maturity remaining in 2024. Each forward equity purchase contract obligates the holder to purchase, and AEP to sell, for $50 a number of shares in common stock in accordance with the conversion ratios set forth below (subject to an anti-dilution adjustment): • If the AEP common stock market price is equal to or greater than $99.58: 0.5021 shares per contract. • If the AEP common stock market price is less than $99.58 but greater than $82.98: a number of shares per contract equal to $50 divided by the applicable market price. The holder receives a variable number of shares at $50. • If the AEP common stock market price is less than or equal to $82.98: 0.6026 shares per contract. A holder’s ownership interest in the notes is pledged to AEP to secure the holder’s obligation under the related forward equity purchase contract. If a holder of the forward equity purchase contract chooses at any time to no longer be a holder of the notes, such holder’s obligation under the forward equity purchase contract must be secured by a U.S. Treasury security which must be equal to the aggregate principal amount of the notes. At the time of issuance, the $805 million of notes were recorded within Long-term Debt on the balance sheets. The present value of the purchase contract payments of $62 million were recorded in Deferred Credits and Other Noncurrent Liabilities with a current portion in Other Current Liabilities at the time of issuance, representing the obligation to make forward equity contract payments, with an offsetting reduction to Paid-in Capital. The difference between the face value and present value of the purchase contract payments will be accreted to Interest Expense on the statements of income over the three year period ending in 2022. The liability recorded for the contract payments is considered non-cash and excluded from the statements of cash flows. Until settlement of the forward equity purchase contract, earnings per-share dilution resulting from the equity unit issuance will be determined under the treasury stock method. The maximum amount of shares AEP will be required to issue to settle the purchase contract is 9,701,860 shares (subject to an anti-dilution adjustment). Debt Covenants (Applies to AEP and AEPTCo) Covenants in AEPTCo’s note purchase agreements and indenture limit the amount of contractually-defined priority debt (which includes a further sub-limit of $50 million of secured debt) to 10% of consolidated tangible net assets. AEPTCo’s contractually-defined priority debt was 1.1% of consolidated tangible net assets as of December 31, 2021. The method for calculating the consolidated tangible net assets is contractually-defined in the note purchase agreement. Dividend Restrictions Utility Subsidiaries’ Restrictions Parent depends on its utility subsidiaries to pay dividends to shareholders. AEP utility subsidiaries pay dividends to Parent provided funds are legally available. Various financing arrangements and regulatory requirements may impose certain restrictions on the ability of the subsidiaries to transfer funds to Parent in the form of dividends. All of the dividends declared by AEP’s utility subsidiaries that provide transmission or local distribution services are subject to a Federal Power Act restriction that prohibits the payment of dividends out of capital accounts without regulatory approval; payment of dividends is allowed out of retained earnings only. The Federal Power Act also creates a reserve on retained earnings attributable to hydroelectric generation plants. Because of their ownership of such plants, this reserve applies to APCo and I&M. Certain AEP subsidiaries have credit agreements that contain covenants that limit their debt to capitalization ratio to 67.5%. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. The most restrictive dividend limitation for certain AEP subsidiaries is through the Federal Power Act restriction, while for other AEP subsidiaries the most restrictive dividend limitation is through the credit agreements. As of December 31, 2021, the maximum amount of restricted net assets of AEP’s subsidiaries that may not be distributed to the Parent in the form of a loan, advance or dividend was $15.5 billion. The Federal Power Act restriction limits the ability of the AEP subsidiaries owning hydroelectric generation to pay dividends out of retained earnings. Additionally, the credit agreement covenant restrictions can limit the ability of the AEP subsidiaries to pay dividends out of retained earnings. As of December 31, 2021, the amount of any such restrictions were as follows: AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Restricted Retained Earnings $ 2,655.2 (a) $ 791.8 $ — $ 313.4 $ 648.5 $ — $ — $ 577.9 (a) Includes the restrictions of consolidated and non-consolidated subsidiaries. Parent Restrictions (Applies to AEP) The holders of AEP’s common stock are entitled to receive the dividends declared by the Board of Directors provided funds are legally available for such dividends. Parent’s income primarily derives from common stock equity in the earnings of its utility subsidiaries. Pursuant to the leverage restrictions in credit agreements, AEP must maintain a percentage of debt-to-total capitalization at a level that does not exceed 67.5%. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. As of December 31, 2021, AEP had $8.2 billion of available retained earnings to pay dividends to common shareholders. AEP paid $1.5 billion, $1.4 billion and $1.3 billion of dividends to common shareholders for the years ended December 31, 2021, 2020 and 2019, respectively. Lines of Credit and Short-term Debt (Applies to AEP and SWEPCo) AEP uses its commercial paper program to meet the short-term borrowing needs of its subsidiaries. The program funds a Utility Money Pool, which funds AEP’s utility subsidiaries; a Nonutility Money Pool, which funds certain AEP nonutility subsidiaries; and the short-term debt requirements of subsidiaries that are not participating in either money pool for regulatory or operational reasons, as direct borrowers. As of December 31, 2021, AEP had $5 billion in revolving credit facilities to support its commercial paper program. The commercial paper program for the year ended 2021, had a weighted-average interest rate of 0.24% and a maximum amount outstanding of $2.5 billion. AEP’s outstanding short-term debt was as follows: December 31, 2021 2020 Company Type of Debt Outstanding Interest Outstanding Interest (in millions) (in millions) AEP Securitized Debt for Receivables (b) $ 750.0 0.19 % $ 592.0 0.85 % AEP Commercial Paper 1,364.0 0.34 % 1,852.3 0.29 % AEP 364-Day Term Loan 500.0 0.81 % — — % SWEPCo Notes Payable — — % 35.0 2.55 % Total Short-term Debt $ 2,614.0 $ 2,479.3 (a) Weighted-average rate. (b) Amount of securitized debt for receivables as accounted for under the “Transfers and Servicing” accounting guidance. Corporate Borrowing Program – AEP System (Applies to Registrant Subsidiaries) The AEP System uses a corporate borrowing program to meet the short-term borrowing needs of AEP’s subsidiaries. The corporate borrowing program includes a Utility Money Pool, which funds AEP’s utility subsidiaries; a Nonutility Money Pool, which funds certain AEP nonutility subsidiaries; and direct borrowing from AEP. The AEP System Utility Money Pool operates in accordance with the terms and conditions of its agreement filed with the FERC. The amounts of outstanding loans to (borrowings from) the Utility Money Pool as of December 31, 2021 and 2020 are included in Advances to Affiliates and Advances from Affiliates, respectively, on the Registrant Subsidiaries’ balance sheets. The Utility Money Pool participants’ money pool activity and corresponding authorized borrowing limits are described in the following tables: Year Ended December 31, 2021: Maximum Average Net Loans to Borrowings Maximum Borrowings Average (Borrowings from) Authorized from the Loans to the from the Loans to the the Utility Money Short-term Utility Utility Utility Utility Pool as of Borrowing Company Money Pool Money Pool Money Pool Money Pool December 31, 2021 Limit (in millions) AEP Texas $ 355.5 $ 104.7 $ 172.5 $ 40.0 $ (26.9) $ 500.0 AEPTCo 444.9 117.3 189.1 29.7 (108.0) (b) 820.0 (a) APCo 199.3 616.9 87.5 118.3 (178.5) 500.0 I&M 166.5 368.2 110.4 67.7 (71.8) 500.0 OPCo 259.2 622.9 61.6 127.2 42.0 500.0 PSO 267.7 747.3 134.0 113.1 (72.3) 400.0 SWEPCo 280.3 561.9 142.4 287.4 153.8 400.0 Year Ended December 31, 2020: Maximum Average Net Loans to Borrowings Maximum Borrowings Average (Borrowings from) Authorized from the Loans to the from the Loans to the the Utility Money Short-term Utility Utility Utility Utility Pool as of Borrowing Company Money Pool Money Pool Money Pool Money Pool December 31, 2020 Limit (in millions) AEP Texas $ 320.4 $ 313.4 $ 132.0 $ 139.0 $ (67.1) $ 500.0 AEPTCo 358.4 259.7 116.3 55.0 (155.4) 820.0 (a) APCo 434.3 189.0 242.8 76.3 2.8 500.0 I&M 218.6 13.4 114.5 13.3 (89.7) 500.0 OPCo 353.9 32.8 182.4 25.2 (259.2) 500.0 PSO 155.4 57.1 72.3 28.4 (155.4) 300.0 SWEPCo 178.9 — 113.0 — (124.6) 350.0 (a) Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions. (b) Amount excludes $1 million of Advances from Affiliates classified as Liabilities Held for Sale on the AEP Transco balance sheet. See “Dispositions of KPCo and KTCo” section of Note 7 for additional information. The activity in the above tables does not include short-term lending activity of certain AEP nonutility subsidiaries. AEP Texas’ wholly-owned subsidiary, AEP Texas North Generation Company, LLC and SWEPCo’s wholly-owned subsidiary, Mutual Energy SWEPCo, LLC participate in the Nonutility Money Pool. The amounts of outstanding loans to the Nonutility Money Pool as of December 31, 2021 and 2020 are included in Advances to Affiliates on each subsidiaries’ balance sheets. The Nonutility Money Pool participants’ money pool activity is described in the following tables: Year Ended December 31, 2021: Maximum Loans Average Loans Loans to the Nonutility to the Nonutility to the Nonutility Money Pool as of Company Money Pool Money Pool December 31, 2021 (in millions) AEP Texas $ 7.1 $ 6.9 $ 6.9 SWEPCo 2.1 2.1 2.1 Year Ended December 31, 2020: Maximum Loans Average Loans Loans to the Nonutility to the Nonutility to the Nonutility Money Pool as of Company Money Pool Money Pool December 31, 2020 (in millions) AEP Texas $ 7.5 $ 7.1 $ 7.1 SWEPCo 2.1 2.1 2.1 AEP has a direct financing relationship with AEPTCo to meet its short-term borrowing needs. The amounts of outstanding loans to and borrowings from AEP as of December 31, 2021 and 2020 are included in Advances to Affiliates and Advances from Affiliates, respectively, on AEPTCo’s balance sheets. AEPTCo’s direct financing activities with AEP and corresponding authorized borrowing limits are described in the following tables: Year Ended December 31, 2021: Maximum Maximum Average Average Borrowings from Loans to Authorized Borrowings Loans Borrowings Loans AEP as of AEP as of Short-term from AEP to AEP from AEP to AEP December 31, 2021 December 31, 2021 Borrowing Limit (in millions) $ 14.6 $ 224.2 $ 1.8 $ 118.0 $ 1.5 $ 12.7 $ 50.0 (a) Year Ended December 31, 2020: Maximum Maximum Average Average Borrowings from Loans to Authorized Borrowings Loans Borrowings Loans AEP as of AEP as of Short-term from AEP to AEP from AEP to AEP December 31, 2020 December 31, 2020 Borrowing Limit (in millions) $ 1.4 $ 215.3 $ 1.3 $ 132.6 $ 1.2 $ 109.0 $ 50.0 (a) (a) Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions. The maximum and minimum interest rates for funds either borrowed from or loaned to the Utility Money Pool are summarized in the following table: Years Ended December 31, 2021 2020 2019 Maximum Interest Rate 0.48 % 2.70 % 3.43 % Minimum Interest Rate 0.02 % 0.27 % 1.77 % The average interest rates for funds borrowed from and loaned to the Utility Money Pool are summarized in the following table: Average Interest Rate for Funds Borrowed Average Interest Rate for Funds Loaned Company 2021 2020 2019 2021 2020 2019 AEP Texas 0.33 % 1.51 % 2.63 % 0.26 % 0.81 % 2.03 % AEPTCo 0.32 % 1.29 % 2.64 % 0.10 % 1.99 % 2.41 % APCo 0.41 % 2.12 % 2.45 % 0.25 % 0.85 % 2.66 % I&M 0.33 % 1.07 % 2.34 % 0.23 % 1.18 % 2.60 % OPCo 0.27 % 0.99 % 2.67 % 0.14 % 2.06 % 2.68 % PSO 0.34 % 0.92 % 2.85 % 0.07 % 1.95 % 2.27 % SWEPCo 0.26 % 1.27 % 2.72 % 0.18 % — % 2.22 % Maximum, minimum and average interest rates for funds loaned to the Nonutility Money Pool are summarized in the following table: Maximum Interest Rate Minimum Interest Rate Average Interest Rate Year Ended for Funds Loaned to for Funds Loaned to for Funds Loaned to December 31, Company the Nonutility Money Pool the Nonutility Money Pool the Nonutility Money Pool 2021 AEP Texas 0.58 % 0.21 % 0.37 % 2021 SWEPCo 0.58 % 0.21 % 0.37 % 2020 AEP Texas 2.70 % 0.27 % 1.18 % 2020 SWEPCo 2.70 % 0.27 % 1.18 % 2019 AEP Texas 3.02 % 1.91 % 2.56 % 2019 SWEPCo 3.02 % 1.91 % 2.55 % AEPTCo’s maximum, minimum and average interest rates for funds either borrowed from or loaned to AEP are summarized in the following table: Maximum Minimum Maximum Minimum Average Average Interest Rate Interest Rate Interest Rate Interest Rate Interest Rate Interest Rate for Funds for Funds for Funds for Funds for Funds for Funds Year Ended Borrowed from Borrowed from Loaned to Loaned to Borrowed from Loaned to December 31, AEP AEP AEP AEP AEP AEP 2021 0.86 % 0.25 % 0.86 % 0.25 % 0.38 % 0.35 % 2020 2.70 % 0.27 % 2.70 % 0.27 % 1.20 % 1.13 % 2019 3.02 % 1.91 % 3.02 % 1.91 % 2.55 % 2.51 % Interest expense and interest income related to the Utility Money Pool, Nonutility Money Pool and direct borrowing financing relationship are included in Interest Expense and Interest Income, respectively, on each of the Registrant Subsidiaries’ statements of income. The interest expense and interest income related to the corporate borrowing programs were immaterial for the years ended December 31, 2021, 2020 and 2019. Credit Facilities See “Letters of Credit” section of Note 6 for additional information. Securitized Accounts Receivables – AEP Credit (Applies to AEP) AEP Credit has a receivables securitization agreement with bank conduits. Under the securitization agreement, AEP Credit receives financing from the bank conduits for the interest in the receivables AEP Credit acquires from affiliated utility subsidiaries. These securitized transactions allow AEP Credit to repay its outstanding debt obligations, continue to purchase the operating companies’ receivables and accelerate AEP Credit’s cash collections. AEP Credit’s receivables securitization agreement provides a commitment of $750 million from bank conduits to purchase receivables and was amended in September 2021 to include a $125 million and a $625 million facility, which expire in September 2023 and 2024, respectively. As of December 31, 2021, the affiliated utility subsidiaries are in compliance with all requirements under the agreement. Accounts receivable information for AEP Credit was as follows: Years Ended December 31, 2021 2020 2019 (dollars in millions) Effective Interest Rates on Securitization of Accounts Receivable 0.19 % 0.85 % 2.42 % Net Uncollectible Accounts Receivable Written Off $ 26.5 $ 15.3 $ 26.6 December 31, 2021 2020 (in millions) Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts $ 995.2 $ 958.4 Short-term – Securitized Debt of Receivables 750.0 592.0 Delinquent Securitized Accounts Receivable 57.9 62.3 Bad Debt Reserves Related to Securitization 42.8 60.0 Unbilled Receivables Related to Securitization 307.1 296.8 AEP Credit’s delinquent customer accounts receivable represent accounts greater than 30 days past due. Securitized Accounts Receivables – AEP Credit (Applies to Registrant Subsidiaries, except AEP Texas and AEPTCo) Under this sale of receivables arrangement, the Registrant Subsidiaries sell, without recourse, certain of their customer accounts receivable and accrued unbilled revenue balances to AEP Credit and are charged a fee based on AEP Credit’s financing costs, administrative costs and uncollectible accounts experience for each Registrant Subsidiary’s receivables. APCo does not have regulatory authority to sell its West Virginia accounts receivable. KPCo terminated selling accounts receivable to AEP Credit in the first quarter of 2022, based on the pending sale to Liberty. As a result of the termination, in the first quarter of 2022, KPCo will record an allowance for uncollectible accounts on its balance sheet for those receivables no longer sold to AEP Credit. The costs of customer accounts receivable sold are reported in Other Operation expense on the Registrant Subsidiaries’ statements of income. The Registrant Subsidiaries manage and service their customer accounts receivable, which are sold to AEP Credit. AEP Credit securitizes the eligible receivables for the operating companies and retains the remainder. The amount of accounts receivable and accrued unbilled revenues under the sale of receivables agreement were: December 31, Company 2021 2020 (in millions) APCo $ 153.1 $ 136.0 I&M 156.9 170.5 OPCo 392.7 398.8 PSO 114.5 85.0 SWEPCo 153.0 158.6 The fees paid to AEP Credit for customer accounts receivable sold were: Years Ended December 31, Company 2021 (a) 2020 2019 (in millions) APCo $ 4.9 $ 5.2 $ 7.4 I&M 7.0 7.9 11.1 OPCo 8.3 24.1 27.1 PSO 3.4 4.8 7.8 SWEPCo 5.4 6.7 10.2 (a) In 2020, an increase in allowance for doubtful accounts was recognized in response to the anticipated impact of COVID-19 on the collectability of accounts receivable, which caused an increase in fees paid by the registrants. In 2021, due to higher than expected collections of accounts receivables, allowance for doubtful accounts was adjusted resulting in the issuance of credits to offset the higher fees previously paid and to lower subsequent fees paid. The proceeds on the sale of receivables to AEP Credit were: Years Ended December 31, Company 2021 2020 2019 (in millions) APCo $ 1,324.1 $ 1,272.9 $ 1,310.3 I&M 1,927.0 1,891.8 1,824.2 OPCo 2,458.5 2,366.2 2,293.6 PSO 1,406.4 1,221.0 1,442.5 SWEPCo 1,636.1 1,593.8 1,618.5

Stock-Based Compensation

Stock-Based Compensation	12 Months Ended
Stock-Based Compensation	Dec. 31, 2021
Stock-based Compensation	STOCK-BASED COMPENSATION The disclosures in this note apply to AEP only. The impact of AEP’s share-based compensation plans is insignificant to the financial statements of the Registrant Subsidiaries. Awards under AEP’s long-term incentive plan may be granted to employees and directors. The Amended and Restated American Electric Power System Long-Term Incentive Plan (Prior Plan), was replaced prospectively for new grants by the American Electric Power System 2015 Long-Term Incentive Plan (2015 LTIP) effective in April 2015. The 2015 LTIP was subsequently amended in September 2016. The 2015 LTIP provides for a maximum of 10 million AEP common shares to be available for grant to eligible employees and directors. As of December 31, 2021, 5,976,468 shares remained available for issuance under the 2015 LTIP. No new awards may be granted under the Prior Plan. The 2015 LTIP awards may be stock options, stock appreciation rights, restricted stock, restricted stock units, performance shares, performance units, cash-based awards and other stock-based awards. Shares issued pursuant to a stock option or a stock appreciation right reduce the shares remaining available for grants under the 2015 LTIP by 0.286 of a share. Each share issued for any other award that settles in AEP stock reduces the shares remaining available for grants under the 2015 LTIP by one share. Cash settled awards do not reduce the number of shares remaining available under the 2015 LTIP. The following sections provide further information regarding each type of stock-based compensation award granted under these plans. Performance Shares Performance units granted prior to 2017 were settled in cash rather than AEP common stock and did not reduce the number of shares remaining available under the 2015 LTIP. Those performance units had a fair value upon vesting equal to the average closing market price of AEP common stock for the last 20 trading days of the performance period. Performance shares granted in and after 2017 are settled in AEP common stock and reduce the aggregate share authorization. In all cases the number of performance shares held at the end of the three-year performance period is multiplied by the performance score for such period to determine the actual number of performance shares that participants realize. The performance score can range from 0% to 200% and is determined at the end of the performance period based on performance measures, which include both performance and market conditions, established for each grant at the beginning of the performance period by the Human Resources Committee of AEP’s Board of Directors (HR Committee). Certain employees must satisfy a minimum stock ownership requirement. If those employees have not met their stock ownership requirement, a portion or all of their performance shares are mandatorily deferred as AEP career shares to the extent needed to meet their stock ownership requirement. AEP career shares are a form of non-qualified deferred compensation that has a value equivalent to a share of AEP common stock. AEP career shares are settled in AEP common stock after the participant’s termination of employment. AEP career shares are recorded in Paid-in Capital on the balance sheets. Amounts equivalent to cash dividends on both performance shares and AEP career shares accrue as additional shares. Management records compensation cost for performance shares over an approximately three-year vesting period. Performance shares are recorded as mezzanine equity on the balance sheets until the vesting date and compensation cost is calculated at fair value based on metrics for each grant. Performance shares granted in 2021 and 2020 have three performance metrics: (a) three-year cumulative operating earnings per-share with a 50% weight, (b) total shareholder return with a 40% weight and (c) non-emitting generation capacity as a percentage of total owned and purchased capacity with a 10% weight. Performance shares granted in 2019 have two equally-weighted performance metrics: (a) three-year cumulative operating earnings per-share and (b) total shareholder return. The three-year cumulative operating earnings per-share metric and non-emitting generating capacity metric are adjusted quarterly for changes in performance relative to a target approved by the HR Committee. The total shareholder return metric is measured relative to a peer group of similar companies and is based on a third-party Monte Carlo valuation. The value related to this metric does not change over the three-year vesting period. The HR Committee awarded performance shares and reinvested dividends on outstanding performance shares and AEP career shares as follows: Years Ended December 31, Performance Shares 2021 2020 2019 Awarded Shares (in thousands) 565.0 424.8 535.0 Weighted-Average Share Fair Value at Grant Date $ 81.02 $ 116.56 $ 83.21 Vesting Period (in years) 3 3 3 Performance Shares and AEP Career Shares Years Ended December 31, 2021 2020 2019 Awarded Shares (in thousands) 74.5 73.4 66.4 Weighted-Average Fair Value at Grant Date $ 84.48 $ 84.87 $ 88.73 Vesting Period (in years) (a) (a) (a) (a) The vesting period for the reinvested dividends on performance shares is equal to the remaining life of the related performance shares. Dividends on AEP career shares vest immediately when the dividend is awarded but are not settled in AEP common stock until after the participant’s AEP employment ends. Performance scores and final awards are determined and approved by the HR Committee in accordance with the pre-established performance measures within approximately two months after the end of the performance period. The certified performance scores and shares earned for the three-year periods were as follows: Years Ended December 31, Performance Shares 2021 2020 2019 Certified Performance Score 102.9 % 128.2 % 132.7 % Performance Shares Earned 537,166 757,858 792,897 Performance Shares Mandatorily Deferred as AEP Career Shares 14,613 13,614 10,063 Performance Shares Voluntarily Deferred into the Incentive Compensation Deferral Program 22,915 26,936 49,392 Performance Shares to be Settled (a) 499,638 717,308 733,442 (a) Performance shares settled in AEP common stock in the quarter following the end of the year shown. The settlements were as follows: Years Ended December 31, Performance Shares and AEP Career Shares 2021 2020 2019 (in millions) Cash Settlements for Performance Units $ — $ — $ 58.3 AEP Common Stock Settlements for Performance Shares 54.7 75.4 — AEP Common Stock Settlements for Career Share Distributions 4.0 1.9 6.6 A summary of the status of AEP’s nonvested Performance Shares as of December 31, 2021 and changes during the year ended December 31, 2021 were as follows: Nonvested Performance Shares Shares Weighted (in thousands) Nonvested as of January 1, 2021 938.6 $ 98.05 Awarded 565.0 81.02 Dividends 53.4 84.45 Vested (a) (529.0) 83.87 Forfeited (104.2) 87.65 Nonvested as of December 31, 2021 923.8 96.15 (a) The vested Performance Shares will be converted to 500 thousand shares based on the closing share price on the day before settlement. Monte Carlo Valuation AEP engages a third-party for a Monte Carlo valuation to calculate the fair value of the total shareholder return metric for the performance shares awarded during and after 2017. The valuations use a lattice model and the expected volatility assumptions used were the historical volatilities for AEP and the members of their peer group. The assumptions used in the Monte Carlo valuations were as follows: Years Ended December 31, Assumptions 2021 2020 2019 Valuation Period (in years) (a) 2.88 2.87 2.87 Expected Volatility Minimum 25.87 % 13.67 % 14.83 % Expected Volatility Maximum 39.90 % 28.15 % 25.57 % Expected Volatility Average 31.01 % 16.39 % 17.39 % Dividend Rate (b) — % — % — % Risk Free Rate 0.19 % 1.40 % 2.49 % (a) Period from award date to vesting date. (b) Equivalent to reinvesting dividends. Restricted Stock Units The HR Committee grants restricted stock units (RSUs), which generally vest, subject to the participant’s continued employment, over at least three years in approximately equal annual increments. The RSUs accrue dividends as additional RSUs. The additional RSUs granted as dividends vest on the same date as the underlying RSUs. RSUs are converted into shares of AEP common stock upon vesting, except the RSUs granted prior to 2017 to AEP’s executive officers which settled in cash. Executive officers are those officers who are subject to the disclosure requirements set forth in Section 16 of the Securities Exchange Act of 1934. For RSUs that settle in shares, compensation cost is measured at fair value on the grant date and recorded over the vesting period. Fair value is determined by multiplying the number of RSUs granted by the grant date market closing price. For RSUs that settled in cash, compensation cost was recorded over the vesting period and adjusted for changes in fair value until vested. The fair value at vesting was determined by multiplying the number of RSUs vested by the 20-day average closing price of AEP common stock. The maximum contractual term of outstanding RSUs is approximately 40 months from the grant date. The HR Committee awarded RSUs, including additional units awarded as dividends, as follows: Years Ended December 31, Restricted Stock Units 2021 2020 2019 Awarded Units (in thousands) 280.0 268.7 304.8 Weighted-Average Grant Date Fair Value $ 80.39 $ 94.38 $ 81.57 The total fair value and total intrinsic value of restricted stock units vested were as follows: Years Ended December 31, Restricted Stock Units 2021 2020 2019 (in millions) Fair Value of Restricted Stock Units Vested $ 20.5 $ 22.9 $ 16.3 Intrinsic Value of Restricted Stock Units Vested (a) 22.0 25.2 21.6 (a) Intrinsic value is calculated as market price at the vesting date. A summary of the status of AEP’s nonvested RSUs as of December 31, 2021 and changes during the year ended December 31, 2021 were as follows: Nonvested Restricted Stock Units Shares/Units Weighted (in thousands) Nonvested as of January 1, 2021 448.0 $ 86.56 Awarded 280.0 80.39 Vested (250.5) 81.92 Forfeited (53.2) 85.80 Nonvested as of December 31, 2021 424.3 84.86 The total aggregate intrinsic value of nonvested RSUs as of December 31, 2021 was $38 million and the weighted-average remaining contractual life was 1.77 years. Other Stock-Based Plans AEP also has a Stock Unit Accumulation Plan for Non-Employee Directors providing each non-employee director with AEP stock units as a substantial portion of the compensation for their services as a director. The number of stock units provided is based on the closing price of AEP common stock on the last trading day of the quarter for which the stock units were earned. Amounts equivalent to cash dividends on the stock units accrue as additional AEP stock units. The stock units granted to non-employee directors are fully vested on their grant date. Stock units are settled in cash upon termination of board service or up to 10 years later if the participant so elects. Cash settlements for stock units are calculated based on the average closing price of AEP common stock for the last 20 trading days prior to the distribution date. Effective in June 2022, these stock units become payable in AEP common stock rather than cash. After five years of service on the Board of Directors, non-employee directors receive subsequent AEP stock units as contributions to an AEP stock fund awarded under the Stock Unit Accumulation Plan. Such amounts may be exchanged into other market-based investments that are similar to the investment options available to employees that participate in AEP’s Incentive Compensation Deferral Plan. These balances are also paid in cash upon termination of board service or up to 10 years later if the participant so elects. Management records compensation cost for stock units when the units are awarded and adjusts the liability for changes in value based on the current 20-day average closing price of AEP common stock on the valuation date. Cash settlements for stock unit distributions were $5 million for the year ended December 31, 2021. For the years ended December 31, 2020 and 2019, cash settlements for stock unit distributions were immaterial. The Board of Directors awarded stock units, including units awarded for dividends, as follows: Years Ended December 31, Stock Unit Accumulation Plan for Non-Employee Directors 2021 2020 2019 Awarded Units (in thousands) 12.6 12.1 10.0 Weighted-Average Grant Date Fair Value $ 84.54 $ 83.80 $ 89.13 Share-based Compensation Plans For share-based payment arrangements the compensation cost, the actual tax benefit from the tax deductions for compensation cost recognized in income and the total compensation cost capitalized were as follows: Years Ended December 31, Share-based Compensation Plans 2021 2020 2019 (in millions) Compensation Cost for Share-based Payment Arrangements (a) $ 61.1 $ 53.8 $ 57.9 Actual Tax Benefit 8.7 7.2 8.4 Total Compensation Cost Capitalized 16.9 20.4 20.0 (a) Compensation cost for share-based payment arrangements is included in Other Operation and Maintenance expenses on the statements of income. As of December 31, 2021, there was $73 million of total unrecognized compensation cost related to unvested share-based compensation arrangements granted under the 2015 LTIP. Unrecognized compensation cost related to unvested share-based arrangements will change as the fair value of performance shares is adjusted each period and as forfeitures for all award types are realized. AEP’s unrecognized compensation cost will be recognized over a weighted-average period of 1.39 years. Under the 2015 LTIP, AEP is permitted to use authorized but unissued shares, treasury shares, shares acquired in the open market specifically for distribution under these plans, or any combination thereof to fulfill share commitments. AEP’s current practice is to use authorized but unissued shares to fulfill share commitments. The number of shares used to fulfill share commitments is generally reduced to offset tax withholding obligations.

Related Party Transactions

Related Party Transactions	12 Months Ended
Related Party Transactions	Dec. 31, 2021
Related Party Transactions	RELATED PARTY TRANSACTIONS The disclosures in this note apply to all Registrant Subsidiaries unless indicated otherwise. For other related party transactions, also see “AEP System Tax Allocation Agreement” section of Note 12 in addition to “Corporate Borrowing Program – AEP System” and “Securitized Accounts Receivables – AEP Credit” sections of Note 14. Power Coordination Agreement (Applies to all Registrant Subsidiaries except AEP Texas and AEPTCo) Effective January 1, 2014, the FERC approved the PCA. Under the PCA, APCo, I&M, KPCo and WPCo are individually responsible for planning their respective capacity obligations. The PCA allows, but does not obligate, APCo, I&M, KPCo and WPCo to participate collectively under a common fixed resource requirement capacity plan in PJM and to participate in specified collective Off-system Sales and purchase activities. AEPSC conducts power, capacity, coal, natural gas, interest rate and, to a lesser extent, heating oil, gasoline and other risk management activities on behalf of APCo, I&M, KPCo, PSO, SWEPCo and WPCo. Certain power and natural gas risk management activities for APCo, I&M, KPCo and WPCo are allocated based on the four member companies’ respective equity positions, while power and natural gas risk management activities for PSO and SWEPCo are allocated based on the Operating Agreement. With the transfer of OPCo’s generation assets to AGR in 2014, AEPSC conducts only gasoline, diesel fuel, energy procurement and risk management activities on OPCo’s behalf. System Integration Agreement (Applies to APCo, I&M, PSO and SWEPCo) Under the SIA, AEPSC allocates physical and financial revenues and expenses from transactions with neighboring utilities, power marketers and other power and natural gas risk management activities based upon the location of such activity. Margins resulting from trading and marketing activities originating in PJM generally accrue to the benefit of APCo, I&M, KPCo and WPCo, while trading and marketing activities originating in SPP generally accrue to the benefit of PSO and SWEPCo. Margins resulting from other transactions are allocated among APCo, I&M, KPCo, PSO, SWEPCo and WPCo based upon the equity positions of these companies. Affiliated Revenues and Purchases The tables below represent revenues from affiliates, net of respective provisions for refund, by type of revenue for the Registrant Subsidiaries: Related Party Revenues AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Year Ended December 31, 2021 Direct Sales to East Affiliates $ — $ — $ 128.6 $ — $ — $ — $ — Transmission Revenues — 1,136.1 60.3 (2.5) (1.1) — 39.6 Other Revenues 3.9 17.8 9.0 6.3 25.9 4.2 1.4 Total Affiliated Revenues $ 3.9 $ 1,153.9 $ 197.9 $ 3.8 $ 24.8 $ 4.2 $ 41.0 Related Party Revenues AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Year Ended December 31, 2020 Direct Sales to East Affiliates $ — $ — $ 112.5 $ — $ — $ — $ — Auction Sales to OPCo (a) — — 5.3 3.1 — — — Direct Sales to AEPEP 87.5 — — — — — — Transmission Revenues — 885.0 49.1 2.9 16.6 — 37.4 Other Revenues 3.3 11.3 7.8 4.5 24.9 5.2 1.6 Total Affiliated Revenues $ 90.8 $ 896.3 $ 174.7 $ 10.5 $ 41.5 $ 5.2 $ 39.0 Related Party Revenues AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Year Ended December 31, 2019 Direct Sales to East Affiliates $ — $ — $ 128.6 $ — $ — $ — $ — Auction Sales to OPCo (a) — — 11.4 6.7 — — — Direct Sales to AEPEP 157.2 — — — — — (0.1) Transmission Revenues — 795.5 58.5 0.7 7.7 1.3 3.6 Other Revenues 3.3 11.2 6.8 3.1 19.6 4.8 1.4 Total Affiliated Revenues $ 160.5 $ 806.7 $ 205.3 $ 10.5 $ 27.3 $ 6.1 $ 4.9 (a) Refer to the Ohio Auctions section below for further information regarding these amounts. The tables below represent the purchased power expenses incurred for purchases from affiliates. AEP Texas, AEPTCo, APCo, PSO and SWEPCo did not purchase any power from affiliates for the years ended December 31, 2021, 2020 and 2019. Related Party Purchases I&M OPCo (in millions) Year Ended December 31, 2021 Auction Purchases from AEPEP (a) $ — $ 26.6 Auction Purchases from AEP Energy (a) — 25.3 Direct Purchases from AEGCo 217.9 — Total Affiliated Purchases $ 217.9 $ 51.9 Related Party Purchases I&M OPCo (in millions) Year Ended December 31, 2020 Auction Purchases from AEPEP (a) $ — $ 51.0 Auction Purchases from AEP Energy (a) — 58.7 Auction Purchases from AEPSC (a) — 10.0 Direct Purchases from AEGCo 172.8 — Total Affiliated Purchases $ 172.8 $ 119.7 Related Party Purchases I&M OPCo (in millions) Year Ended December 31, 2019 Auction Purchases from AEPEP (a) $ — $ 64.6 Auction Purchases from AEP Energy (a) — 69.9 Auction Purchases from AEPSC (a) — 21.5 Direct Purchases from AEGCo 214.9 — Total Affiliated Purchases $ 214.9 $ 156.0 (a) Refer to the Ohio Auctions section below for further information regarding this amount. The above summarized related party revenues and expenses are reported in Sales to AEP Affiliates and Purchased Electricity from AEP Affiliates, respectively, on the Registrant Subsidiaries’ statements of income. Since the Registrant Subsidiaries are included in AEP’s consolidated results, the above summarized related party transactions are eliminated in total in AEP’s consolidated revenues and expenses. PJM and SPP Transmission Service Charges (Applies to all Registrant Subsidiaries except AEP Texas) The AEP East Companies are parties to the TA, which defines how transmission costs through the PJM OATT are allocated among the AEP East Companies on a 12-month average coincident peak basis. Additional costs for transmission services provided by AEPTCo and other transmission affiliates are billed to AEP East Companies through the PJM OATT. The following table shows the net transmission service charges recorded by APCo, I&M and OPCo: Years Ended December 31, Company 2021 2020 2019 (in millions) APCo $ 302.0 $ 243.2 $ 222.3 I&M 186.7 145.9 143.5 OPCo 508.9 417.4 373.4 The charges shown above are recorded in Other Operation expenses on the statements of income. PSO, SWEPCo and AEPSC are parties to the TCA in connection with the operation of the transmission assets of PSO and SWEPCo. The TCA has been approved by the FERC and establishes a coordinating committee, which is charged with overseeing the coordinated planning of the transmission facilities of the parties to the agreement. This includes the performance of transmission planning studies, the interaction of such companies with independent system operators and other regional bodies interested in transmission planning and compliance with the terms of the OATT filed with the FERC and the rules of the FERC relating to such a tariff. Under the TCA, the parties to the agreement delegated to AEPSC the responsibility of monitoring the reliability of their transmission systems and administering the OATT on their behalf. The allocations have been governed by the FERC-approved OATT for the SPP. Additional costs for transmission services provided by AEPTCo and other transmission affiliates are billed to PSO and SWEPCo through the SPP OATT. The following table shows the net transmission service charges recorded by PSO and SWEPCo: Years Ended December 31, Company 2021 2020 2019 (in millions) PSO $ 94.7 $ 69.7 $ 46.9 SWEPCo 56.2 31.3 20.1 The charges shown above are recorded in Other Operation expenses on the statements of income. AEPTCo provides transmission services to affiliates in accordance with the OATT, TA and TCA. AEPTCo recorded affiliated transmission revenues in Sales to AEP Affiliates on the statements of income. Refer to the Affiliated Revenues and Purchases section above for amounts related to these transactions. ERCOT Transmission Service Charges (Applies to AEP and AEP Texas) Pursuant to an order from the PUCT, ETT bills AEP Texas for its ERCOT wholesale transmission services. ETT billed AEP Texas $28 million, $28 million and $27 million for transmission services for the years ended December 31, 2021, 2020 and 2019, respectively. The billings are recorded in Other Operation expenses on AEP Texas’ statements of income. Oklaunion PPA between AEP Texas and AEPEP (Applies to AEP Texas) In 2007, AEP Texas entered into a PPA with an affiliate, AEPEP, whereby AEP Texas agreed to sell AEPEP 100% of AEP Texas’ capacity and associated energy from its undivided interest (54.69%) in the Oklaunion Power Station. The PPA was approved by the FERC. In September 2018, the co-owners of Oklaunion Power Station voted to close the plant in 2020. Effective October 2018, AEP Texas increased depreciation expense to ensure the plant balances are fully depreciated as of September 2020 and recovered through the PPA billings to AEPEP. Under the early termination provisions of the PPA, AEPEP paid AEP Texas the full Property, Plant and Equipment balance through depreciation payments until termination of the PPA due to the plant closing in September 2020. See “Dispositions” section of Note 7 for additional information. AEP Texas recorded revenue of $0, $88 million and $157 million from AEPEP for the years ended December 31, 2021, 2020 and 2019, respectively. These amounts are included in Sales to AEP Affiliates on AEP Texas’ statements of income. Joint License Agreement (Applies to AEPTCo, APCo, I&M, OPCo and PSO) AEPTCo entered into a 50-year joint license agreement with APCo, I&M, KPCo, OPCo and PSO, respectively, allowing either party to occupy the granting party’s facilities or real property. In addition, AEPTCo entered into a 5-year joint license agreement with APCo and WPCo. After the expiration of these agreements, the term shall automatically renew for successive one-year terms unless either party provides notice. The joint license billing provides compensation to the granting party for the cost of carrying assets, including depreciation expense, property taxes, interest expense, return on equity and income taxes. AEPTCo recorded the following costs in Other Operation expense related to these agreements: Years Ended December 31, Billing Company 2021 2020 2019 (in millions) APCo $ 2.4 $ 0.9 $ 0.2 I&M 4.8 3.0 1.5 KPCo 0.5 0.4 0.3 OPCo 4.6 4.5 2.2 PSO 0.4 0.4 0.3 WPCo 0.2 0.2 0.1 APCo, I&M, KPCo, OPCo, PSO and WPCo recorded income related to these agreements in Sales to AEP Affiliates on the statements of income. Ohio Auctions (Applies to APCo, I&M and OPCo) In connection with OPCo’s June 2012 - May 2015 ESP, the PUCO ordered OPCo to conduct energy and capacity auctions for its entire SSO load for delivery beginning in June 2015. AEP Energy, AEPEP, APCo, KPCo, I&M and WPCo participate in the auction process and have been awarded tranches of OPCo’s SSO load. Refer to the Affiliated Revenues and Purchases section above for amounts related to these transactions. Unit Power Agreements (Applies to I&M) UPA between AEGCo and I&M A UPA between AEGCo and I&M (the I&M Power Agreement) provides for the sale by AEGCo to I&M of all the power (and the energy associated therewith) available to AEGCo at the Rockport Plant unless it is sold to another utility. Subsequently, I&M assigns 30% of the power to KPCo. See the “UPA between AEGCo and KPCo” section below. I&M is obligated, whether or not power is available from AEGCo, to pay as a demand charge for the right to receive such power (and as an energy charge for any associated energy taken by I&M) net of amounts received by AEGCo from any other sources, sufficient to enable AEGCo to pay all its operating and other expenses, including a rate of return on the common equity of AEGCo as approved by the FERC. The I&M Power Agreement will continue in effect until the debt obligations of AEGCo secured by the Rockport Plant have been satisfied and discharged (currently expected to be December 2028). UPA between AEGCo and KPCo Pursuant to an assignment between I&M and KPCo and a UPA between AEGCo and KPCo, AEGCo sells KPCo 30% of the power (and the energy associated therewith) available to AEGCo from both units of the Rockport Plant. KPCo pays to AEGCo in consideration for the right to receive such power the same amounts which I&M would have paid AEGCo under the terms of the I&M Power Agreement for such entitlement. The KPCo UPA ends in December 2022. Cook Coal Terminal (Applies to I&M, PSO and SWEPCo) Cook Coal Terminal, which is owned by AEGCo, performs coal transloading and storage services at cost for I&M. The coal transloading costs were $11 million, $12 million and $13 million for the years ended December 31, 2021, 2020 and 2019, respectively. I&M recorded the cost of transloading services in Fuel on the balance sheets. Cook Coal Terminal also performs railcar maintenance services at cost for I&M, PSO and SWEPCo. The railcar maintenance costs were as follows: Years Ended December 31, Company 2021 2020 2019 (in millions) I&M $ 0.3 $ 0.9 $ 1.3 PSO 0.4 0.7 0.8 SWEPCo 2.8 3.0 4.0 I&M, PSO and SWEPCo recorded the cost of the railcar maintenance services in Fuel on the balance sheets. I&M Barging, Urea Transloading and Other Services (Applies to APCo and I&M) I&M provides barging, urea transloading and other transportation services to affiliates. Urea is a chemical used to control NO x emissions at certain generation plants in the AEP System. I&M recorded revenues from barging, transloading and other services in Other Revenues – Affiliated on the statements of income. The affiliated companies recorded these costs paid to I&M as fuel expenses or other operation expenses. The amounts of affiliated expenses were: Years Ended December 31, Company 2021 2020 2019 (in millions) AEGCo $ 7.6 $ 10.6 $ 14.9 APCo 40.1 43.7 38.9 KPCo 3.1 3.2 4.8 WPCo 3.2 3.3 4.8 Central Machine Shop (Applies to APCo, I&M, OPCo, PSO and SWEPCo) APCo operates a facility which repairs and rebuilds specialized components for the generation plants across the AEP System. APCo defers the cost of performing these services on the balance sheet and then transfers the cost to the affiliate for reimbursement. The AEP subsidiaries recorded these billings as capital or maintenance expenses depending on the nature of the services received. These billings are recoverable from customers. The following table provides the amounts billed by APCo to the following affiliates: Years Ended December 31, Company 2021 2020 2019 (in millions) AGR $ 0.4 $ 2.9 $ 0.8 I&M 2.4 3.2 2.3 KPCo 1.0 0.9 1.4 OPCo 0.4 — — PSO 0.7 0.9 1.1 SWEPCo 2.7 0.5 1.1 Sales and Purchases of Property Certain AEP subsidiaries had affiliated sales and purchases of electric property individually amounting to $100 thousand or more, sales and purchases of meters and transformers, and sales and purchases of transmission property. There were no gains or losses recorded on the transactions. The following tables show the sales and purchases, recorded at net book value: Sales Years Ended December 31, Company 2021 2020 2019 (in millions) AEP Texas $ 0.4 $ 0.9 $ 0.9 AEPTCo 1.4 0.2 — APCo 6.2 5.7 5.5 I&M 7.0 1.5 7.5 OPCo 9.2 7.0 7.0 PSO 0.5 1.1 0.8 SWEPCo 0.4 0.8 0.2 Purchases Years Ended December 31, Company 2021 2020 2019 (in millions) AEP Texas $ 0.4 $ 1.5 $ 0.3 AEPTCo 16.7 6.0 10.2 APCo 1.0 1.3 6.0 I&M 0.6 3.4 0.9 OPCo 1.4 1.2 3.0 PSO 0.3 0.4 0.5 SWEPCo 0.3 2.8 0.7 The amounts above are recorded in Property, Plant and Equipment on the balance sheets. Sempra Renewables LLC PPAs (Applies to I&M, OPCo and SWEPCo) In April 2019, AEP acquired Sempra Renewables LLC and its ownership interests in 724 MWs of wind generation. The operating wind generation portfolio includes seven wind farms. Prior to the acquisition, two wind farms had existing PPAs with I&M, OPCo and SWEPCo. One of the joint venture wind farms has PPAs with I&M and OPCo for a portion of its energy production. The I&M portion totaled $10 million, $11 million and $9 million and the OPCo portion totaled $20 million, $23 million and $17 million respectively, for the years ended December 31, 2021, 2020 and 2019, respectively. Another joint venture wind farm has a PPA with SWEPCo for a portion of its energy production which totaled $14 million, $14 million and $10 million of purchased electricity for the years ended December 31, 2021, 2020 and 2019, respectively. See “Acquisitions” section of Note 7 for additional information. Intercompany Billings The Registrant Subsidiaries and other AEP subsidiaries perform certain utility services for each other when necessary or practical. The costs of these services are billed on a direct-charge basis, whenever possible, or on reasonable basis of proration for services that benefit multiple companies. The billings for services are made at cost and include no compensation for the use of equity capital. Charitable Contributions to AEP Foundation The American Electric Power Foundation is funded by American Electric Power and its utility operating units. The Foundation provides a permanent, ongoing resource for charitable initiatives and multi-year commitments in the communities served by AEP and initiatives outside of AEP’s 11-state service area. Charitable contributions to the AEP Foundation were recorded in Other Operation on the statements of income. In 2021 and 2020, there were no charitable contributions made to the AEP Foundation. The charitable contributions to the AEP Foundation recorded in 2019 were as follows: Year Ended Company December 31, 2019 (in millions) AEP $ 50.0 AEP Texas 6.2 AEPTCo 6.5 APCo 8.9 I&M 9.0 OPCo 5.4 PSO 3.4 SWEPCo 5.5 OKTCo Radial Assets Transfer (Applies to AEP, AEPTCo and PSO) In August 2020, AEPSC filed a request with FERC, on behalf of PSO and OKTCo, to transfer OKTCo’s interests in its radial assets to PSO. OKTCo had previously constructed radial assets in the PSO service territory and after the radial assets were placed into service, management determined the radial assets were not eligible to be included as part of OKTCo’s SPP OATT formula rates. In October 2020, FERC approved the request and in December 2020, OKTCo completed the transfer of its interest in the radial assets to PSO, through Parent, at net book value. At the transfer date, the net book value of the radial assets were $60 million, before associated tax liabilities.

Variable Interest Entities

Variable Interest Entities	12 Months Ended
Variable Interest Entities	Dec. 31, 2021
Variable Interest Entities	VARIABLE INTEREST ENTITIES AND EQUITY METHOD INVESTMENTS The disclosures in this note apply to all Registrants unless indicated otherwise. The accounting guidance for “Variable Interest Entities” is a consolidation model that considers if a company has a variable interest in a VIE. A VIE is a legal entity that possesses any of the following conditions: the entity’s equity at risk is not sufficient to permit the legal entity to finance its activities without additional subordinated financial support, equity owners are unable to direct the activities that most significantly impact the legal entity’s economic performance (or they possess disproportionate voting rights in relation to the economic interest in the legal entity), or the equity owners lack the obligation to absorb the legal entity’s expected losses or the right to receive the legal entity’s expected residual returns. Entities are required to consolidate a VIE when it is determined that they have a controlling financial interest in a VIE and therefore, are the primary beneficiary of that VIE, as defined by the accounting guidance for “Variable Interest Entities.” In determining whether AEP is the primary beneficiary of a VIE, management considers whether AEP has the power to direct the most significant activities of the VIE and is obligated to absorb losses or receive the expected residual returns that are significant to the VIE. Management believes that significant assumptions and judgments were applied consistently. AEP holds ownership interests in businesses with varying ownership structures. Partnership interests and other variable interests are evaluated to determine if each entity is a VIE, and if so, whether or not the VIE should be consolidated into AEP’s financial statements. AEP has not provided material financial or other support that was not previously contractually required to any of its consolidated VIEs. If an entity is determined not to be a VIE, or if the entity is determined to be a VIE and AEP is not deemed to be the primary beneficiary, the entity is accounted for under the equity method of accounting. Consolidated Variable Interests Entities Sabine (Applies to AEP and SWEPCo) Sabine is a mining operator providing mining services to SWEPCo. SWEPCo has no equity investment in Sabine but is Sabine’s only customer. SWEPCo guarantees the debt obligations and lease obligations of Sabine. Under the terms of the note agreements, substantially all assets are pledged and all rights under the lignite mining agreement are assigned to SWEPCo. The creditors of Sabine have no recourse to any AEP entity other than SWEPCo. Under the provisions of the mining agreement, SWEPCo is required to pay, as a part of the cost of lignite delivered, an amount equal to mining costs plus a management fee. In addition, SWEPCo determines how much coal will be mined each year. Based on these facts, management concluded that SWEPCo is the primary beneficiary and is required to consolidate Sabine. SWEPCo’s total billings from Sabine for the years ended December 31, 2021, 2020 and 2019 were $162 million, $131 million and $110 million, respectively. See the tables below for the classification of Sabine’s assets and liabilities on SWEPCo’s balance sheets. As part of the process to receive a renewal of a Texas Railroad Commission permit for lignite mining, SWEPCo provides guarantees of mine reclamation of $155 million. Since SWEPCo uses self-bonding, the guarantee commits SWEPCo to complete the reclamation, in the event, Sabine does not complete the work. This guarantee ends upon completion of reclamation. The mine end-of-life has been adjusted to March 2023, in order to align with the announced closure of the Pirkey Power Plant. Reclamation is expected to be complete by 2037 at an estimated cost of $104 million. Actual reclamation costs could vary due to inflation and scope changes to the mine reclamation. SWEPCo recovers these costs through its fuel clauses. As of December 31, 2021, SWEPCo has recorded $94 million of mine reclamation costs in Asset Retirement Obligations and has collected $85 million through a rider for reclamation costs. The remaining $10 million is recorded in Deferred Charges and Other Noncurrent Assets on SWEPCo’s balance sheets. DCC Fuel (Applies to AEP and I&M) I&M has nuclear fuel lease agreements with DCC Fuel, which was formed for the purpose of acquiring, owning and leasing nuclear fuel to I&M. DCC Fuel purchased the nuclear fuel from I&M with funds received from the issuance of notes to financial institutions. Each DCC Fuel entity is a single-lessee leasing arrangement with only one asset and is capitalized with all debt. Each is a separate legal entity from I&M, the assets of which are not available to satisfy the debts of I&M. Payments on the leases for the years ended December 31, 2021, 2020 and 2019 were $91 million, $94 million and $95 million, respectively. The leases were recorded as finance leases on I&M’s balance sheets as title to the nuclear fuel transfers to I&M at the end of the respective lease terms, which do not exceed 54 months. Based on I&M’s control of DCC Fuel, management concluded that I&M is the primary beneficiary and is required to consolidate DCC Fuel. The finance leases are eliminated upon consolidation. See the tables below for the classification of DCC Fuel’s assets and liabilities on I&M’s balance sheets. Transition Funding (Applies to AEP and AEP Texas) Transition Funding was formed for the sole purpose of issuing and servicing securitization bonds related to Texas Restructuring Legislation. Management has concluded that AEP Texas is the primary beneficiary of Transition Funding because AEP Texas has the power to direct the most significant activities of the VIE and AEP Texas’ equity interest could potentially be significant. Therefore, AEP Texas is required to consolidate Transition Funding. As of December 31, 2021 and 2020, $68 million and $66 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, and $141 million and $209 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Transition Funding has securitized transition assets of $184 million and $242 million as of December 31, 2021 and 2020, respectively, which are presented separately on the face of the balance sheets. The securitized transition assets represent the right to impose and collect Texas true-up costs from customers receiving electric transmission or distribution service from AEP Texas under-recovery mechanisms approved by the PUCT. The securitization bonds are payable only from and secured by the securitized transition assets. The bondholders have no recourse to AEP Texas or any other AEP entity. AEP Texas acts as the servicer for Transition Funding’s securitized transition assets and remits all related amounts collected from customers to Transition Funding for interest and principal payments on the securitization bonds and related costs. See the tables below for the classification of Transition Funding’s assets and liabilities on the balance sheets. Restoration Funding (Applies to AEP and AEP Texas) Restoration Funding was formed for the sole purpose of issuing and servicing securitization bonds related to storm restoration of AEP Texas’ distribution system primarily due to damage caused by Hurricane Harvey. Management has concluded that AEP Texas is the primary beneficiary of Restoration Funding because AEP Texas has the power to direct the most significant activities of the VIE and AEP Texas’ equity interest could potentially be significant. Therefore, AEP Texas is required to consolidate Restoration Funding. As of December 31, 2021 and 2020, $23 million and $23 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, and $173 million and $195 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Restoration Funding has securitized assets of $183 million and $205 million as of December 31, 2021 and 2020, respectively, which are presented separately on the face of the balance sheets. The securitized restoration assets represent the right to impose and collect Texas storm restoration costs from customers receiving electric transmission or distribution service from AEP Texas under-recovery mechanisms approved by the PUCT. The securitization bonds are payable only from and secured by the securitized assets. The bondholders have no recourse to AEP Texas or any other AEP entity. AEP Texas acts as the servicer for Restoration Funding’s securitized assets and remits all related amounts collected from customers to Restoration Funding for interest and principal payments on the securitization bonds and related costs. See the table below for the classification of Restoration Funding’s assets and liabilities on the balance sheets. Appalachian Consumer Rate Relief Funding (Applies to AEP and APCo) Appalachian Consumer Rate Relief Funding was formed for the sole purpose of issuing and servicing securitization bonds related to APCo’s under-recovered ENEC deferral balance. Management has concluded that APCo is the primary beneficiary of Appalachian Consumer Rate Relief Funding because APCo has the power to direct the most significant activities of the VIE and APCo’s equity interest could potentially be significant. Therefore, APCo is required to consolidate Appalachian Consumer Rate Relief Funding. As of December 31, 2021 and 2020, $26 million and $25 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, and $173 million and $199 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Appalachian Consumer Rate Relief Funding has securitized assets of $185 million and $210 million as of December 31, 2021 and 2020, respectively, which are presented separately on the face of the balance sheets. The phase-in recovery property represents the right to impose and collect West Virginia deferred generation charges from customers receiving electric transmission, distribution and generation service from APCo under a recovery mechanism approved by the WVPSC. In November 2013, securitization bonds were issued. The securitization bonds are payable only from and secured by the securitized assets. The bondholders have no recourse to APCo or any other AEP entity. APCo acts as the servicer for Appalachian Consumer Rate Relief Funding’s securitized assets and remits all related amounts collected from customers to Appalachian Consumer Rate Relief Funding for interest and principal payments on the securitization bonds and related costs. See the tables below for the classification of Appalachian Consumer Rate Relief Funding’s assets and liabilities on APCo’s balance sheets. AEP Credit (Applies to AEP) AEP Credit is a wholly-owned subsidiary of Parent. AEP Credit purchases, without recourse, accounts receivable from certain utility subsidiaries of AEP to reduce working capital requirements. AEP provides a minimum of 5% equity and up to 25% of AEP Credit’s short-term borrowing needs in excess of third-party financings. Any third-party financing of AEP Credit only has recourse to the receivables securitized for such financing. Based on AEP’s control of AEP Credit, management concluded that AEP is the primary beneficiary and is required to consolidate AEP Credit. See the tables below for the classification of AEP Credit’s assets and liabilities on the balance sheets. See “Securitized Accounts Receivables - AEP Credit” section of Note 14. EIS (Applies to AEP) AEP’s subsidiaries participate in one protected cell of EIS for six lines of insurance. EIS has multiple protected cells. Neither AEP nor its subsidiaries have an equity investment in EIS. The AEP System is essentially this EIS cell’s only participant, but allows certain third-parties access to this insurance. AEP’s subsidiaries and any allowed third-parties share in the insurance coverage, premiums and risk of loss from claims. Based on AEP’s control and the structure of the protected cell of EIS, management concluded that AEP is the primary beneficiary of the protected cell and is required to consolidate the protected cell of EIS. The insurance premium expense to the protected cell for the years ended December 31, 2021, 2020 and 2019 was $30 million, $31 million and $34 million, respectively. See the tables below for the classification of the protected cell’s assets and liabilities on the balance sheets. The amount reported as equity is the protected cell’s policy holders’ surplus. Transource Energy (Applies to AEP) Transource Energy was formed for the purpose of investing in utilities which develop, acquire, construct, own and operate transmission facilities in accordance with FERC-approved rates. AEP has equity and voting ownership of 86.5% with the other owner having 13.5% interest. Management has concluded that Transource Energy is a VIE and that AEP is the primary beneficiary because AEP has the power to direct the most significant activities of the entity and AEP’s equity interest could potentially be significant. Therefore, AEP is required to consolidate Transource Energy. Transource Energy’s activities consist of the development, construction and operation of FERC-regulated transmission assets in Missouri, West Virginia, Pennsylvania, Maryland and Oklahoma. Transource Energy has a credit facility agreement where borrowings are loaned through intercompany lending agreements to its subsidiaries. The creditor to the agreement has no recourse to the general credit of AEP. Transource Energy’s credit facility agreement contains certain covenants and require it to maintain a percentage of debt-to-total capitalization at a level that does not exceed 67.5%. See the tables below for the classification of Transource Energy’s assets and liabilities on the balance sheets. Apple Blossom Wind Holdings LLC and Black Oak Getty Wind Holdings LLC (Applies to AEP) In April 2019, AEP acquired an equity interest in Apple Blossom Wind Holdings LLC (Apple Blossom) and Black Oak Getty Wind Holdings LLC (Black Oak) (collectively the Project Entities) as part of the purchase of Sempra Renewables LLC. Both of the Project Entities have long-term PPAs for 100% of their energy production. The Project Entities are tax equity partnerships with nonaffiliated noncontrolling interests to which a percentage of earnings, tax attributes and cash flows are allocated in accordance with the respective limited liability company agreements. Management has concluded that the Project Entities are VIEs and that AEP is the primary beneficiary based on its power as managing member to direct the activities that most significantly impact the Project Entities’ economic performance. In addition, AEP has not provided material financial or other support to the Project Entities that was not previously contractually required. As the primary beneficiary of the Project Entities, AEP consolidates the Project Entities into its financial statements. See the table below for the classification of Project Entities’ assets and liabilities on the balance sheets. The nonaffiliated interests in the Project Entities is presented in Noncontrolling Interests on the balance sheets. As of December 31, 2021 and 2020, AEP recorded $108 million and $119 million, respectively, of Noncontrolling Interests related to the Project Entities in Equity on the balance sheets. The Project Entities’ tax equity partnerships represent substantive profit-sharing arrangements. The method for attributing income and loss to the noncontrolling interests is a balance sheet approach referred to as the hypothetical liquidation at book value (HLBV) method. Under the HLBV method, the income and loss attributable to the noncontrolling interests reflect changes in the amounts the members would hypothetically receive at each balance sheet date under the liquidation provisions of the respective limited liability company agreements, assuming the net assets of these entities were liquidated at recorded amounts, after taking into account any capital transactions, such as contributions or distributions, between the entities and the members. For the years ended December 31, 2021 and 2020, the HLBV method resulted in a loss of $7 million and $6 million, respectively, allocated to Noncontrolling Interests. Santa Rita East (Applies to AEP) In July 2019, AEP acquired a 75% interest in Santa Rita East Wind Energy Holdings, LLC and its wholly-owned subsidiary, Santa Rita East Wind Energy, LLC (collectively, Santa Rita East). In November 2020, AEP acquired an additional 10% interest in Santa Rita East resulting in AEP having a total interest of 85%. Santa Rita East is a partnership whose sole purpose is to own and operate a 302 MW wind generation facility in west Texas. Santa Rita East delivers energy and provides renewable energy credits through three long-term PPAs totaling 260 MWs. The remaining 42 MWs of energy are sold at wholesale into ERCOT. Management has concluded that Santa Rita East is a VIE and that AEP is the primary beneficiary based on its power as managing member of the partnership to direct the activities that most significantly impact Santa Rita East’s economic performance. As the primary beneficiary of Santa Rita East, AEP consolidates Santa Rita East into its financial statements. See the tables below for the classification of Santa Rita East’s assets and liabilities on the balance sheets. AEP recognized $25 million and $23 million of PTC attributable to Santa Rita East for the years ended December 31, 2021 and 2020, respectively, which was recorded in Income Tax Expense (Benefit) on the statements of income. The nonaffiliated interest in Santa Rita East is presented in Noncontrolling Interests on the balance sheets. As of December 31, 2021 and 2020, AEP recorded $59 million and $61 million, respectively, of Noncontrolling Interests related to Santa Rita East in Equity on the balance sheets. Dry Lake (Applies to AEP) In November 2020, AEP signed a Purchase and Sale Agreement with a nonaffiliate to acquire a 75% ownership interest in the entity that owns Dry Lake Solar Project (collectively, Dry Lake). Dry Lake is a partnership whose sole purpose is to own, operate and maintain a 100 MW solar generation facility in southern Nevada. In March 2021, AEP closed the transaction and the solar project was placed in-service in May 2021. Dry Lake delivers energy and provides renewable energy credits through a long-term PPA. Management has concluded that Dry Lake is a VIE and that AEP is the primary beneficiary based on its power as managing member to direct the activities that most significantly impact Dry Lake’s economic performance. As the primary beneficiary of Dry Lake, AEP consolidates Dry Lake into its financial statements. See the table below for the classification of Dry Lake assets and liabilities on the balance sheets. AEP recognized $33 million of ITC attributable to Dry Lake for the year ended December 31, 2021 which was recorded in Income Tax Expense (Benefit) on the statements of income. The nonaffiliated interest in Dry Lake is presented in Noncontrolling Interests on the balance sheets. As of December 31, 2021, AEP recognized $35 million of Noncontrolling Interest on the balance sheets. The balances below represent the assets and liabilities of the VIEs that are consolidated. These balances include intercompany transactions that are eliminated upon consolidation. American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities December 31, 2021 Registrant Subsidiaries SWEPCo I&M AEP Texas Transition Funding AEP Texas Restoration Funding APCo (in millions) ASSETS Current Assets $ 77.2 $ 65.2 $ 24.9 $ 24.3 $ 16.0 Net Property, Plant and Equipment 51.8 118.6 — — — Other Noncurrent Assets 104.1 57.2 208.3 (a) 192.6 (b) 187.8 (c) Total Assets $ 233.1 $ 241.0 $ 233.2 $ 216.9 $ 203.8 LIABILITIES AND EQUITY Current Liabilities $ 18.9 $ 65.1 $ 71.2 $ 36.1 $ 29.0 Noncurrent Liabilities 214.3 175.9 157.8 179.6 172.9 Equity (0.1) — 4.2 1.2 1.9 Total Liabilities and Equity $ 233.1 $ 241.0 $ 233.2 $ 216.9 $ 203.8 (a) Includes an intercompany item eliminated in consolidation of $24 million. (b) Includes an intercompany item eliminated in consolidation of $8 million. (c) Includes an intercompany item eliminated in consolidation of $2 million. American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities December 31, 2021 Other Consolidated VIEs AEP Credit Protected Transource Energy Apple Blossom and Black Oak Santa Rita East Dry Lake (in millions) ASSETS Current Assets $ 996.6 $ 217.3 $ 38.8 $ 9.9 $ 7.6 $ 4.0 Net Property, Plant and Equipment — — 475.4 217.3 437.6 146.1 Other Noncurrent Assets 10.4 — 3.0 11.3 — 0.3 Total Assets $ 1,007.0 $ 217.3 $ 517.2 $ 238.5 $ 445.2 $ 150.4 LIABILITIES AND EQUITY Current Liabilities $ 953.1 $ 37.5 $ 12.5 $ 6.6 $ 5.8 $ 0.9 Noncurrent Liabilities 0.9 82.3 216.9 5.2 7.0 0.6 Equity 53.0 97.5 287.8 226.7 432.4 148.9 Total Liabilities and Equity $ 1,007.0 $ 217.3 $ 517.2 $ 238.5 $ 445.2 $ 150.4 American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities December 31, 2020 Registrant Subsidiaries SWEPCo I&M AEP Texas Transition Funding AEP Texas Restoration Funding APCo (in millions) ASSETS Current Assets $ 88.0 $ 76.1 $ 61.2 $ 23.3 $ 16.8 Net Property, Plant and Equipment 97.3 138.9 — — — Other Noncurrent Assets 99.3 70.9 273.9 (a) 214.9 (b) 212.7 (c) Total Assets $ 284.6 $ 285.9 $ 335.1 $ 238.2 $ 229.5 LIABILITIES AND EQUITY Current Liabilities $ 57.7 $ 76.0 $ 69.8 $ 33.9 $ 28.7 Noncurrent Liabilities 225.3 209.9 246.5 203.1 198.9 Equity 1.6 — 18.8 1.2 1.9 Total Liabilities and Equity $ 284.6 $ 285.9 $ 335.1 $ 238.2 $ 229.5 (a) Includes an intercompany item eliminated in consolidation of $32 million. (b) Includes an intercompany item eliminated in consolidation of $9 million. (c) Includes an intercompany item eliminated in consolidation of $3 million. American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities December 31, 2020 Other Consolidated VIEs AEP Credit Protected Transource Energy Apple Blossom and Black Oak Santa Rita East (in millions) ASSETS Current Assets $ 960.4 $ 198.1 $ 22.2 $ 9.6 $ 6.0 Net Property, Plant and Equipment — — 458.7 223.1 453.1 Other Noncurrent Assets 12.9 — 3.7 12.1 — Total Assets $ 973.3 $ 198.1 $ 484.6 $ 244.8 $ 459.1 LIABILITIES AND EQUITY Current Liabilities $ 827.2 $ 43.1 $ 32.6 $ 5.3 $ 3.5 Noncurrent Liabilities 0.8 62.5 185.0 4.9 6.7 Equity 145.3 92.5 267.0 234.6 448.9 Total Liabilities and Equity $ 973.3 $ 198.1 $ 484.6 $ 244.8 $ 459.1 Non-Consolidated Significant Variable Interests DHLC (Applies to AEP and SWEPCo) DHLC is a mining operator which sells 50% of the lignite produced to SWEPCo and 50% to CLECO. The operations of DHLC are governed by the lignite mining agreement among SWEPCo, CLECO and DHLC. SWEPCo and CLECO share the executive board seats and voting rights equally. In accordance with the lignite mining agreement, each entity is responsible for 50% of DHLC’s obligations, including debt. SWEPCo and CLECO equally approve DHLC’s annual budget. The creditors of DHLC have no recourse to any AEP entity other than SWEPCo. As SWEPCo is the sole equity owner of DHLC, it receives 100% of the management fee. SWEPCo’s total billings from DHLC for the years ended December 31, 2021, 2020 and 2019 were $47 million, $142 million and $55 million, respectively. SWEPCo is not required to consolidate DHLC as it is not the primary beneficiary, although SWEPCo holds a significant variable interest in DHLC. SWEPCo’s equity investment in DHLC is included in Deferred Charges and Other Noncurrent Assets on SWEPCo’s balance sheets. SWEPCo’s investment in DHLC was: December 31, 2021 2020 As Reported on Maximum As Reported on Maximum (in millions) Capital Contribution from SWEPCo $ 7.6 $ 7.6 $ 7.6 $ 7.6 Retained Earnings 23.8 23.8 20.4 20.4 SWEPCo’s Share of Obligations — 50.3 — 98.5 Total Investment in DHLC $ 31.4 $ 81.7 $ 28.0 $ 126.5 OVEC (Applies to AEP and OPCo) AEP and several nonaffiliated utility companies jointly own OVEC. As of December 31, 2021, AEP’s ownership in OVEC was 43.47%. Parent owns 39.17% and OPCo owns 4.3%. APCo, I&M and OPCo are members to an intercompany power agreement. The Registrants’ power participation ratios are 15.69% for APCo, 7.85% for I&M and 19.93% for OPCo. Participants of this agreement are entitled to receive and are obligated to pay for all OVEC generating capacity, approximately 2,400 MWs, in proportion to their respective power participation ratios. The proceeds from the sale of power by OVEC are designed to be sufficient for OVEC to meet its operating expenses and fixed costs, including outstanding indebtedness, and provide a return on capital. The intercompany power agreement ends in June 2040. AEP and other nonaffiliated owners authorized environmental investments related to their ownership interests. OVEC financed capital expenditures in connection with the engineering and construction of FGD projects and the associated waste disposal landfills at its two generation plants. These environmental projects were funded through debt issuances. As of December 31, 2021 and 2020, OVEC’s outstanding indebtedness was approximately $1.1 billion and $1.3 billion, respectively. Although they are not an obligor or guarantor, the Registrants’ are responsible for their respective ratio of OVEC’s outstanding debt through the intercompany power agreement. Principal and interest payments related to OVEC’s outstanding indebtedness are disclosed in accordance with the accounting guidance for “Commitments.” See the “Commitments” section of Note 6 for additional information. AEP is not required to consolidate OVEC as it is not the primary beneficiary, although AEP and its subsidiary holds a significant variable interest in OVEC. Power to control decision making that significantly impacts the economic performance of OVEC is shared amongst the owners through their representation on the Board of Directors of OVEC and the representation of the sponsoring companies on the Operating Committee under the intercompany power agreement. AEP’s investment in OVEC was: December 31, 2021 2020 As Reported on Maximum As Reported on Maximum Exposure (in millions) Capital Contribution from AEP $ 4.4 $ 4.4 $ 4.4 $ 4.4 AEP’s Ratio of OVEC Debt (a) — 492.0 — 555.0 Total Investment in OVEC $ 4.4 $ 496.4 $ 4.4 $ 559.4 (a) Based on the Registrants’ power participation ratios APCo, I&M and OPCo’s share of OVEC debt was $177 million, $89 million and $226 million as of December 31, 2021 and $200 million, $100 million and $255 million as of December 31, 2020, respectively. Power purchased by the Registrant Subsidiaries from OVEC is included in Purchased Electricity for Resale on the statements of income and is shown in the table below: Years Ended December 31, Company 2021 2020 2019 (in millions) APCo $ 104.3 $ 94.4 $ 104.5 I&M 52.2 47.2 52.3 OPCo 133.0 120.8 132.7 AEPSC (Applies to AEP) AEPSC provides certain managerial and professional services to AEP’s subsidiaries. Parent is the sole equity owner of AEPSC. AEP management controls the activities of AEPSC. The costs of the services are based on a direct-charge or on a prorated basis and billed to the AEP subsidiary companies at AEPSC’s cost. AEP subsidiaries have not provided financial or other support outside of the reimbursement of costs for services rendered. AEPSC finances its operations through cost reimbursement from other AEP subsidiaries. There are no other terms or arrangements between AEPSC and any of the AEP subsidiaries that could require additional financial support from an AEP subsidiary or expose them to losses outside of the normal course of business. AEPSC and its billings are subject to regulation by the FERC. AEP subsidiaries are exposed to losses to the extent they cannot recover the costs of AEPSC through their normal business operations. AEP subsidiaries are considered to have a significant interest in AEPSC due to their activity in AEPSC’s cost reimbursement structure. However, AEP subsidiaries do not have control over AEPSC. AEPSC is consolidated by AEP. In the event AEPSC would require financing or other support outside the cost reimbursement billings, this financing would be provided by AEP. Total AEPSC billings to the Registrant Subsidiaries were as follows: Years Ended December 31, Company 2021 2020 2019 (in millions) AEP Texas $ 206.9 $ 199.4 $ 206.6 AEPTCo 267.1 270.3 242.3 APCo 313.3 294.9 308.3 I&M 200.9 210.2 184.8 OPCo 234.9 232.8 230.4 PSO 123.7 113.2 125.7 SWEPCo 168.6 161.8 169.5 The carrying amount and classification of variable interest in AEPSC’s accounts payable were as follows: December 31, 2021 2020 Company As Reported on Maximum As Reported on Maximum (in millions) AEP Texas $ 22.2 $ 22.2 $ 30.5 $ 30.5 AEPTCo 23.3 23.3 45.9 45.9 APCo 44.1 44.1 42.8 42.8 I&M 21.8 21.8 27.1 27.1 OPCo 25.5 25.5 33.9 33.9 PSO 13.7 13.7 15.7 15.7 SWEPCo 20.5 20.5 22.0 22.0 AEGCo (Applies to AEP) AEGCo, a wholly-owned subsidiary of Parent, is consolidated by AEP. AEGCo owns a 50% ownership interest in Rockport Plant, Unit 1 and leases a 50% interest in Rockport Plant, Unit 2. AEGCo sells all the output from the Rockport Plant to I&M and KPCo. AEP has agreed to provide AEGCo with the funds necessary to satisfy all of the debt obligations of AEGCo. I&M is considered to have a significant interest in AEGCo due to these transactions. I&M is exposed to losses to the extent it cannot recover the costs of AEGCo through its normal business operations. In the event AEGCo would require financing or other support outside the billings to I&M and KPCo, this financing would be provided by AEP. Total billings to I&M from AEGCo for the years ended December 31, 2021, 2020 and 2019 were $218 million, $173 million and $215 million, respectively. The carrying amounts of I&M’s liabilities associated with AEGCo as of December 31, 2021 and 2020 were $18 million and $9 million, respectively. Management estimates the maximum exposure of loss to be equal to the amount of such liability. See “Rockport Lease” section of Note 13 for additional information. Significant Equity Method Investments in Unconsolidated Entities (Applies to AEP) For a discussion of the equity method of accounting, see the “Equity Investment in Unconsolidated Entities” section of Note 1. Sempra Renewables LLC In April 2019, AEP acquired a 50% interest in five wind farms in multiple states as part of the purchase of Sempra Renewables LLC. The wind farms are joint ventures with BP Wind Energy who holds the other 50% interest. All five wind farms have long-term PPAs for 100% of their energy production. One of the jointly-owned wind farms has PPAs with I&M and OPCo for a portion of its energy production. Another jointly-owned wind farm has a PPA with SWEPCo for a portion of its energy production. The joint venture wind farms are not considered VIEs and AEP is not required to consolidate them as AEP does not have a controlling financial interest. However, AEP is able to exercise significant influence over the wind farms and therefore applies the equity method of accounting. As of December 31, 2021 and 2020, AEP’s carrying value of the investment in the five joint venture wind farms was $399 million and $376 million, respectively. The difference between AEP’s carrying value and the amount of underlying equity in net assets is immaterial. The investment includes amounts recognized in AOCI related to interest rate cash flow hedges. AEP’s equity earnings associated with the five joint venture wind farms was a loss of $12 million and earnings of $2 million for the years ended December 31, 2021 and 2020, respectively. AEP recognized $33 million and $36 million of PTC attributable to the joint venture wind farms for the years ended December 31, 2021 and 2020, respectively, which was recorded in Income Tax Expense (Benefit) on the statements of income. ETT

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
Property, Plant and Equipment	Dec. 31, 2021
Property, Plant and Equipment	PROPERTY, PLANT AND EQUIPMENT The disclosures in this note apply to all Registrants unless indicated otherwise. Property, Plant and Equipment is shown functionally on the face of the balance sheets. The following tables include the total plant balances as of December 31, 2021 and 2020: December 31, 2021 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Regulated Property, Plant and Equipment Generation $ 21,196.8 (a) $ — $ — $ 6,683.9 $ 5,531.8 $ — $ 1,802.4 $ 4,734.5 (a) Transmission 29,866.0 5,849.9 10,886.3 4,322.4 1,783.1 2,992.8 1,107.7 2,316.9 Distribution 24,440.0 4,917.2 — 4,683.3 2,800.1 6,070.6 3,004.9 2,514.3 Other 5,249.8 958.7 427.2 668.9 755.1 982.2 433.5 542.0 CWIP 3,632.4 (a) 551.3 1,394.8 469.9 302.8 365.0 156.0 240.7 (a) Less: Accumulated Depreciation 20,375.5 1,642.9 772.9 5,047.4 3,885.3 2,457.4 1,707.0 3,002.2 Total Regulated Property, Plant and Equipment - Net 64,009.5 10,634.2 11,935.4 11,781.0 7,287.6 7,953.2 4,797.5 7,346.2 Nonregulated Property, Plant and Equipment - Net 1,991.8 1.2 0.3 23.3 23.3 9.8 5.3 53.9 Total Property, Plant and Equipment - Net $ 66,001.3 (b) $ 10,635.4 $ 11,935.7 (b) $ 11,804.3 $ 7,310.9 $ 7,963.0 $ 4,802.8 $ 7,400.1 December 31, 2020 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Regulated Property, Plant and Equipment Generation $ 21,587.8 (a) $ — $ — $ 6,633.7 $ 5,264.7 $ — $ 1,480.7 $ 4,681.4 (a) Transmission 27,841.5 5,279.6 9,593.5 3,900.5 1,696.4 2,831.9 1,069.9 2,165.7 Distribution 23,972.1 4,580.8 — 4,464.3 2,594.6 5,708.3 2,853.0 2,382.5 Other 4,852.4 866.0 328.8 598.0 644.6 888.5 388.1 564.5 CWIP 3,815.0 (a) 614.1 1,422.6 484.6 362.4 362.3 128.7 228.3 (a) Less: Accumulated Depreciation 20,094.2 1,528.1 572.8 4,711.0 3,538.6 2,348.8 1,607.3 3,032.0 Total Regulated Property, Plant and Equipment - Net 61,974.6 9,812.4 10,772.1 11,370.1 7,024.1 7,442.2 4,313.1 6,990.4 Nonregulated Property, Plant and Equipment - Net 1,927.0 1.2 0.7 24.0 28.2 9.9 6.9 97.8 Total Property, Plant and Equipment - Net $ 63,901.6 $ 9,813.6 $ 10,772.8 $ 11,394.1 $ 7,052.3 $ 7,452.1 $ 4,320.0 $ 7,088.2 (a) AEP and SWEPCo’s regulated generation and regulated CWIP include amounts related to SWEPCo’s Arkansas jurisdictional share of the Turk Plant. (b) Amount excludes $2.3 billion and $165 million for AEP and AEPTCo, respectively, of Property, Plant and Equipment - Net classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. Depreciation, Depletion and Amortization The Registrants provide for depreciation of Property, Plant and Equipment, excluding coal-mining properties, on a straight-line basis over the estimated useful lives of property, generally using composite rates by functional class. The following tables provide total regulated annual composite depreciation rates and depreciable lives for the Registrants: AEP 2021 2020 2019 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 2.7% - 7.8% 20 - 132 2.7% - 6.3% 20 - 132 2.5% - 5.5% 20 - 132 Transmission 2.0% - 2.6% 15 - 75 2.0% - 2.6% 15 - 75 1.8% - 2.6% 15 - 81 Distribution 2.8% - 3.6% 7 - 80 2.7% - 3.7% 7 - 78 2.7% - 3.7% 7 - 78 Other 3.0% - 12.5% 5 - 75 2.8% - 11.3% 5 - 75 2.6% - 9.5% 5 - 75 AEP Texas 2021 2020 2019 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Transmission 2.2% 50 - 75 2.0% 50 - 75 1.8% 45 - 81 Distribution 2.9% 7 - 70 3.1% 7 - 70 3.5% 7 - 70 Other 5.8% 5 - 50 6.1% 5 - 50 6.3% 5 - 50 AEPTCo 2021 2020 2019 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Transmission 2.5% 24 - 75 2.4% 24 - 75 2.0% 24 - 75 Other 6.7% 5 - 56 6.3% 5 - 64 5.8% 5 - 64 APCo 2021 2020 2019 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 3.6% 35 - 118 3.3% 35 - 118 3.2% 35 - 118 Transmission 2.1% 15 - 75 2.2% 15 - 75 1.8% 15 - 71 Distribution 3.5% 12 - 57 3.7% 12 - 57 3.7% 12 - 57 Other 8.5% 5 - 55 7.8% 5 - 55 7.2% 5 - 55 I&M 2021 2020 2019 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 4.7% 20 - 132 4.6% 20 - 132 4.0% 20 - 132 Transmission 2.4% 45 - 70 2.3% 45 - 70 1.9% 50 - 73 Distribution 3.4% 14 - 71 3.4% 14 - 71 3.4% 9 - 75 Other 9.0% 5 - 51 10.2% 5 - 51 9.4% 5 - 50 OPCo 2021 2020 2019 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Transmission 2.3% 39 - 60 2.3% 39 - 60 2.3% 39 - 60 Distribution 2.9% 11 - 70 3.1% 14 - 65 3.1% 14 - 65 Other 6.1% 5 - 50 5.0% 5 - 50 4.9% 5 - 50 PSO 2021 2020 2019 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 2.8% 30 - 75 3.1% 35 - 75 2.9% 35 - 75 Transmission 2.4% 42 - 75 2.2% 45 - 75 2.4% 45 - 75 Distribution 2.9% 15 - 78 2.9% 15 - 78 2.9% 15 - 78 Other 6.1% 5 - 56 5.7% 5 - 64 5.6% 5 - 64 SWEPCo 2021 2020 2019 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 2.7% 30 - 65 2.7% 35 - 65 2.5% 40 - 70 Transmission 2.4% 49 - 74 2.3% 47 - 73 2.4% 50 - 73 Distribution 2.8% 15 - 80 2.7% 15 - 67 2.7% 25 - 70 Other 8.6% 5 - 58 8.5% 5 - 52 7.6% 5 - 55 The following table includes the nonregulated annual composite depreciation rate ranges and nonregulated depreciable life ranges for AEP. Depreciation rate ranges and depreciable life ranges are not meaningful for nonregulated property of AEP Texas, AEPTCo, APCo, I&M, OPCo, PSO and SWEPCo for 2021, 2020 and 2019. 2021 2020 2019 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 3.8% - 10.4% 10 - 59 3.6% - 4.0% 15 - 59 3.2% - 21.2% 15 - 59 Transmission 2.6% 30 - 40 2.5% 30 - 40 2.5% 30 - 40 Distribution NA NA NA NA 2.3% 40 Other 16.5% 5 - 35 (a) 16.1% 5 - 50 17.6% 5 - 50 (a) In 2020 management announced plans to retire the Pirkey Plant in 2023 and the related depreciable lives have been adjusted accordingly. See Note 5 - Effects of Regulation for additional information. NA Not applicable. SWEPCo provides for depreciation, depletion and amortization of coal-mining assets over each asset’s estimated useful life or the estimated life of each mine, whichever is shorter, using the straight-line method for mining structures and equipment. SWEPCo uses either the straight-line method or the units-of-production method to amortize mine development costs and deplete coal rights based on estimated recoverable tonnages. SWEPCo includes these costs in fuel expense. For regulated operations, the composite depreciation rate generally includes a component for non-ARO removal costs, which is credited to Accumulated Depreciation and Amortization on the balance sheets. Actual removal costs incurred are charged to Accumulated Depreciation and Amortization. Any excess of accrued non-ARO removal costs over actual removal costs incurred is reclassified from Accumulated Depreciation and Amortization and reflected as a regulatory liability. For nonregulated operations, non-ARO removal costs are expensed as incurred. Asset Retirement Obligations (Applies to all Registrants except AEPTCo) The Registrants record ARO in accordance with the accounting guidance for “Asset Retirement and Environmental Obligations” for legal obligations for asbestos removal and for the retirement of certain ash disposal facilities, wind farms, solar farms and certain coal-mining facilities. I&M records ARO for the decommissioning of the Cook Plant. The Registrants have identified, but not recognized, ARO liabilities related to electric transmission and distribution assets as a result of certain easements on property on which assets are owned. Generally, such easements are perpetual and require only the retirement and removal of assets upon the cessation of the property’s use. The retirement obligation is not estimable for such easements since the Registrants plan to use their facilities indefinitely. The retirement obligation would only be recognized if and when the Registrants abandon or cease the use of specific easements, which is not expected. The Registrants recorded the following revisions to ARO estimates as of December 31, 2021 and 2020: • As of December 31, 2021 and 2020, I&M’s ARO liability for nuclear decommissioning of the Cook Plant was $1.93 billion and $1.80 billion, respectively. These liabilities are reflected in Asset Retirement Obligations on I&M’s balance sheets. As of December 31, 2021 and 2020, the fair value of I&M’s assets that are legally restricted for purposes of settling decommissioning liabilities totaled $3.54 billion and $2.98 billion, respectively. These assets are included in Spent Nuclear Fuel and Decommissioning Trusts on I&M’s balance sheets. In December 2021, I&M recorded a $58 million revision for Cook Plant as a result of the latest decommissioning cost study. The ARO liability was updated and changes from the previous study were driven primarily by general increases in the projected cost of labor and materials. • In 2020, Virginia’s Governor signed House Bill 443 (HB 443) requiring APCo to close certain ash disposal units at the retired Glen Lyn Station by removal of all coal combustion material. In June 2020, APCo recorded a revision to increase estimated Glen Lyn Station ash disposal ARO liabilities by $199 million due to the enactment of HB 443. In June 2021, management completed fully designed and costed project plans for the Glen Lyn Station site and increased ash disposal ARO liabilities by an additional $79 million. HB 443 provides for the recovery of all costs associated with closure by removal through the Virginia environmental rate adjustment clause. APCo is permitted to record carrying costs on the unrecovered balance of closure costs as a weighted-average cost of capital approved by the Virginia SCC. The legislation provides for regulatory recovery of these costs. • In 2020, SWEPCo recorded a revision to increase estimated ARO liabilities by $21 million primarily due to the revision in the useful life of DHLC. See Note 5 - Effects of Regulation for additional information. In September 2020, SWEPCo recorded an $18 million revision due to a reduction in estimated ash pond closure costs. • In 2020, AEP Texas and PSO recorded a revision to decrease estimated ARO liabilities by $17 million and $5 million, respectively, due to the retirement of the Oklaunion Power Station in September 2020. See “Oklaunion Power Station” section of Note 7 for additional information. • In 2020, AGR derecognized $106 million of Conesville Plant related ARO liabilities as a result of the Environmental Liability and Property Transfer and Asset Purchase Agreement executed with a non-affiliated third-party. See “Conesville Plant” section of Note 7 for additional information. The following is a reconciliation of the 2021 and 2020 aggregate carrying amounts of ARO by Registrant: Company ARO as of December 31, 2020 Accretion Liabilities Liabilities Revisions in ARO as of December 31, 2021 (in millions) AEP (b)(c)(d)(e)(f) $ 2,516.7 $ 105.0 $ 22.8 $ (41.4) $ 138.6 $ 2,741.7 AEP Texas (b)(e) 4.6 0.2 — (0.4) — 4.4 APCo (b)(e) 313.1 13.7 — (6.9) 84.7 404.6 I&M (b)(c)(e) 1,813.8 72.9 0.3 (0.1) 59.4 1,946.3 OPCo (e) 1.9 0.1 — (0.1) — 1.9 PSO (b)(e) 47.4 3.3 7.6 (0.7) — 57.6 SWEPCo (b)(d)(e) 222.1 9.8 9.2 (20.9) 2.5 222.7 Company ARO as of December 31, 2019 Accretion Liabilities Liabilities Revisions in ARO as of December 31, 2020 (in millions) AEP (b)(c)(d)(e) $ 2,418.9 $ 102.4 $ 0.3 $ (188.0) $ 183.1 $ 2,516.7 AEP Texas (b)(e) 29.1 0.8 — (8.5) (16.8) 4.6 APCo (b)(e) 111.1 8.9 — (7.8) 200.9 313.1 I&M (b)(c)(e) 1,748.6 70.2 0.1 (0.2) (4.9) 1,813.8 OPCo (e) 1.8 0.1 — — — 1.9 PSO (b)(e) 52.2 3.1 — (3.1) (4.8) 47.4 SWEPCo (b)(d)(e) 212.2 10.7 — (10.9) 10.1 222.1 (a) Unless discussed above, primarily related to ash ponds, landfills and mine reclamation, generally due to changes in estimated closure area, volumes and/or unit costs. (b) Includes ARO related to ash disposal facilities. (c) Includes ARO related to nuclear decommissioning costs for the Cook Plant of $1.93 billion and $1.80 billion as of December 31, 2021 and 2020, respectively. (d) Includes ARO related to Sabine and DHLC. (e) Includes ARO related to asbestos removal. (f) Includes $18 million of ARO classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. Allowance for Funds Used During Construction and Interest Capitalization The Registrants’ amounts of Allowance for Equity Funds Used During Construction are summarized in the following table: Years Ended December 31, Company 2021 2020 2019 (in millions) AEP $ 139.7 $ 148.1 $ 168.4 AEP Texas 21.5 19.4 15.2 AEPTCo 67.2 74.0 84.3 APCo 15.6 14.6 16.6 I&M 12.8 11.5 19.4 OPCo 10.8 12.5 18.2 PSO 2.4 4.0 2.7 SWEPCo 7.0 7.7 6.8 The Registrants’ amounts of allowance for borrowed funds used during construction, including capitalized interest, are summarized in the following table: Years Ended December 31, Company 2021 2020 2019 (in millions) AEP $ 53.8 $ 66.0 $ 88.7 AEP Texas 10.5 12.5 20.0 AEPTCo 21.0 25.5 32.2 APCo 7.5 7.9 9.3 I&M 5.1 5.7 8.9 OPCo 4.7 6.2 6.7 PSO 0.7 2.0 1.9 SWEPCo 3.0 3.9 4.0 Jointly-owned Electric Facilities (Applies to AEP, I&M, PSO and SWEPCo) The Registrants have electric facilities that are jointly-owned with affiliated and nonaffiliated companies. Using its own financing, each participating company is obligated to pay its share of the costs of these jointly-owned facilities in the same proportion as its ownership interest. Each Registrant’s proportionate share of the operating costs associated with these facilities is included in its statements of income and the investments and accumulated depreciation are reflected in its balance sheets under Property, Plant and Equipment as follows: Registrant’s Share as of December 31, 2021 Fuel Percent of Utility Plant Construction Accumulated (in millions) AEP Dolet Hills Power Station, Unit 1 (a) Lignite 40.2 % $ — $ — $ — Flint Creek Generating Station, Unit 1 (b) Coal 50.0 % 377.6 6.3 133.5 Pirkey Power Plant, Unit 1 (b) Lignite 85.9 % 613.8 — 528.3 Turk Generating Plant (b) Coal 73.3 % 1,598.0 10.2 285.6 Total $ 2,589.4 $ 16.5 $ 947.4 I&M Rockport Generating Plant (c)(d)(e) Coal 50.0 % $ 1,247.2 $ 13.9 $ 794.5 PSO North Central Wind Energy Facilities (f)(g) Wind 45.5 % $ 313.7 $ — $ 4.2 SWEPCo Dolet Hills Power Station, Unit 1 (a) Lignite 40.2 % $ — $ — $ — Flint Creek Generating Station, Unit 1 (b) Coal 50.0 % 377.6 6.3 133.5 Pirkey Power Plant, Unit 1 (b) Lignite 85.9 % 613.8 — 528.3 Turk Generating Plant (b) Coal 73.3 % 1,598.0 10.2 285.6 North Central Wind Energy Facilities (f)(g) Wind 54.5 % 376.2 — 5.4 Total $ 2,965.6 $ 16.5 $ 952.8 Registrant’s Share as of December 31, 2020 Fuel Percent of Utility Plant Construction Accumulated (in millions) AEP Dolet Hills Power Station, Unit 1 (a) Lignite 40.2 % $ 342.4 $ 4.6 $ 295.4 Flint Creek Generating Station, Unit 1 (b) Coal 50.0 % 377.2 3.0 116.0 Pirkey Power Plant, Unit 1 (b) Lignite 85.9 % 602.8 3.7 441.0 Turk Generating Plant (b) Coal 73.3 % 1,594.3 2.8 257.3 Total $ 2,916.7 $ 14.1 $ 1,109.7 I&M Rockport Generating Plant (c)(d)(e) Coal 50.0 % $ 1,228.5 $ 19.6 $ 677.3 SWEPCo Dolet Hills Power Station, Unit 1 (a) Lignite 40.2 % $ 342.4 $ 4.6 $ 295.4 Flint Creek Generating Station, Unit 1 (b) Coal 50.0 % 377.2 3.0 116.0 Pirkey Power Plant, Unit 1 (b) Lignite 85.9 % 602.8 3.7 441.0 Turk Generating Plant (b) Coal 73.3 % 1,594.3 2.8 257.3 Total $ 2,916.7 $ 14.1 $ 1,109.7 (a) Operated by CLECO, a nonaffiliated company. The Dolet Hills Power Station was retired in December 2021. (b) Operated by SWEPCo. (c) Operated by I&M. (d) Amounts include I&M’s 50% ownership of both Unit 1 and capital additions for Unit 2. Unit 2 is subject to a finance lease with a nonaffiliated company. See the “Rockport Lease” section of Note 13 for additional information. (e) AEGCo owns 50% of Unit 1 with I&M and 50% of capital additions for Unit 2. (f) PSO and SWEPCo own undivided interests of 45.5% and 54.5% of the NCWF, respectively. Sundance was placed into service in April 2021. Maverick was placed into service in September 2021. See the “Acquisitions” section of Note 7 for additional information. (g) Operated by PSO.

Revenue from Contracts with Cus

Revenue from Contracts with Customers	12 Months Ended
Revenue from Contracts with Customers	Dec. 31, 2021
Revenue from Contracts with Customers	REVENUE FROM CONTRACTS WITH CUSTOMERS The disclosures in this note apply to all Registrants, unless indicated otherwise. Disaggregated Revenues from Contracts with Customers The table below represents AEP’s reportable segment revenues from contracts with customers, net of respective provisions for refund, by type of revenue: Year Ended December 31, 2021 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation & Marketing Corporate and Other Reconciling Adjustments AEP Consolidated (in millions) Retail Revenues: Residential Revenues $ 3,952.6 $ 2,138.2 $ — $ — $ — $ — $ 6,090.8 Commercial Revenues 2,208.5 1,081.2 — — — — 3,289.7 Industrial Revenues 2,168.2 395.2 — — — (0.8) 2,562.6 Other Retail Revenues 170.6 43.9 — — — — 214.5 Total Retail Revenues 8,499.9 3,658.5 — — — (0.8) 12,157.6 Wholesale and Competitive Retail Revenues: Generation Revenues 942.6 — — 137.9 — — 1,080.5 Transmission Revenues (a) 355.5 572.4 1,456.4 — — (1,206.0) 1,178.3 Renewable Generation Revenues (b) — — — 86.9 — (3.6) 83.3 Retail, Trading and Marketing Revenues (c) — — — 1,722.6 1.4 (51.6) 1,672.4 Total Wholesale and Competitive Retail Revenues 1,298.1 572.4 1,456.4 1,947.4 1.4 (1,261.2) 4,014.5 Other Revenues from Contracts with Customers (b) 187.5 194.2 17.1 7.2 60.1 (115.2) 350.9 Total Revenues from Contracts with Customers 9,985.5 4,425.1 1,473.5 1,954.6 61.5 (1,377.2) 16,523.0 Other Revenues: Alternative Revenues (b) 13.5 48.8 52.7 — — (73.6) 41.4 Other Revenues (b) (d) (0.5) 19.0 — 209.1 10.7 (10.7) 227.6 Total Other Revenues 13.0 67.8 52.7 209.1 10.7 (84.3) 269.0 Total Revenues $ 9,998.5 $ 4,492.9 $ 1,526.2 $ 2,163.7 $ 72.2 $ (1,461.5) $ 16,792.0 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $1.1 billion. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $52 million. The remaining affiliated amounts were immaterial. (d) Generation & Marketing includes economic hedge activity. Year Ended December 31, 2020 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation & Marketing Corporate and Other Reconciling Adjustments AEP Consolidated (in millions) Retail Revenues: Residential Revenues $ 3,606.8 $ 2,086.9 $ — $ — $ — $ — $ 5,693.7 Commercial Revenues 2,016.2 1,048.6 — — — — 3,064.8 Industrial Revenues 2,018.0 390.1 — — — (0.7) 2,407.4 Other Retail Revenues 155.6 42.5 — — — — 198.1 Total Retail Revenues 7,796.6 3,568.1 — — — (0.7) 11,364.0 Wholesale and Competitive Retail Revenues: Generation Revenues 588.3 — — 131.9 — — 720.2 Transmission Revenues (a) 334.5 467.0 1,257.0 — — (1,006.7) 1,051.8 Renewable Generation Revenues (b) — — — 60.9 — (1.6) 59.3 Retail, Trading and Marketing Revenues (c) — — — 1,486.9 (5.5) (103.0) 1,378.4 Total Wholesale and Competitive Retail Revenues 922.8 467.0 1,257.0 1,679.7 (5.5) (1,111.3) 3,209.7 Other Revenues from Contracts with Customers (b) 163.2 157.8 22.4 2.3 92.5 (148.6) 289.6 Total Revenues from Contracts with Customers 8,882.6 4,192.9 1,279.4 1,682.0 87.0 (1,260.6) 14,863.3 Other Revenues: Alternative Revenues (b) (3.2) 70.0 (80.6) — — 7.5 (6.3) Other Revenues (b) (d) — 83.0 — 43.6 9.8 (74.9) 61.5 Total Other Revenues (3.2) 153.0 (80.6) 43.6 9.8 (67.4) 55.2 Total Revenues $ 8,879.4 $ 4,345.9 $ 1,198.8 $ 1,725.6 $ 96.8 $ (1,328.0) $ 14,918.5 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $965 million. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $103 million. The remaining affiliated amounts were immaterial. (d) Generation & Marketing includes economic hedge activity. Year Ended December 31, 2019 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation & Marketing Corporate and Other Reconciling Adjustments AEP Consolidated (in millions) Retail Revenues: Residential Revenues $ 3,643.7 $ 2,069.9 $ — $ — $ — $ — $ 5,713.6 Commercial Revenues 2,155.3 1,152.9 — — — — 3,308.2 Industrial Revenues 2,179.0 429.1 — — — (0.9) 2,607.2 Other Retail Revenues 179.1 43.8 — — — — 222.9 Total Retail Revenues 8,157.1 3,695.7 — — — (0.9) 11,851.9 Wholesale and Competitive Retail Revenues: Generation Revenues 807.6 — — 254.8 — — 1,062.4 Transmission Revenues (a) 292.1 435.1 1,077.2 — — (825.0) 979.4 Renewable Generation Revenues (b) — — — 57.3 — — 57.3 Retail, Trading and Marketing Revenues (c) — — — 1,480.7 — (135.6) 1,345.1 Total Wholesale and Competitive Retail Revenues 1,099.7 435.1 1,077.2 1,792.8 — (960.6) 3,444.2 Other Revenues from Contracts with Customers (b) 168.2 169.4 16.6 4.9 104.7 (147.1) 316.7 Total Revenues from Contracts with Customers 9,425.0 4,300.2 1,093.8 1,797.7 104.7 (1,108.6) 15,612.8 Other Revenues: Alternative Revenues (b) (57.9) 32.3 (20.6) — — (66.9) (113.1) Other Revenues (b) (d) — 150.0 — 59.9 (8.9) (139.3) 61.7 Total Other Revenues (57.9) 182.3 (20.6) 59.9 (8.9) (206.2) (51.4) Total Revenues $ 9,367.1 $ 4,482.5 $ 1,073.2 $ 1,857.6 $ 95.8 $ (1,314.8) $ 15,561.4 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $794 million. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $136 million. The remaining affiliated amounts were immaterial. (d) Generation & Marketing includes economic hedge activity. The table below represents revenues from contracts with customers, net of respective provisions for refund, by type of revenue for the Registrant Subsidiaries: Year Ended December 31, 2021 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 550.3 $ — $ 1,379.6 $ 805.4 $ 1,587.9 $ 651.9 $ 709.5 Commercial Revenues 358.5 — 556.3 507.2 722.7 378.9 529.3 Industrial Revenues 108.9 — 584.3 557.0 286.3 274.1 344.4 Other Retail Revenues 31.3 — 70.8 5.2 12.6 77.7 10.0 Total Retail Revenues 1,049.0 — 2,591.0 1,874.8 2,609.5 1,382.6 1,593.2 Wholesale Revenues: Generation Revenues (a) — — 302.7 318.1 — 22.9 386.6 Transmission Revenues (b) 497.5 1,393.9 128.8 33.7 74.9 37.5 122.7 Total Wholesale Revenues 497.5 1,393.9 431.5 351.8 74.9 60.4 509.3 Other Revenues from Contracts with Customers (c) 41.2 17.0 70.4 104.1 153.1 31.3 23.5 Total Revenues from Contracts with Customers 1,587.7 1,410.9 3,092.9 2,330.7 2,837.5 1,474.3 2,126.0 Other Revenues: Alternative Revenues (d) 6.1 58.4 12.3 (4.0) 42.6 0.1 5.8 Other Revenues (d) — — — — 19.0 — — Total Other Revenues 6.1 58.4 12.3 (4.0) 61.6 0.1 5.8 Total Revenues $ 1,593.8 $ 1,469.3 $ 3,105.2 $ 2,326.7 $ 2,899.1 $ 1,474.4 $ 2,131.8 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $129 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $1.1 billion. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $60 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. Year Ended December 31, 2020 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 563.6 $ — $ 1,250.6 $ 794.1 $ 1,523.4 $ 579.4 $ 630.8 Commercial Revenues 366.7 — 517.0 499.3 682.0 320.1 466.7 Industrial Revenues 120.1 — 553.5 547.4 270.0 221.1 328.8 Other Retail Revenues 29.5 — 67.6 6.6 13.1 66.0 9.1 Total Retail Revenues 1,079.9 — 2,388.7 1,847.4 2,488.5 1,186.6 1,435.4 Wholesale Revenues: Generation Revenues (a) — — 230.2 274.6 — 15.1 162.0 Transmission Revenues (b) 399.9 1,210.3 130.8 29.0 67.0 27.5 111.2 Total Wholesale Revenues 399.9 1,210.3 361.0 303.6 67.0 42.6 273.2 Other Revenues from Contracts with Customers (c) 48.2 22.4 59.5 85.0 109.5 34.7 26.7 Total Revenues from Contracts with Customers 1,528.0 1,232.7 2,809.2 2,236.0 2,665.0 1,263.9 1,735.3 Other Revenues: Alternative Revenues (d) 3.4 (87.0) (13.0) 5.8 66.6 2.2 3.2 Other Revenues (d) 87.5 — — — 17.5 — — Total Other Revenues 90.9 (87.0) (13.0) 5.8 84.1 2.2 3.2 Total Revenues $ 1,618.9 $ 1,145.7 $ 2,796.2 $ 2,241.8 $ 2,749.1 $ 1,266.1 $ 1,738.5 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $112 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $952 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $69 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. Year Ended December 31, 2019 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 571.5 $ — $ 1,266.9 $ 730.0 $ 1,502.0 $ 650.2 $ 638.6 Commercial Revenues 411.5 — 559.9 494.2 738.5 388.5 485.4 Industrial Revenues 129.4 — 592.2 550.7 299.9 303.5 338.7 Other Retail Revenues 29.9 — 75.2 7.3 13.1 81.6 9.0 Total Retail Revenues 1,142.3 — 2,494.2 1,782.2 2,553.5 1,423.8 1,471.7 Wholesale Revenues: Generation Revenues (a) — — 251.5 402.4 — 39.5 194.7 Transmission Revenues (b) 379.2 1,025.5 103.6 25.1 56.0 27.5 106.7 Total Wholesale Revenues 379.2 1,025.5 355.1 427.5 56.0 67.0 301.4 Other Revenues from Contracts with Customers (c) 30.1 16.6 61.8 98.4 139.3 22.0 26.1 Total Revenues from Contracts with Customers 1,551.6 1,042.1 2,911.1 2,308.1 2,748.8 1,512.8 1,799.2 Other Revenues: Alternative Revenues (d) 0.6 (20.7) 13.6 (1.4) 31.7 (31.0) (48.3) Other Revenues (d) 157.1 — — — 17.1 — — Total Other Revenues 157.7 (20.7) 13.6 (1.4) 48.8 (31.0) (48.3) Total Revenues $ 1,709.3 $ 1,021.4 $ 2,924.7 $ 2,306.7 $ 2,797.6 $ 1,481.8 $ 1,750.9 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $129 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $782 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $73 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. Performance Obligations AEP has performance obligations as part of its normal course of business. A performance obligation is a promise to transfer a distinct good or service, or a series of distinct goods or services that are substantially the same and have the same pattern of transfer to a customer. The invoice practical expedient within the accounting guidance for “Revenue from Contracts with Customers” allows for the recognition of revenue from performance obligations in the amount of consideration to which there is a right to invoice the customer and when the amount for which there is a right to invoice corresponds directly to the value transferred to the customer. The purpose of the invoice practical expedient is to depict an entity’s measure of progress toward completion of the performance obligation within a contract and can only be applied to performance obligations that are satisfied over time and when the invoice is representative of services provided to date. AEP subsidiaries elected to apply the invoice practical expedient to recognize revenue for performance obligations satisfied over time as the invoices from the respective revenue streams are representative of services or goods provided to date to the customer. Performance obligations for AEP’s subsidiaries are summarized as follows: Retail Revenues AEP’s subsidiaries within the Vertically Integrated Utilities and Transmission and Distribution Utilities segments have performance obligations to generate, transmit and distribute electricity for sale to rate-regulated retail customers. The performance obligation to deliver electricity is satisfied over time as the customer simultaneously receives and consumes the benefits provided. Revenues are variable as they are subject to the customer’s usage requirements. Rate-regulated retail customers typically have the right to discontinue receiving service at will, therefore these contracts between AEP’s subsidiaries and their customers for rate-regulated services are generally limited to the services requested and received to date for such arrangements. Retail customers are generally billed on a monthly basis, and payment is typically due within 15 to 20 days after the issuance of the invoice. Payments from REPs are due to AEP Texas within 35 days. Wholesale Revenues - Generation AEP’s subsidiaries within the Vertically Integrated Utilities and Generation & Marketing segments have performance obligations to sell electricity to wholesale customers from generation assets in PJM, SPP and ERCOT. The performance obligation to deliver electricity from generation assets is satisfied over time as the customer simultaneously receives and consumes the benefits provided. Wholesale generation revenues are variable as they are subject to the customer’s usage requirements. AEP’s subsidiaries within the Vertically Integrated Utilities and Generation & Marketing segments also have performance obligations to stand ready in order to promote grid reliability. Stand ready services are sold into PJM’s RPM capacity market. RPM entails a base auction and at least three incremental auctions for a specific PJM delivery year, with the incremental auctions spanning three years. The performance obligation to stand ready is satisfied over time and the consideration for which is variable until the occurrence of the final incremental auction, at which point the performance obligation becomes fixed. Payments from the RTO for stand ready services are typically received within one week from the issuance of the invoice, which is typically issued weekly. Gross margin resulting from generation sales within the Vertically Integrated Utilities segment are primarily subject to margin sharing agreements with customers and vary by state, where the revenues are reflected gross in the disaggregated revenues tables above. APCo has a performance obligation to supply wholesale electricity to KGPCo through a PPA. The FERC regulates the cost-based wholesale power transactions between APCo and KGPCo. The purchased power agreement includes a component for the recovery of transmission costs under the FERC OATT. The transmission cost component of purchased power is cost-based and regulated by the Tennessee Regulatory Authority. APCo’s performance obligation under the purchased power agreement is satisfied over time as KGPCo simultaneously receives and consumes the wholesale electricity. APCo’s revenues from the purchased power agreement are presented within the Generation Revenues line in the disaggregated revenues tables above. Wholesale Revenues - Transmission AEP’s subsidiaries within the Vertically Integrated Utilities, Transmission and Distribution Utilities and AEP Transmission Holdco segments have performance obligations to transmit electricity to wholesale customers through assets owned and operated by AEP subsidiaries. The performance obligation to provide transmission services in PJM, SPP and ERCOT encompass a time frame greater than a year, where the performance obligation within each RTO is partially fixed for a period of one year or less. Payments from the RTO for transmission services are typically received within one week from the issuance of the invoice, which is issued monthly for SPP and ERCOT and weekly for PJM. AEP subsidiaries within the PJM and SPP regions collect revenues through transmission formula rates. The FERC-approved rates establish the annual transmission revenue requirement (ATRR) and transmission service rates for transmission owners. The formula rates establish rates for a one year period and also include a true-up calculation for the prior year’s billings, allowing for over/under-recovery of the transmission owner’s ATRR. The annual true-ups meet the definition of alternative revenues in accordance with the accounting guidance for “Regulated Operations,” and are therefore presented as such in the disaggregated revenues tables above. AEP subsidiaries within the ERCOT region collect revenues through a combination of base rates and interim Transmission Costs of Services filings that are approved by the PUCT. The AEP East Companies are parties to the TA, which defines how transmission costs are allocated among the AEP East Companies on a 12-month average coincident peak basis. PSO, SWEPCo and AEPSC are parties to the TCA by and among PSO, SWEPCo and AEPSC, in connection with the operation of the transmission assets of the two AEP utility subsidiaries. AEPTCo is a transmission owner within the PJM and SPP regions providing transmission services to affiliates in accordance with the OATT, TA and TCA. Affiliate revenues as a result of the respective TA and the TCA are reflected as Transmission Revenues in the disaggregated revenues tables above. Marketing, Competitive Retail and Renewable Revenues AEP’s subsidiaries within the Generation & Marketing segment have performance obligations to deliver electricity to competitive retail and wholesale customers. Performance obligations for marketing, competitive retail and renewable offtake sales are satisfied over time as the customer simultaneously receives and consumes the benefits provided. Revenues are primarily variable as they are subject to customer’s usage requirements; however, certain contracts mandate a delivery of a set quantity of electricity at a predetermined price, resulting in a fixed performance obligation. Payment terms under marketing arrangements typically follow standard Edison Electric Institute and International Swaps and Derivatives Association terms, which call for payment in 20 days. Payments for competitive retail and offtake arrangements for renewable assets range from 15 to 60 days and are dependent on the product sold, location and the creditworthiness of customer. Invoices for marketing arrangements, competitive retail and offtake arrangements for renewable assets are issued monthly. Fixed Performance Obligations The following table represents the Registrants’ remaining fixed performance obligations satisfied over time as of December 31, 2021. Fixed performance obligations primarily include wholesale transmission services, electricity sales for fixed amounts of energy and stand ready services into PJM’s RPM market. The Registrant Subsidiaries amounts shown in the table below include affiliated and nonaffiliated revenues. Company 2022 2023-2024 2025-2026 After 2026 Total (in millions) AEP $ 1,231.9 $ 160.8 $ 157.9 $ 97.0 $ 1,647.6 AEP Texas 531.0 — — — 531.0 AEPTCo 1,510.3 — — — 1,510.3 APCo 201.5 32.2 23.2 11.6 268.5 I&M 37.7 8.8 8.8 4.5 59.8 OPCo 78.3 — — — 78.3 PSO 13.1 — — — 13.1 SWEPCo 43.0 — — — 43.0 Contract Assets and Liabilities Contract assets are recognized when the Registrants have a right to consideration that is conditional upon the occurrence of an event other than the passage of time, such as future performance under a contract. The Registrants did not have any material contract assets as of December 31, 2021 and 2020. When the Registrants receive consideration, or such consideration is unconditionally due from a customer prior to transferring goods or services to the customer under the terms of a sales contract, they recognize a contract liability on the balance sheet in the amount of that consideration. Revenue for such consideration is subsequently recognized in the period or periods in which the remaining performance obligations in the contract are satisfied. The Registrants’ contract liabilities typically arise from services provided under joint use agreements for utility poles. The Registrants did not have any material contract liabilities as of December 31, 2021 and 2020. Accounts Receivable from Contracts with Customers Accounts receivable from contracts with customers are presented on the Registrants’ balance sheets within the Accounts Receivable - Customers line item. The Registrants’ balances for receivables from contracts that are not recognized in accordance with the accounting guidance for “Revenue from Contracts with Customers” included in Accounts Receivable - Customers were not material as of December 31, 2021 and 2020. See “Securitized Accounts Receivable - AEP Credit” section of Note 14 for additional information. The following table represents the amount of affiliated accounts receivable from contracts with customers included in Accounts Receivable - Affiliated Companies on the Registrant Subsidiaries’ balance sheets: Years Ended December 31, Company 2021 2020 (in millions) AEP Texas $ 0.4 $ 0.2 AEPTCo 95.5 81.0 APCo 117.8 52.7 I&M 61.2 34.8 OPCo 51.7 45.9 PSO 18.8 7.8 SWEPCo 24.7 11.2 Contract Costs Contract costs to obtain or fulfill a contract for AEP subsidiaries within the Generation & Marketing segment are accounted for under the guidance for “Other Assets and Deferred Costs” and presented as a single asset and are neither bifurcated nor reclassified between current and noncurrent assets on the Registrants’ balance sheets. Contract costs to acquire a contract are amortized in a manner consistent with the transfer of goods or services to the customer in Other Operation on the Registrants’ income statements. The Registrants did not have material contract costs as of December 31, 2021 and 2020.

Goodwill

Goodwill	12 Months Ended
Goodwill	Dec. 31, 2021
Goodwill	GOODWILL The disclosure in this note applies to AEP only. The changes in AEP’s carrying amount of goodwill for the years ended December 31, 2021 and 2020 by operating segment are as follows: Corporate and Other Generation AEP Consolidated (in millions) Balance as of December 31, 2019 $ 37.1 $ 15.4 $ 52.5 Impairment Losses — — — Balance as of December 31, 2020 37.1 15.4 52.5 Impairment Losses — — — Balance as of December 31, 2021 $ 37.1 $ 15.4 $ 52.5 In the fourth quarters of 2021 and 2020, annual impairment tests were performed. The fair values of the reporting units with goodwill were estimated using cash flow projections and other market value indicators. There were no goodwill impairment losses. AEP does not have any accumulated impairment on existing goodwill.

Organization and Summary of S_2

Organization and Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2021
Basis of Accounting	ORGANIZATION The Registrants engage in the generation, transmission and distribution of electric power. The Registrant Subsidiaries that conduct most of these activities are regulated by the FERC under the Federal Power Act and the Energy Policy Act of 2005 and maintain accounts in accordance with the FERC and other regulatory guidelines. Most of these companies are subject to further regulation with regard to rates and other matters by state regulatory commissions. AEP provides competitive electric and gas supply for residential, commercial and industrial customers in deregulated electricity markets and also provides energy management solutions throughout the United States, including energy efficiency services through its independent retail electric supplier.
Rates and Service Regulation	Rates and Service Regulation AEP’s public utility subsidiaries’ rates are regulated by the FERC and state regulatory commissions in the eleven state operating territories in which they operate. The FERC also regulates the Registrants’ affiliated transactions, including AEPSC intercompany service billings which are generally at cost, under the 2005 Public Utility Holding Company Act and the Federal Power Act. The FERC also has jurisdiction over certain issuances and acquisitions of securities of the public utility subsidiaries, the acquisition or sale of certain utility assets and mergers with another electric utility or holding company. The state regulatory commissions also regulate certain intercompany transactions under various orders and affiliate statutes. Both the FERC and state regulatory commissions are permitted to review and audit the relevant books and records of companies within a public utility holding company system. The FERC regulates wholesale power markets and wholesale power transactions. The Registrants’ wholesale power transactions are generally market-based. Wholesale power transactions are cost-based regulated when a cost-based contract is negotiated and filed with the FERC or the FERC determines that the Registrants have “market power” in the region where the transaction occurs. Wholesale power supply contracts have been entered into with various municipalities and cooperatives that are FERC-regulated, cost-based contracts. These contracts are generally formula rate mechanisms, which are trued-up to actual costs annually. The state regulatory commissions regulate all of the retail distribution operations and rates of the Registrants’ retail public utility subsidiaries on a cost basis. The state regulatory commissions also regulate the retail generation/power supply operations and rates except in Ohio and the ERCOT region of Texas. For generation in Ohio, customers who have not switched to a CRES provider for generation pay market-based auction rates. In addition, all OPCo distribution customers continue to pay for certain legacy deferred generation-related costs through PUCO approved riders. In the ERCOT region of Texas, the generation/supply business is under customer choice and market pricing is conducted by REPs. AEP has one active REP in ERCOT. AEP’s nonregulated subsidiaries enter into short and long-term wholesale transactions to buy or sell capacity, energy and ancillary services in the ERCOT market. In addition, these nonregulated subsidiaries control certain wind assets, the power from which is marketed and sold in ERCOT. Power from the Oklaunion Power Station was also marketed and sold by these nonregulated subsidiaries in ERCOT prior to its retirement in 2020. The FERC also regulates the Registrants’ wholesale transmission operations and rates. Retail transmission rates are based upon the FERC OATT rate when retail rates are unbundled in connection with restructuring. Retail transmission rates are based on formula rates included in the PJM OATT that are cost-based and are unbundled in Ohio for OPCo, in Virginia for APCo and in Michigan for I&M. AEP Texas’ retail transmission rates in Texas are unbundled but the retail transmission rates are regulated, on a cost basis, by the PUCT. Bundled retail transmission rates are regulated, on a cost basis, by the state commissions. Transmission rates for AEPTCo’s seven wholly-owned transmission subsidiaries within the AEP Transmission Holdco segment are based on formula rates included in the applicable RTO’s OATT that are cost-based. In West Virginia, APCo and WPCo provide retail electric service at bundled rates approved by the WVPSC, with rates set on a combined cost-of-service basis.
Principles of Consolidation	Principles of Consolidation AEP’s consolidated financial statements include its wholly-owned and majority-owned subsidiaries and VIEs of which AEP is the primary beneficiary. The consolidated financial statements for AEP Texas include the Registrant Subsidiary, its wholly-owned subsidiaries, Transition Funding (consolidated VIEs) and Restoration Funding (a consolidated VIE). The consolidated financial statements for APCo include the Registrant Subsidiary, its wholly-owned subsidiaries and Appalachian Consumer Rate Relief Funding (a consolidated VIE). The consolidated financial statements for I&M include the Registrant Subsidiary, its wholly-owned subsidiaries and DCC Fuel (consolidated VIEs). The consolidated statements of cash flows for OPCo include the Registrant Subsidiary and Ohio Phase-in Recovery Funding (a consolidated VIE) for the year ended December 31, 2019. In July 2019, the Ohio Phase-in Recovery Funding securitization bonds matured. The consolidated financial statements for SWEPCo include the Registrant Subsidiary, its wholly-owned subsidiary and Sabine (a consolidated VIE). Intercompany items are eliminated in consolidation. The equity method of accounting is used for equity investments where the Registrants exercise significant influence but do not hold a controlling financial interest. Such investments are initially recorded at cost in Deferred Charges and Other Noncurrent Assets on the balance sheets. The proportionate share of the investee’s equity earnings or losses is included in Equity Earnings of Unconsolidated Subsidiaries on the statements of income.
Accounting for the Effects of Cost-Based Regulation	Accounting for the Effects of Cost-Based Regulation The Registrants’ financial statements reflect the actions of regulators that result in the recognition of certain revenues and expenses in different time periods than enterprises that are not rate-regulated. In accordance with accounting guidance for “Regulated Operations,” regulatory assets (deferred expenses) and regulatory liabilities (deferred revenue reductions or refunds) are recorded to reflect the economic effects of regulation in the same accounting period by matching expenses with their recovery through regulated revenues and by matching income with its passage to customers in cost-based regulated rates.
Use of Estimates	Use of Estimates The preparation of these financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. These estimates include, but are not limited to, inventory valuation, allowance for doubtful accounts, goodwill, intangible and long-lived asset impairment, unbilled electricity revenue, valuation of long-term energy contracts, the effects of regulation, long-lived asset recovery, storm costs, the effects of contingencies and certain assumptions made in accounting for pension and postretirement benefits. The estimates and assumptions used are based upon management’s evaluation of the relevant facts and circumstances as of the date of the financial statements. Actual results could ultimately differ from those estimates.
Cash and Cash Equivalents	Cash and Cash Equivalents Cash and Cash Equivalents include temporary cash investments with original maturities of three months or less.
Restricted Cash for Securitized Funding	Restricted Cash (Applies to AEP, AEP Texas and APCo) Restricted Cash primarily includes funds held by trustees for the payment of securitization bonds.
Other Temporary Investments	Other Temporary Investments (Applies to AEP) Other Temporary Investments primarily include marketable securities and investments by its protected cell of EIS. These securities have readily determinable fair values and are carried at fair value with changes in fair value recognized in net income. The cost of securities sold is based on the specific identification or weighted-average cost method. See “Fair Value Measurements of Other Temporary Investments” section of Note 11 for additional information.
Inventory	InventoryFossil fuel inventories are carried at average cost with the exception of AGR, which carries these inventories at the lower of average cost or net realizable value. Materials and supplies inventories are carried at average cost.
Accounts Receivable	Accounts Receivable Customer accounts receivable primarily include receivables from wholesale and retail energy customers, receivables from energy contract counterparties related to risk management activities and customer receivables primarily related to other revenue-generating activities. Revenue is recognized over time as the performance obligations of delivering energy to customers are satisfied. To the extent that deliveries have occurred but a bill has not been issued, the Registrants accrue and recognize, as Accrued Unbilled Revenues on the balance sheets, an estimate of the revenues for energy delivered since the last billing. AEP Credit factors accounts receivable on a daily basis, excluding receivables from risk management activities, through purchase agreements with I&M, KGPCo, KPCo, OPCo, PSO, SWEPCo and a portion of APCo. Since APCo does not have regulatory authority to sell accounts receivable in its West Virginia regulatory jurisdiction, only a portion of APCo’s accounts receivable are sold to AEP Credit. AEP Credit has a receivables securitization agreement with bank conduits. Under the securitization agreement, AEP Credit receives financing from bank conduits for the interest in the billed and unbilled receivables they acquire from affiliated utility subsidiaries. See “Securitized Accounts Receivable – AEP Credit” section of Note 14 for additional information.
Allowance for Uncollectible Accounts	Allowance for Uncollectible Accounts Generally, AEP Credit records bad debt expense based upon a 12-month rolling average of bad debt write-offs in proportion to gross accounts receivable purchased from participating AEP subsidiaries. The assessment is performed separately by each participating AEP subsidiary, which inherently contemplates any differences in geographical risk characteristics for the allowance. For receivables related to APCo’s West Virginia operations, the bad debt reserve is calculated based on a rolling two-year average write-off in proportion to gross accounts receivable. KPCo terminated selling accounts receivable to AEP Credit in the first quarter of 2022, based on the pending sale to Liberty. As a result of the termination, in the first quarter of 2022, KPCo will record an allowance for uncollectible accounts on its balance sheet for those receivables no longer sold to AEP Credit. For customer accounts receivables relating to risk management activities, accounts receivables are reviewed for bad debt reserves at a specific counterparty level basis. For AEP Texas, bad debt reserves are calculated using the specific identification of receivable balances greater than 120 days delinquent, and for those balances less than 120 days where the collection is doubtful. For miscellaneous accounts receivable, bad debt expense is recorded based upon a 12-month rolling average of bad debt write-offs in proportion to gross accounts receivable, unless specifically identified. In addition to these processes, management contemplates available current information, as well as any reasonable and supportable forecast information, to determine if allowances for uncollectible accounts should be further adjusted in accordance with the accounting guidance for “Credit Losses.” Management’s assessments contemplate expected losses over the life of the accounts receivable.
Concentrations of Credit Risk and Significant Customers	The Registrant Subsidiaries monitor credit levels and the financial condition of their customers on a continuous basis to minimize credit risk. The regulatory commissions allow recovery in rates for a reasonable level of bad debt costs. Management believes adequate provisions for credit loss have been made in the accompanying Registrant Subsidiary financial statements.
Emission Allowances and Renewable Energy Credits	Renewable Energy Credits (Applies to all Registrants except AEP Texas and AEPTCo) In regulated jurisdictions, the Registrants record renewable energy credits (RECs) at cost. For AEP’s competitive generation business, management records RECs at the lower of cost or net realizable value. The Registrants follow the inventory model for these RECs. RECs expected to be consumed within one year are reported in Materials and Supplies on the balance sheets. RECs with expected consumption beyond one year are included in Deferred Charges and Other Noncurrent Assets on the balance sheets. The purchases and sales of RECs are reported in the Operating Activities section of the statements of cash flows. RECs that are consumed to meet applicable state renewable portfolio standards are recorded in Fuel and Other Consumables Used for Electric Generation at an average cost on the statements of income. The net margin on sales of RECs affects the determination of deferred fuel and REC costs.
Property, Plant and Equipment and Equity Investments	Property, Plant and Equipment Regulated Electric utility property, plant and equipment for rate-regulated operations are stated at original cost. Additions, major replacements and betterments are added to the plant accounts. Under the group composite method of depreciation, continuous interim routine replacements of items such as boiler tubes, pumps, motors, etc. result in original cost retirements, less salvage, being charged to accumulated depreciation. The group composite method of depreciation assumes that on average, asset components are retired at the end of their useful lives and thus there is no gain or loss. The equipment in each primary electric plant account is identified as a separate group. The depreciation rates that are established take into account the past history of interim capital replacements and the amount of removal cost incurred and salvage received. These rates and the related lives are subject to periodic review. Removal costs accrued are typically recorded as regulatory liabilities when the revenue received for removal costs accrued exceeds actual removal costs incurred. The asset removal costs liability is relieved as removal costs are incurred. A regulatory asset balance will occur if actual removal costs incurred exceed accumulated removal costs accrued. The costs of labor, materials and overhead incurred to operate and maintain plant and equipment are included in operating expenses. Nuclear fuel, including nuclear fuel in the fabrication phase, is included in Other Property, Plant and Equipment on the balance sheets. Long-lived assets are required to be tested for impairment when it is determined that the carrying value of the assets may no longer be recoverable or when the assets meet the held-for-sale criteria under the accounting guidance for “Impairment or Disposal of Long-Lived Assets.” When it becomes probable that an asset in-service or an asset under construction will be abandoned and regulatory cost recovery has been disallowed or is not probable, the cost of that asset shall be removed from plant-in-service or CWIP and charged to expense. The fair value of an asset is the amount at which that asset could be bought or sold in a current transaction between willing parties, as opposed to a forced or liquidation sale. Quoted market prices in active markets are the best evidence of fair value and are used as the basis for the measurement, if available. In the absence of quoted prices for identical or similar assets in active markets, fair value is estimated using various internal and external valuation methods including cash flow analysis and appraisals. Nonregulated Nonregulated operations generally follow the policies of rate-regulated operations listed above but with the following exceptions. Property, plant and equipment of nonregulated operations are stated at original cost (or as adjusted for any applicable impairments) plus the original cost of property acquired or constructed since the acquisition, less disposals. Normal and routine retirements from the plant accounts, net of salvage, are charged to accumulated depreciation for most nonregulated operations under the group composite method of depreciation. A gain or loss would be recorded if the retirement is not considered an interim routine replacement. Removal costs are charged to expense.
Allowance for Funds Used During Construction (AFUDC) and Interest Capitalization	Allowance for Funds Used During Construction and Interest Capitalization For regulated operations, AFUDC represents the estimated cost of borrowed and equity funds used to finance construction projects that is capitalized and recovered through depreciation over the service life of regulated electric utility plant. The Registrants record the equity component of AFUDC in Allowance for Equity Funds Used During Construction and the debt component of AFUDC as a reduction to Interest Expense on the statements of income. For nonregulated operations, including certain generating assets, interest is capitalized during construction in accordance with the accounting guidance for “Capitalization of Interest.”
Fair Value Measurements of Assets and Liabilities	Valuation of Nonderivative Financial Instruments The book values of Cash and Cash Equivalents, Advances to/from Affiliates, Accounts Receivable, Accounts Payable and Short-term Debt approximate fair value because of the short-term maturity of these instruments. Fair Value Measurements of Assets and Liabilities (Applies to all Registrants except AEPTCo) The accounting guidance for “Fair Value Measurements and Disclosures” establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). Where observable inputs are available for substantially the full term of the asset or liability, the instrument is categorized in Level 2. When quoted market prices are not available, pricing may be completed using comparable securities, dealer values, operating data and general market conditions to determine fair value. Valuation models utilize various inputs such as commodity, interest rate and, to a lesser degree, volatility and credit that include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, market corroborated inputs (i.e. inputs derived principally from, or correlated to, observable market data) and other observable inputs for the asset or liability. For commercial activities, exchange-traded derivatives, namely futures contracts, are generally fair valued based on unadjusted quoted prices in active markets and are classified as Level 1. Level 2 inputs primarily consist of OTC broker quotes in moderately active or less active markets, as well as exchange-traded derivatives where there is insufficient market liquidity to warrant inclusion in Level 1. Management verifies price curves using these broker quotes and classifies these fair values within Level 2 when substantially all of the fair value can be corroborated. Management typically obtains multiple broker quotes, which are nonbinding in nature but are based on recent trades in the marketplace. When multiple broker quotes are obtained, the quoted bid and ask prices are averaged. In certain circumstances, a broker quote may be discarded if it is a clear outlier. Management uses a historical correlation analysis between the broker quoted location and the illiquid locations. If the points are highly correlated, these locations are included within Level 2 as well. Certain OTC and bilaterally executed derivative instruments are executed in less active markets with a lower availability of pricing information. Illiquid transactions, complex structured transactions, FTRs and counterparty credit risk may require nonmarket-based inputs. Some of these inputs may be internally developed or extrapolated and utilized to estimate fair value. When such inputs have a significant impact on the measurement of fair value, the instrument is categorized as Level 3. The main driver of contracts being classified as Level 3 is the inability to substantiate energy price curves in the market. A portion of the Level 3 instruments have been economically hedged which limits potential earnings volatility. AEP utilizes its trustee’s external pricing service to estimate the fair value of the underlying investments held in the benefit plan and nuclear trusts. AEP’s investment managers review and validate the prices utilized by the trustee to determine fair value. AEP’s management performs its own valuation testing to verify the fair values of the securities. AEP receives audit reports of the trustee’s operating controls and valuation processes. Assets in the benefits and nuclear trusts, cash and cash equivalents, other temporary investments and restricted cash for securitized funding are classified using the following methods. Equities are classified as Level 1 holdings if they are actively traded on exchanges. Items classified as Level 1 are investments in money market funds, fixed income and equity mutual funds and equity securities. They are valued based on observable inputs, primarily unadjusted quoted prices in active markets for identical assets. Items classified as Level 2 are primarily investments in individual fixed income securities. Fixed income securities generally do not trade on exchanges and do not have an official closing price but their valuation inputs are based on observable market data. Pricing vendors calculate bond valuations using financial models and matrices. The models use observable inputs including yields on benchmark securities, quotes by securities brokers, rating agency actions, discounts or premiums on securities compared to par prices, changes in yields for U.S. Treasury securities, corporate actions by bond issuers, prepayment schedules and histories, economic events and, for certain securities, adjustments to yields to reflect changes in the rate of inflation. Other securities with model-derived valuation inputs that are observable are also classified as Level 2 investments. Investments with unobservable valuation inputs are classified as Level 3 investments. Investments classified as Other are valued using Net Asset Value as a practical expedient. Items classified as Other are primarily cash equivalent funds, common collective trusts, commingled funds, structured products, private equity, real estate, infrastructure and alternative credit investments. These investments do not have a readily determinable fair value or they contain redemption restrictions which may include the right to suspend redemptions under certain circumstances. Redemption restrictions may also prevent certain investments from being redeemed at the reporting date for the underlying value.
Deferred Fuel Costs	Deferred Fuel Costs (Applies to all Registrants except AEP Texas and AEPTCo) The cost of fuel and related emission allowances and emission control chemicals/consumables is charged to Fuel and Other Consumables Used for Electric Generation expense when the fuel is burned or the allowance or consumable is utilized. The cost of fuel also includes the cost of nuclear fuel burned which is computed primarily using the units-of-production method. In regulated jurisdictions with an active FAC, fuel cost over-recoveries (the excess of fuel-related revenues over applicable fuel costs incurred) are generally deferred as current regulatory liabilities and under-recoveries (the excess of applicable fuel costs incurred over fuel-related revenues) are generally deferred as current regulatory assets. Fuel cost over-recovery and under-recovery balances are classified as noncurrent when there is a commission-approved plan to delay refunds or recoveries beyond a one year period. These deferrals are amortized when refunded or when billed to customers in later months with the state regulatory commissions’ review and approval. The amount of an over-recovery or under-recovery can also be affected by actions of the state regulatory commissions. On a routine basis, state regulatory commissions review and/or audit the Registrants’ fuel procurement policies and practices, the fuel cost calculations and FAC deferrals. FAC deferrals are adjusted when costs are no longer probable of recovery or when refunds of fuel reserves are probable. The Registrants share the majority of their Off-system Sales margins to customers either through an active FAC or other rate mechanisms. Where the FAC or Off-system Sales sharing mechanism is capped, frozen or non-existent, changes in fuel costs or sharing of off-system sales impact earnings.
Revenue Recognition	Revenue Recognition Regulatory Accounting The Registrants’ financial statements reflect the actions of regulators that can result in the recognition of revenues and expenses in different time periods than enterprises that are not rate-regulated. Regulatory assets (deferred expenses or alternative revenues recognized in accordance with the guidance for “Regulated Operations”) and regulatory liabilities (deferred revenue reductions or refunds) are recorded to reflect the economic effects of regulation in the same accounting period by matching expenses with their recovery through regulated revenues and by matching revenue with its passage to customers in cost-based regulated rates. When regulatory assets are probable of recovery through regulated rates, assets are recorded on the balance sheets. Regulatory assets are reviewed for probability of recovery at each balance sheet date or whenever new events occur. Examples of new events include the issuance of a regulatory commission order or passage of new legislation. If it is determined that recovery of a regulatory asset is no longer probable, the regulatory asset is derecognized as a charge against income. Retail and Wholesale Supply and Delivery of Electricity The Registrants recognize revenues from customers for retail and wholesale electricity sales and electricity transmission and distribution delivery services. The Registrants recognize such revenues on the statements of income as the performance obligations of delivering energy to customers are satisfied. Recognized revenues include both billed and unbilled amounts. In accordance with the applicable state commission’s regulatory treatment, PSO and SWEPCo do not include the fuel portion in unbilled revenue, but rather recognize such revenues when billed to customers. Wholesale transmission revenue is based on FERC-approved formula rate filings made for each calendar year using estimated costs. Revenues initially recognized per the annual rate filing are compared to actual costs, resulting in the subsequent recognition of an over or under-recovered amount, with interest, that is refunded or recovered, respectively, in a future year’s rates. These annual true-ups meet the definition of alternative revenues in accordance with the accounting guidance for “Regulated Operations”, and are recognized by the Registrants in the second quarter of each calendar year following the filing of annual FERC reports. Any portion of the true-ups applicable to an affiliated company is recorded as Accounts Receivable - Affiliated Companies or Accounts Payable - Affiliated Companies on the balance sheets. Any portion of the true-ups applicable to third-parties is recorded as Regulatory Assets or Regulatory Liabilities on the balance sheets. See Note 19 - Revenue from Contracts with Customers for additional information. Gross versus Net Presentation of Certain Electricity Supply and Delivery Activities Most of the power produced at the generation plants is sold to PJM or SPP. The Registrants also purchase power from PJM and SPP to supply power to customers. Generally, these power sales and purchases are reported on a net basis as revenues on the statements of income. However, purchases of power in excess of sales to PJM or SPP, on an hourly net basis, used to serve retail load are recorded gross as Purchased Electricity for Resale on the statements of income. With the exception of certain dedicated load bilateral power supply contracts, the transactions of AEP’s nonregulated subsidiaries are reported as gross purchases or sales. Physical energy purchases arising from non-derivative contracts are accounted for on a gross basis in Purchased Electricity for Resale on the statements of income. Energy purchases arising from non-trading derivative contracts are recorded based on the transaction’s facts and circumstances. Purchases under non-trading derivatives used to serve accrual based obligations are recorded in Purchased Electricity for Resale on the statements of income. All other non-trading derivative purchases are recorded net in revenues. In general, the Registrants record expenses when purchased electricity is received and when expenses are incurred, with the exception of certain power purchase contracts that are derivatives and accounted for using MTM accounting where generation/supply rates are not cost-based regulated. In jurisdictions where the generation/supply business is subject to cost-based regulation, the unrealized MTM amounts are deferred as regulatory assets (for losses) and regulatory liabilities (for gains). Energy Marketing and Risk Management Activities (Applies to all Registrants except AEPTCo) The Registrants engage in power, capacity and, to a lesser extent, natural gas marketing as major power producers and participants in electricity and natural gas markets. The Registrants also engage in power, capacity, coal, natural gas and, to a lesser extent, heating oil, gasoline and other commodity risk management activities focused on markets where the AEP System owns assets and on adjacent markets. These activities include the purchase-and-sale of energy under forward contracts at fixed and variable prices. These contracts include physical transactions, exchange-traded futures, and to a lesser extent, OTC swaps and options. Certain energy marketing and risk management transactions are with RTOs. The Registrants recognize revenues from marketing and risk management transactions that are not derivatives as the performance obligation of delivering the commodity is satisfied. Expenses from marketing and risk management transactions that are not derivatives are also recognized upon delivery of the commodity. The Registrants use MTM accounting for marketing and risk management transactions that are derivatives unless the derivative is designated in a qualifying cash flow hedge relationship or elected normal under the normal purchase normal sale election. Unrealized MTM gains and losses are included on the balance sheets as Risk Management Assets or Liabilities, as appropriate, and on the statements of income in Total Revenues. Realized gains and losses on marketing and risk management transactions are included in revenues or expenses based on the transaction’s facts and circumstances. However, in regulated jurisdictions subject to cost-based regulation, unrealized MTM amounts and some realized gains and losses are deferred as regulatory assets (for losses) and regulatory liabilities (for gains).
Levelization of Nuclear Refueling Outage Costs	Levelization of Nuclear Refueling Outage Costs (Applies to AEP and I&M) In accordance with regulatory orders, I&M defers incremental operation and maintenance costs associated with periodic refueling outages at its Cook Plant and amortizes the costs over approximately 18 months, beginning with the month following the start of each unit’s refueling outage and lasting until the end of the month in which the same unit’s next scheduled refueling outage begins.
Maintenance	Maintenance The Registrants expense maintenance costs as incurred. If it becomes probable that the Registrants will recover specifically-incurred costs through future rates, a regulatory asset is established to match the expensing of those maintenance costs with their recovery in cost-based regulated revenues. In certain regulated jurisdictions, the Registrants defer costs above the level included in base rates and amortize those deferrals commensurate with recovery through rate riders.
Income Taxes and Investment Tax Credits	Income Taxes and Investment and Production Tax Credits The Registrants use the liability method of accounting for income taxes. Under the liability method, deferred income taxes are provided for all temporary differences between the book and tax basis of assets and liabilities which will result in a future tax consequence. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which the temporary differences are expected to be recovered or settled. When the flow-through method of accounting for temporary differences is required by a regulator to be reflected in regulated revenues (that is, when deferred taxes are not included in the cost-of-service for determining regulated rates for electricity), deferred income taxes are recorded and related regulatory assets and liabilities are established to match the regulated revenues and tax expense. AEP and subsidiaries apply the deferral methodology for the recognition of ITCs. Deferred ITCs are amortized to income tax expense over the life of the asset that generated the credit. Amortization of deferred ITCs begins when the asset is placed in-service, except where regulatory commissions reflect ITCs in the rate-making process, then amortization begins when the cash tax benefit is recognized. Alternatively, PTCs reduce income tax expense as they are earned. PTCs are earned when electricity is produced. The Registrants account for uncertain tax positions in accordance with the accounting guidance for “Income Taxes.” The Registrants classify interest expense or income related to uncertain tax positions as interest expense or income as appropriate and classify penalties as Other Operation expense on the statements of income. AEP System Tax Allocation Agreement AEP and subsidiaries join in the filing of a consolidated federal income tax return. The allocation of the AEP System’s current consolidated federal income tax to the AEP System companies allocates the benefit of current tax loss of the parent company (Parent Company Loss Benefit) to the AEP System subsidiaries with taxable income reducing their current tax expense proportionately. The consolidated NOL of the AEP System is allocated to each company in the consolidated group with taxable losses. With the exception of the allocation of the consolidated AEP System NOL, the loss of the Parent and tax credits, the method of allocation reflects a separate return result for each company in the consolidated group.
Excise Taxes	Excise Taxes (Applies to all Registrants except AEPTCo) As agents for some state and local governments, the Registrants collect from customers certain excise taxes levied by those state or local governments on customers. The Registrants do not record these taxes as revenue or expense.
Debt	Debt Gains and losses from the reacquisition of debt used to finance regulated electric utility plants are deferred and amortized over the remaining term of the reacquired debt in accordance with their rate-making treatment unless the debt is refinanced. If the reacquired debt associated with the regulated business is refinanced, the reacquisition costs attributable to the portions of the business that are subject to cost-based regulatory accounting are generally deferred and amortized over the term of the replacement debt consistent with its recovery in rates. Operations not subject to cost-based rate regulation report gains and losses on the reacquisition of debt in Interest Expense on the statements of income upon reacquisition. Debt discount or premium and debt issuance expenses are deferred and amortized generally utilizing the straight-line method over the term of the related debt. The straight-line method approximates the effective interest method and is consistent with the treatment in rates for regulated operations. The net amortization expense is included in Interest Expense on the statements of income.
Goodwill and Intangible Assets, Policy	Goodwill (Applies to AEP)When the Registrants acquire a business, as defined by the accounting guidance for “Business Combinations,” management recognizes all acquired assets and liabilities at their fair value. To the extent that consideration exceeds the net fair value of the identified assets and liabilities, goodwill is recognized on the balance sheets. Goodwill is not amortized. Management tests acquired goodwill at the reporting unit level for impairment at least annually at its estimated fair value. Fair value is the amount at which an asset or liability could be bought or sold in a current transaction between willing parties other than in a forced or liquidation sale. Quoted market prices in active markets are the best evidence of fair value and are used as the basis for the measurement, if available. In the absence of quoted prices for identical or similar assets in active markets, management estimates fair value using various internal and external valuation methods.
Pension and Other Postretirement Plans	Pension and OPEB Plans (Applies to all Registrants except AEPTCo) AEP sponsors a qualified pension plan and two unfunded non-qualified pension plans. Substantially all AEP employees are covered by the qualified plan or both the qualified and a non-qualified pension plan. AEP also sponsors OPEB plans to provide health and life insurance benefits for retired employees. The Registrant Subsidiaries account for their participation in the AEP sponsored pension and OPEB plans using multiple-employer accounting. See Note 8 - Benefit Plans for additional information including significant accounting policies associated with the plans. AEP sponsors a qualified pension plan and two unfunded non-qualified pension plans. Substantially all AEP employees are covered by the qualified plan or both the qualified and a non-qualified pension plan. AEP also sponsors OPEB plans to provide health and life insurance benefits for retired employees. Due to the Registrant Subsidiaries’ participation in AEP’s benefit plans, the assumptions used by the actuary, with the exception of the rate of compensation increase, and the accounting for the plans by each subsidiary are the same. This section details the assumptions that apply to all Registrants and the rate of compensation increase for each Registrant. The Registrants recognize the funded status associated with defined benefit pension and OPEB plans on the balance sheets. Disclosures about the plans are required by the “Compensation – Retirement Benefits” accounting guidance. The Registrants recognize an asset for a plan’s overfunded status or a liability for a plan’s underfunded status, and recognize, as a component of other comprehensive income, the changes in the funded status of the plan that arise during the year that are not recognized as a component of net periodic benefit cost. The Registrants record a regulatory asset instead of other comprehensive income for qualifying benefit costs of regulated operations that for rate-making purposes are deferred for future recovery. The cumulative funded status adjustment is equal to the remaining unrecognized deferrals for unamortized actuarial losses or gains, prior service costs and transition obligations, such that remaining deferred costs result in an AOCI equity reduction or regulatory asset and deferred gains result in an AOCI equity addition or regulatory liability.
Investments Held in Trust for Future Liabilities	Investments Held in Trust for Future Liabilities (Applies to all Registrants except AEPTCo) AEP has several trust funds with significant investments intended to provide for future payments of pension and OPEB benefits, nuclear decommissioning and SNF disposal. All of the trust funds’ investments are diversified and managed in compliance with all laws and regulations. The investment strategy for the trust funds is to use a diversified portfolio of investments to achieve an acceptable rate of return while managing the investment risk of the assets relative to the associated liabilities. To minimize investment risk, the trust funds are broadly diversified among classes of assets, investment strategies and investment managers. Management regularly reviews the actual asset allocations and periodically rebalances the investments to targeted allocations when appropriate. Investment policies and guidelines allow investment managers in approved strategies to use financial derivatives to obtain or manage market exposures and to hedge assets and liabilities. The investments are reported at fair value under the “Fair Value Measurements and Disclosures” accounting guidance. Benefit Plans All benefit plan assets are invested in accordance with each plan’s investment policy. The investment policy outlines the investment objectives, strategies and target asset allocations by plan. The investment philosophies for AEP’s benefit plans support the allocation of assets to minimize risks and optimize net returns. Strategies used include: • Maintaining a long-term investment horizon. • Diversifying assets to help control volatility of returns at acceptable levels. • Managing fees, transaction costs and tax liabilities to maximize investment earnings. • Using active management of investments where appropriate risk/return opportunities exist. • Keeping portfolio structure style-neutral to limit volatility compared to applicable benchmarks. • Using alternative asset classes such as real estate and private equity to maximize return and provide additional portfolio diversification. The objective of the investment policy for the pension fund is to maintain the funded status of the plan while providing for growth in the plan assets to offset the growth in the plan liabilities. The current target asset allocations are as follows: Pension Plan Assets Target Equity 25 % Fixed Income 59 % Other Investments 15 % Cash and Cash Equivalents 1 % OPEB Plans Assets Target Equity 59 % Fixed Income 40 % Cash and Cash Equivalents 1 % The investment policy for each benefit plan contains various investment limitations. The investment policies establish concentration limits for securities and prohibit the purchase of securities issued by AEP (with the exception of proportionate and immaterial holdings of AEP securities in passive index strategies or certain commingled funds). However, the investment policies do not preclude the benefit trust funds from receiving contributions in the form of AEP securities, provided that the AEP securities acquired by each plan may not exceed the limitations imposed by law. For equity investments, the concentration limits are generally as follows: • No security in excess of 5% of all equities. • Cash equivalents must be less than 10% of an investment manager’s equity portfolio. • No individual stock may be more than 10% and 7% for pension and OPEB investments, respectively, of each manager’s equity portfolio. • No securities may be bought or sold on margin or other use of leverage. For fixed income investments, each investment manager’s portfolio is compared to investment grade, diversified long and intermediate benchmark indices. A portion of the pension assets is invested in real estate funds to provide diversification, add return and hedge against inflation. Real estate properties are illiquid, difficult to value and not actively traded. The pension plan uses external real estate investment managers to invest in commingled funds that hold real estate properties. To mitigate investment risk in the real estate portfolio, commingled real estate funds are used to ensure that holdings are diversified by region, property type and risk classification. Real estate holdings include core, value-added and opportunistic classifications. A portion of the pension assets is invested in private equity. Private equity investments add return and provide diversification and typically require a long-term time horizon to evaluate investment performance. Private equity is classified as an alternative investment because it is illiquid, difficult to value and not actively traded. The pension plan uses limited partnerships to invest across the private equity investment spectrum. The private equity holdings are with multiple general partners who help monitor the investments and provide investment selection expertise. The holdings are currently comprised of venture capital, buyout and hybrid debt and equity investments. AEP participates in a securities lending program with BNY Mellon to provide incremental income on idle assets and to provide income to offset custody fees and other administrative expenses. AEP lends securities to borrowers approved by BNY Mellon in exchange for collateral. All loans are collateralized by at least 102% of the loaned asset’s market value and the collateral is invested. The difference between the rebate owed to the borrower and the collateral rate of return determines the earnings on the loaned security. The securities lending program’s objective is to provide modest incremental income with a limited increase in risk. As of December 31, 2021 and 2020, the fair value of securities on loan as part of the program was $137 million and $177 million, respectively. Cash and securities obtained as collateral exceeded the fair value of the securities loaned as of December 31, 2021 and 2020. Trust owned life insurance (TOLI) underwritten by The Prudential Insurance Company is held in the OPEB plan trusts. The strategy for holding life insurance contracts in the taxable Voluntary Employees’ Beneficiary Association trust is to minimize taxes paid on the asset growth in the trust. Earnings on plan assets are tax-deferred within the TOLI contract and can be tax-free if held until claims are paid. Life insurance proceeds remain in the trust and are used to fund future retiree medical benefit liabilities. With consideration to other investments held in the trust, the cash value of the TOLI contracts is invested in two diversified funds. A portion is invested in a commingled fund with underlying investments in stocks that are actively traded on major international equity exchanges. The other portion of the TOLI cash value is invested in a diversified, commingled fixed income fund with underlying investments in government bonds, corporate bonds and asset-backed securities. Cash and cash equivalents are held in each trust to provide liquidity and meet short-term cash needs. Cash equivalent funds are used to provide diversification and preserve principal. The underlying holdings in the cash
Nuclear Trust Funds	Nuclear Trust Funds (Applies to AEP and I&M) Nuclear decommissioning and SNF trust funds represent funds that regulatory commissions allow I&M to collect through rates to fund future decommissioning and SNF disposal liabilities. By rules or orders, the IURC, the MPSC and the FERC established investment limitations and general risk management guidelines. In general, limitations include: • Acceptable investments (rated investment grade or above when purchased). • Maximum percentage invested in a specific type of investment. • Prohibition of investment in obligations of AEP, I&M or their affiliates. • Withdrawals permitted only for payment of decommissioning costs and trust expenses. I&M maintains trust funds for each regulatory jurisdiction. Regulatory approval is required to withdraw decommissioning funds. These funds are managed by an external investment manager that must comply with the guidelines and rules of the applicable regulatory authorities. The trust assets are invested to optimize the net of tax earnings of the trust giving consideration to liquidity, risk, diversification and other prudent investment objectives. I&M records securities held in these trust funds in Spent Nuclear Fuel and Decommissioning Trusts on its balance sheets. I&M records these securities at fair value. I&M classifies debt securities in the trust funds as available-for-sale due to their long-term purpose. Other-than-temporary impairments for investments in debt securities are considered realized losses as a result of securities being managed by an external investment management firm. The external investment management firm makes specific investment decisions regarding the debt and equity investments held in these trusts and generally intends to sell debt securities in an unrealized loss position as part of a tax optimization strategy. Impairments reduce the cost basis of the securities which will affect any future unrealized gain or realized gain or loss due to the adjusted cost of investment. I&M records unrealized gains, unrealized losses and other-than-temporary impairments from securities in these trust funds as adjustments to the regulatory liability account for the nuclear decommissioning trust funds and to regulatory assets or liabilities for the SNF disposal trust funds in accordance with their treatment in rates. Consequently, changes in fair value of trust assets do not affect earnings or AOCI. See the “Nuclear Contingencies” section of Note 6 for additional discussion of nuclear matters. See “Fair Value Measurements of Trust Assets for Decommissioning and SNF Disposal” section of Note 11 for disclosure of the fair value of assets within the trusts.
Comprehensive Income (Loss)	Comprehensive Income (Loss) (Applies to all Registrants except AEPTCo) Comprehensive income (loss) is defined as the change in equity (net assets) of a business enterprise during a period from transactions and other events and circumstances from non-owner sources. It includes all changes in equity during a period except those resulting from investments by owners and distributions to owners. Comprehensive income (loss) has two components: net income (loss) and other comprehensive income (loss).
Stock-based Compensation	Stock-Based Compensation Plans As of December 31, 2021, AEP had performance shares and restricted stock units outstanding under the American Electric Power System 2015 Long-Term Incentive Plan (2015 LTIP). Upon vesting, all outstanding performance shares and restricted stock units settle in AEP common stock. Performance units awarded prior to 2017 and restricted stock units granted after January 1, 2013 and prior to January 1, 2017 that vested to executive officers were settled in cash. During 2019, all of the remaining performance units and restricted stock units that settle in cash were settled. The impact of AEP’s stock-based compensation plans are insignificant to the financial statements of the Registrant Subsidiaries. AEP maintains a variety of tax qualified and non-qualified deferred compensation plans for employees and non-employee directors that include, among other options, an investment in or an investment return equivalent to that of AEP common stock. This includes AEP career shares maintained under the American Electric Power System Stock Ownership Requirement Plan (SORP), which facilitates executives in meeting minimum stock ownership requirements assigned to them by the Human Resources Committee of the Board of Directors. AEP career shares are derived from vested performance shares granted to employees under the 2015 LTIP and previous long-term incentive plans. AEP career shares accrue additional dividend shares in an amount equal to dividends paid on AEP common shares at the closing market price on the dividend payments date. All AEP career shares are settled in shares of AEP common stock after the executive’s service with AEP ends. Performance shares awarded after January 1, 2017 are classified as temporary equity in the Mezzanine Equity section of the balance sheets until the awards vest. Upon vesting, the performance shares are classified as permanent equity. These awards may be settled in cash upon an employee’s qualifying termination due to a change in control. Because such event is not solely within the control of the company, these awards are classified outside of permanent equity until the awards vest. AEP compensates their non-employee directors, in part, with stock units under the American Electric Power Company, Inc. Stock Unit Accumulation Plan for Non-Employee Directors. These stock units were payable in cash to directors after their service ends. Effective in June 2022, these stock units become payable in AEP common stock rather than cash. Management measures and recognizes compensation expense for all share-based payment awards to employees and directors based on estimated fair values. For share-based payment awards with service only vesting conditions, management recognizes compensation expense on a straight-line basis. Stock-based compensation expense recognized on the statements of income for the years ended December 31, 2021, 2020 and 2019 is based on the number of outstanding awards at the end of each period without a reduction for estimated forfeitures. AEP accounts for forfeitures in the period in which they occur. For the years ended December 31, 2021, 2020 and 2019, compensation cost is included in Net Income for the performance shares, career shares, restricted stock units and the non-employee director stock units. Compensation cost may also be capitalized. See Note 15 - Stock-based Compensation for additional information.
Equity Method Investments	Equity Investment in Unconsolidated Entities (Applies to AEP and SWEPCo) The equity method of accounting is used for equity investments where either AEP or SWEPCo exercise significant influence but do not hold a controlling financial interest. Such investments are initially recorded at cost in Deferred Charges and Other Noncurrent Assets on the balance sheets. The proportionate share of the investee’s equity earnings or losses is included in Equity Earnings (Loss) of Unconsolidated Subsidiaries on the statements of income. AEP and SWEPCo regularly monitor and evaluate equity method investments to determine whether they are impaired. An impairment is recorded when the investment has experienced a decline in value that is other-than-temporary in nature.
Earnings Per Share	Earnings Per Share (EPS) (Applies to AEP) Basic EPS is calculated by dividing net earnings available to common shareholders by the weighted-average number of common shares outstanding during the period. Diluted EPS is calculated by adjusting the weighted-average outstanding common shares, assuming conversion of all potentially dilutive stock awards.

Benefit Plans (Policies)

Benefit Plans (Policies)	12 Months Ended
Benefit Plans (Policies)	Dec. 31, 2021
Pension and Other Postretirement Plans	Pension and OPEB Plans (Applies to all Registrants except AEPTCo) AEP sponsors a qualified pension plan and two unfunded non-qualified pension plans. Substantially all AEP employees are covered by the qualified plan or both the qualified and a non-qualified pension plan. AEP also sponsors OPEB plans to provide health and life insurance benefits for retired employees. The Registrant Subsidiaries account for their participation in the AEP sponsored pension and OPEB plans using multiple-employer accounting. See Note 8 - Benefit Plans for additional information including significant accounting policies associated with the plans. AEP sponsors a qualified pension plan and two unfunded non-qualified pension plans. Substantially all AEP employees are covered by the qualified plan or both the qualified and a non-qualified pension plan. AEP also sponsors OPEB plans to provide health and life insurance benefits for retired employees. Due to the Registrant Subsidiaries’ participation in AEP’s benefit plans, the assumptions used by the actuary, with the exception of the rate of compensation increase, and the accounting for the plans by each subsidiary are the same. This section details the assumptions that apply to all Registrants and the rate of compensation increase for each Registrant. The Registrants recognize the funded status associated with defined benefit pension and OPEB plans on the balance sheets. Disclosures about the plans are required by the “Compensation – Retirement Benefits” accounting guidance. The Registrants recognize an asset for a plan’s overfunded status or a liability for a plan’s underfunded status, and recognize, as a component of other comprehensive income, the changes in the funded status of the plan that arise during the year that are not recognized as a component of net periodic benefit cost. The Registrants record a regulatory asset instead of other comprehensive income for qualifying benefit costs of regulated operations that for rate-making purposes are deferred for future recovery. The cumulative funded status adjustment is equal to the remaining unrecognized deferrals for unamortized actuarial losses or gains, prior service costs and transition obligations, such that remaining deferred costs result in an AOCI equity reduction or regulatory asset and deferred gains result in an AOCI equity addition or regulatory liability.

Derivatives and Hedging (Polici

Derivatives and Hedging (Policies)	12 Months Ended
Derivatives and Hedging (Policies)	Dec. 31, 2021
Derivatives and Hedging	OBJECTIVES FOR UTILIZATION OF DERIVATIVE INSTRUMENTS AEPSC is agent for and transacts on behalf of certain AEP subsidiaries, including the Registrant Subsidiaries. AEPEP is agent for and transacts on behalf of other AEP subsidiaries. The Registrants are exposed to certain market risks as major power producers and participants in the electricity, capacity, natural gas, coal and emission allowance markets. These risks include commodity price risks which may be subject to capacity risk, interest rate risk and credit risk. These risks represent the risk of loss that may impact the Registrants due to changes in the underlying market prices or rates. Management utilizes derivative instruments to manage these risks. STRATEGIES FOR UTILIZATION OF DERIVATIVE INSTRUMENTS TO ACHIEVE OBJECTIVES Risk Management Strategies The strategy surrounding the use of derivative instruments primarily focuses on managing risk exposures, future cash flows and creating value utilizing both economic and formal hedging strategies. The risk management strategies also include the use of derivative instruments for trading purposes which focus on seizing market opportunities to create value driven by expected changes in the market prices of the commodities. To accomplish these objectives, the Registrants primarily employ risk management contracts including physical and financial forward purchase-and-sale contracts and, to a lesser extent, OTC swaps and options. Not all risk management contracts meet the definition of a derivative under the accounting guidance for “Derivatives and Hedging.” Derivative risk management contracts elected normal under the normal purchases and normal sales scope exception are not subject to the requirements of this accounting guidance. The Registrants utilize power, capacity, coal, natural gas, interest rate and, to a lesser extent, heating oil, gasoline and other commodity contracts to manage the risk associated with the energy business. The Registrants utilize interest rate derivative contracts in order to manage the interest rate exposure associated with the commodity portfolio. For disclosure purposes, such risks are grouped as “Commodity,” as these risks are related to energy risk management activities. The Registrants also utilize derivative contracts to manage interest rate risk associated with debt financing. For disclosure purposes, these risks are grouped as “Interest Rate.” The amount of risk taken is determined by the Commercial Operations, Energy Supply and Finance groups in accordance with established risk management policies as approved by the Finance Committee of the Board of Directors. Fair Value Hedging Strategies (Applies to AEP) Parent enters into interest rate derivative transactions as part of an overall strategy to manage the mix of fixed-rate and floating-rate debt. Certain interest rate derivative transactions effectively modify exposure to interest rate risk by converting a portion of fixed-rate debt to a floating-rate. Provided specific criteria are met, these interest rate derivatives may be designated as fair value hedges. Cash Flow Hedging Strategies The Registrants utilize cash flow hedges on certain derivative transactions for the purchase-and-sale of power (“Commodity”) in order to manage the variable price risk related to forecasted purchases and sales. Management monitors the potential impacts of commodity price changes and, where appropriate, enters into derivative transactions to protect profit margins for a portion of future electricity sales and purchases. The Registrants do not hedge all commodity price risk. The Registrants utilize a variety of interest rate derivative transactions in order to manage interest rate risk exposure. The Registrants also utilize interest rate derivative contracts to manage interest rate exposure related to future borrowings of fixed-rate debt. The Registrants do not hedge all interest rate exposure. ACCOUNTING FOR DERIVATIVE INSTRUMENTS AND THE IMPACT ON THE FINANCIAL STATEMENTS The accounting guidance for “Derivatives and Hedging” requires recognition of all qualifying derivative instruments as either assets or liabilities on the balance sheets at fair value. The fair values of derivative instruments accounted for using MTM accounting or hedge accounting are based on exchange prices and broker quotes. If a quoted market price is not available, the estimate of fair value is based on the best information available including valuation models that estimate future energy prices based on existing market and broker quotes and other assumptions. In order to determine the relevant fair values of the derivative instruments, the Registrants apply valuation adjustments for discounting, liquidity and credit quality. Credit risk is the risk that a counterparty will fail to perform on the contract or fail to pay amounts due. Liquidity risk represents the risk that imperfections in the market will cause the price to vary from estimated fair value based upon prevailing market supply and demand conditions. Since energy markets are imperfect and volatile, there are inherent risks related to the underlying assumptions in models used to fair value risk management contracts. Unforeseen events may cause reasonable price curves to differ from actual price curves throughout a contract’s term and at the time a contract settles. Consequently, there could be significant adverse or favorable effects on future net income and cash flows if market prices are not consistent with management’s estimates of current market consensus for forward prices in the current period. This is particularly true for longer term contracts. Cash flows may vary based on market conditions, margin requirements and the timing of settlement of risk management contracts. Certain qualifying derivative instruments have been designated as normal purchase or normal sale contracts, as provided in the accounting guidance for “Derivatives and Hedging.” Derivative contracts that have been designated as normal purchases or normal sales under that accounting guidance are not subject to MTM accounting treatment and are recognized on the statements of income on an accrual basis. The accounting for the changes in the fair value of a derivative instrument depends on whether it qualifies for and has been designated as part of a hedging relationship and further, on the type of hedging relationship. Depending on the exposure, management designates a hedging instrument as a fair value hedge or a cash flow hedge. For contracts that have not been designated as part of a hedging relationship, the accounting for changes in fair value depends on whether the derivative instrument is held for trading purposes. Unrealized and realized gains and losses on derivative instruments held for trading purposes are included in revenues on a net basis on the statements of income. Unrealized and realized gains and losses on derivative instruments not held for trading purposes are included in revenues or expenses on the statements of income depending on the relevant facts and circumstances. Certain derivatives that economically hedge future commodity risk are recorded in the same line item on the statements of income as that of the associated risk being hedged. However, unrealized and some realized gains and losses in regulated jurisdictions for both trading and non-trading derivative instruments are recorded as regulatory assets (for losses) or regulatory liabilities (for gains) in accordance with the accounting guidance for “Regulated Operations.” Accounting for Fair Value Hedging Strategies (Applies to AEP) For fair value hedges (i.e. hedging the exposure to changes in the fair value of an asset, liability or an identified portion thereof attributable to a particular risk), the gain or loss on the derivative instrument as well as the offsetting gain or loss on the hedged item associated with the hedged risk impacts net income during the period of change. AEP records realized and unrealized gains or losses on interest rate swaps that are designated and qualify for fair value hedge accounting treatment and any offsetting changes in the fair value of the debt being hedged in Interest Expense on the statements of income. Accounting for Cash Flow Hedging Strategies (Applies to AEP, APCo, I&M, PSO and SWEPCo) For cash flow hedges (i.e. hedging the exposure to variability in expected future cash flows that is attributable to a particular risk), the Registrants initially report the gain or loss on the derivative instrument as a component of Accumulated Other Comprehensive Income (Loss) on the balance sheets until the period the hedged item affects net income. Credit Risk Management mitigates credit risk in wholesale marketing and trading activities by assessing the creditworthiness of potential counterparties before entering into transactions with them and continuing to evaluate their creditworthiness on an ongoing basis. Management uses credit agency ratings and current market-based qualitative and quantitative data as well as financial statements to assess the financial health of counterparties on an ongoing basis. Master agreements are typically used to facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Collateral requirements in the form of cash, letters of credit, surety bonds and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. Some master agreements include margining, which requires a counterparty to post cash or letters of credit in the event exposure exceeds the established threshold. The threshold represents an unsecured credit limit which may be supported by a parental/affiliate guaranty, as determined in accordance with AEP’s credit policy. In addition, master agreements allow for termination and liquidation of all positions in the event of a default including a failure or inability to post collateral when required. Collateral Triggering Events Credit Downgrade Triggers (Applies to AEP, APCo, I&M, PSO and SWEPCo)

Fair Value Measurements (Polici

Fair Value Measurements (Policies)	12 Months Ended
Fair Value Measurements (Policies)	Dec. 31, 2021
Fair Values of Long-term Debt	The fair values of Long-term Debt are based on quoted market prices, without credit enhancements, for the same or similar issues and the current interest rates offered for instruments with similar maturities classified as Level 2 measurement inputs. These instruments are not marked-to-market. The estimates presented are not necessarily indicative of the amounts that could be realized in a current market exchange. The fair value of AEP’s Equity Units (Level 1) are valued based on publicly-traded securities issued by AEP.
Fair Value Assets And Liabilities Measured On Recurring Basis	As required by the accounting guidance for “Fair Value Measurements and Disclosures,” financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. Management’s assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. There have not been any significant changes in management’s valuation techniques.

Income Taxes (Policies)

Income Taxes (Policies)	12 Months Ended
Income Taxes (Policies)	Dec. 31, 2021
Income Tax Policy	Income Taxes and Investment and Production Tax Credits The Registrants use the liability method of accounting for income taxes. Under the liability method, deferred income taxes are provided for all temporary differences between the book and tax basis of assets and liabilities which will result in a future tax consequence. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which the temporary differences are expected to be recovered or settled. When the flow-through method of accounting for temporary differences is required by a regulator to be reflected in regulated revenues (that is, when deferred taxes are not included in the cost-of-service for determining regulated rates for electricity), deferred income taxes are recorded and related regulatory assets and liabilities are established to match the regulated revenues and tax expense. AEP and subsidiaries apply the deferral methodology for the recognition of ITCs. Deferred ITCs are amortized to income tax expense over the life of the asset that generated the credit. Amortization of deferred ITCs begins when the asset is placed in-service, except where regulatory commissions reflect ITCs in the rate-making process, then amortization begins when the cash tax benefit is recognized. Alternatively, PTCs reduce income tax expense as they are earned. PTCs are earned when electricity is produced. The Registrants account for uncertain tax positions in accordance with the accounting guidance for “Income Taxes.” The Registrants classify interest expense or income related to uncertain tax positions as interest expense or income as appropriate and classify penalties as Other Operation expense on the statements of income. AEP System Tax Allocation Agreement AEP and subsidiaries join in the filing of a consolidated federal income tax return. The allocation of the AEP System’s current consolidated federal income tax to the AEP System companies allocates the benefit of current tax loss of the parent company (Parent Company Loss Benefit) to the AEP System subsidiaries with taxable income reducing their current tax expense proportionately. The consolidated NOL of the AEP System is allocated to each company in the consolidated group with taxable losses. With the exception of the allocation of the consolidated AEP System NOL, the loss of the Parent and tax credits, the method of allocation reflects a separate return result for each company in the consolidated group.

Leases (Policies)

Leases (Policies)	12 Months Ended
Leases (Policies)	Dec. 31, 2021
Lease Policy	Lease obligations are measured using the discount rate implicit in the lease when that rate is readily determinable. AEP has visibility into the rate implicit in the lease when assets are leased from selected financial institutions under master leasing agreements. When the implicit rate is not readily determinable, the Registrants measure their lease obligation using their estimated secured incremental borrowing rate. Incremental borrowing rates are comprised of an underlying risk-free rate and a secured credit spread relative to the lessee on a matched maturity basis.Operating lease rentals and finance lease amortization costs are generally charged to Other Operation and Maintenance expense in accordance with rate-making treatment for regulated operations. The amortization costs related to the Rockport finance lease are charged to Depreciation and Amortization, see “Rockport Lease” below for additional information. Interest on finance lease liabilities is generally charged to Interest Expense. Lease costs associated with capital projects are included in Property, Plant and Equipment on the balance sheets. For regulated operations with finance leases, a finance lease asset and offsetting liability are recorded at the present value of the remaining lease payments for each reporting period. Finance leases for nonregulated property are accounted for as if the assets were owned and financed.

Stock-Based Compensation (Polic

Stock-Based Compensation (Policies)	12 Months Ended
Stock-Based Compensation (Policies)	Dec. 31, 2021
Stock-based Compensation	Stock-Based Compensation Plans As of December 31, 2021, AEP had performance shares and restricted stock units outstanding under the American Electric Power System 2015 Long-Term Incentive Plan (2015 LTIP). Upon vesting, all outstanding performance shares and restricted stock units settle in AEP common stock. Performance units awarded prior to 2017 and restricted stock units granted after January 1, 2013 and prior to January 1, 2017 that vested to executive officers were settled in cash. During 2019, all of the remaining performance units and restricted stock units that settle in cash were settled. The impact of AEP’s stock-based compensation plans are insignificant to the financial statements of the Registrant Subsidiaries. AEP maintains a variety of tax qualified and non-qualified deferred compensation plans for employees and non-employee directors that include, among other options, an investment in or an investment return equivalent to that of AEP common stock. This includes AEP career shares maintained under the American Electric Power System Stock Ownership Requirement Plan (SORP), which facilitates executives in meeting minimum stock ownership requirements assigned to them by the Human Resources Committee of the Board of Directors. AEP career shares are derived from vested performance shares granted to employees under the 2015 LTIP and previous long-term incentive plans. AEP career shares accrue additional dividend shares in an amount equal to dividends paid on AEP common shares at the closing market price on the dividend payments date. All AEP career shares are settled in shares of AEP common stock after the executive’s service with AEP ends. Performance shares awarded after January 1, 2017 are classified as temporary equity in the Mezzanine Equity section of the balance sheets until the awards vest. Upon vesting, the performance shares are classified as permanent equity. These awards may be settled in cash upon an employee’s qualifying termination due to a change in control. Because such event is not solely within the control of the company, these awards are classified outside of permanent equity until the awards vest. AEP compensates their non-employee directors, in part, with stock units under the American Electric Power Company, Inc. Stock Unit Accumulation Plan for Non-Employee Directors. These stock units were payable in cash to directors after their service ends. Effective in June 2022, these stock units become payable in AEP common stock rather than cash. Management measures and recognizes compensation expense for all share-based payment awards to employees and directors based on estimated fair values. For share-based payment awards with service only vesting conditions, management recognizes compensation expense on a straight-line basis. Stock-based compensation expense recognized on the statements of income for the years ended December 31, 2021, 2020 and 2019 is based on the number of outstanding awards at the end of each period without a reduction for estimated forfeitures. AEP accounts for forfeitures in the period in which they occur. For the years ended December 31, 2021, 2020 and 2019, compensation cost is included in Net Income for the performance shares, career shares, restricted stock units and the non-employee director stock units. Compensation cost may also be capitalized. See Note 15 - Stock-based Compensation for additional information.
Stock Based Compensation [Member]
Stock-based Compensation	Awards under AEP’s long-term incentive plan may be granted to employees and directors. The Amended and Restated American Electric Power System Long-Term Incentive Plan (Prior Plan), was replaced prospectively for new grants by the American Electric Power System 2015 Long-Term Incentive Plan (2015 LTIP) effective in April 2015. The 2015 LTIP was subsequently amended in September 2016. The 2015 LTIP provides for a maximum of 10 million AEP common shares to be available for grant to eligible employees and directors. As of December 31, 2021, 5,976,468 shares remained available for issuance under the 2015 LTIP. No new awards may be granted under the Prior Plan. The 2015 LTIP awards may be stock options, stock appreciation rights, restricted stock, restricted stock units, performance shares, performance units, cash-based awards and other stock-based awards. Shares issued pursuant to a stock option or a stock appreciation right reduce the shares remaining available for grants under the 2015 LTIP by 0.286 of a share. Each share issued for any other award that settles in AEP stock reduces the shares remaining available for grants under the 2015 LTIP by one share. Cash settled awards do not reduce the number of shares remaining available under the 2015 LTIP. The following sections provide further information regarding each type of stock-based compensation award granted under these plans.Unrecognized compensation cost related to unvested share-based arrangements will change as the fair value of performance shares is adjusted each period and as forfeitures for all award types are realized. AEP’s unrecognized compensation cost will be recognized over a weighted-average period of 1.39 years.Under the 2015 LTIP, AEP is permitted to use authorized but unissued shares, treasury shares, shares acquired in the open market specifically for distribution under these plans, or any combination thereof to fulfill share commitments. AEP’s current practice is to use authorized but unissued shares to fulfill share commitments. The number of shares used to fulfill share commitments is generally reduced to offset tax withholding obligations.
Performance Units [Member]
Stock-based Compensation	Performance units granted prior to 2017 were settled in cash rather than AEP common stock and did not reduce the number of shares remaining available under the 2015 LTIP. Those performance units had a fair value upon vesting equal to the average closing market price of AEP common stock for the last 20 trading days of the performance period. Performance shares granted in and after 2017 are settled in AEP common stock and reduce the aggregate share authorization. In all cases the number of performance shares held at the end of the three-year performance period is multiplied by the performance score for such period to determine the actual number of performance shares that participants realize. The performance score can range from 0% to 200% and is determined at the end of the performance period based on performance measures, which include both performance and market conditions, established for each grant at the beginning of the performance period by the Human Resources Committee of AEP’s Board of Directors (HR Committee). Certain employees must satisfy a minimum stock ownership requirement. If those employees have not met their stock ownership requirement, a portion or all of their performance shares are mandatorily deferred as AEP career shares to the extent needed to meet their stock ownership requirement. AEP career shares are a form of non-qualified deferred compensation that has a value equivalent to a share of AEP common stock. AEP career shares are settled in AEP common stock after the participant’s termination of employment. AEP career shares are recorded in Paid-in Capital on the balance sheets. Amounts equivalent to cash dividends on both performance shares and AEP career shares accrue as additional shares. Management records compensation cost for performance shares over an approximately three-year vesting period. Performance shares are recorded as mezzanine equity on the balance sheets until the vesting date and compensation cost is calculated at fair value based on metrics for each grant. Performance shares granted in 2021 and 2020 have three performance metrics: (a) three-year cumulative operating earnings per-share with a 50% weight, (b) total shareholder return with a 40% weight and (c) non-emitting generation capacity as a percentage of total owned and purchased capacity with a 10% weight. Performance shares granted in 2019 have two equally-weighted performance metrics: (a) three-year cumulative operating earnings per-share and (b) total shareholder return. The three-year cumulative operating earnings per-share metric and non-emitting generating capacity metric are adjusted quarterly for changes in performance relative to a target approved by the HR Committee. The total shareholder return metric is measured relative to a peer group of similar companies and is based on a third-party Monte Carlo valuation. The value related to this metric does not change over the three-year vesting period.
Restricted Shares and Restricted Stock Units [Member]
Stock-based Compensation	The HR Committee grants restricted stock units (RSUs), which generally vest, subject to the participant’s continued employment, over at least three years in approximately equal annual increments. The RSUs accrue dividends as additional RSUs. The additional RSUs granted as dividends vest on the same date as the underlying RSUs. RSUs are converted into shares of AEP common stock upon vesting, except the RSUs granted prior to 2017 to AEP’s executive officers which settled in cash. Executive officers are those officers who are subject to the disclosure requirements set forth in Section 16 of the Securities Exchange Act of 1934. For RSUs that settle in shares, compensation cost is measured at fair value on the grant date and recorded over the vesting period. Fair value is determined by multiplying the number of RSUs granted by the grant date market closing price. For RSUs that settled in cash, compensation cost was recorded over the vesting period and adjusted for changes in fair value until vested. The fair value at vesting was determined by multiplying the number of RSUs vested by the 20-day average closing price of AEP common stock. The maximum contractual term of outstanding RSUs is approximately 40 months from the grant date.
Stock Unit Accumulation Plan for Non Employee Directors [Member]
Stock-based Compensation	AEP also has a Stock Unit Accumulation Plan for Non-Employee Directors providing each non-employee director with AEP stock units as a substantial portion of the compensation for their services as a director. The number of stock units provided is based on the closing price of AEP common stock on the last trading day of the quarter for which the stock units were earned. Amounts equivalent to cash dividends on the stock units accrue as additional AEP stock units. The stock units granted to non-employee directors are fully vested on their grant date. Stock units are settled in cash upon termination of board service or up to 10 years later if the participant so elects. Cash settlements for stock units are calculated based on the average closing price of AEP common stock for the last 20 trading days prior to the distribution date. Effective in June 2022, these stock units become payable in AEP common stock rather than cash. After five years of service on the Board of Directors, non-employee directors receive subsequent AEP stock units as contributions to an AEP stock fund awarded under the Stock Unit Accumulation Plan. Such amounts may be exchanged into other market-based investments that are similar to the investment options available to employees that participate in AEP’s Incentive Compensation Deferral Plan. These balances are also paid in cash upon termination of board service or up to 10 years later if the participant so elects. Management records compensation cost for stock units when the units are awarded and adjusts the liability for changes in value based on the current 20-day average closing price of AEP common stock on the valuation date.

Variable Interest Entities (Pol

Variable Interest Entities (Policies)	12 Months Ended
Variable Interest Entities (Policies)	Dec. 31, 2021
Variable Interest Entities	The accounting guidance for “Variable Interest Entities” is a consolidation model that considers if a company has a variable interest in a VIE. A VIE is a legal entity that possesses any of the following conditions: the entity’s equity at risk is not sufficient to permit the legal entity to finance its activities without additional subordinated financial support, equity owners are unable to direct the activities that most significantly impact the legal entity’s economic performance (or they possess disproportionate voting rights in relation to the economic interest in the legal entity), or the equity owners lack the obligation to absorb the legal entity’s expected losses or the right to receive the legal entity’s expected residual returns. Entities are required to consolidate a VIE when it is determined that they have a controlling financial interest in a VIE and therefore, are the primary beneficiary of that VIE, as defined by the accounting guidance for “Variable Interest Entities.” In determining whether AEP is the primary beneficiary of a VIE, management considers whether AEP has the power to direct the most significant activities of the VIE and is obligated to absorb losses or receive the expected residual returns that are significant to the VIE. Management believes that significant assumptions and judgments were applied consistently. AEP holds ownership interests in businesses with varying ownership structures. Partnership interests and other variable interests are evaluated to determine if each entity is a VIE, and if so, whether or not the VIE should be consolidated into AEP’s financial statements. AEP has not provided material financial or other support that was not previously contractually required to any of its consolidated VIEs. If an entity is determined not to be a VIE, or if the entity is determined to be a VIE and AEP is not deemed to be the primary beneficiary, the entity is accounted for under the equity method of accounting.

Property, Plant and Equipment (

Property, Plant and Equipment (Policies)	12 Months Ended
Property, Plant and Equipment (Policies)	Dec. 31, 2021
Property, Plant and Equipment	The Registrants provide for depreciation of Property, Plant and Equipment, excluding coal-mining properties, on a straight-line basis over the estimated useful lives of property, generally using composite rates by functional class.SWEPCo provides for depreciation, depletion and amortization of coal-mining assets over each asset’s estimated useful life or the estimated life of each mine, whichever is shorter, using the straight-line method for mining structures and equipment. SWEPCo uses either the straight-line method or the units-of-production method to amortize mine development costs and deplete coal rights based on estimated recoverable tonnages. SWEPCo includes these costs in fuel expense.For regulated operations, the composite depreciation rate generally includes a component for non-ARO removal costs, which is credited to Accumulated Depreciation and Amortization on the balance sheets. Actual removal costs incurred are charged to Accumulated Depreciation and Amortization. Any excess of accrued non-ARO removal costs over actual removal costs incurred is reclassified from Accumulated Depreciation and Amortization and reflected as a regulatory liability. For nonregulated operations, non-ARO removal costs are expensed as incurred.
Asset Retirement Obligations	The Registrants record ARO in accordance with the accounting guidance for “Asset Retirement and Environmental Obligations” for legal obligations for asbestos removal and for the retirement of certain ash disposal facilities, wind farms, solar farms and certain coal-mining facilities. I&M records ARO for the decommissioning of the Cook Plant. The Registrants have identified, but not recognized, ARO liabilities related to electric transmission and distribution assets as a result of certain easements on property on which assets are owned. Generally, such easements are perpetual and require only the retirement and removal of assets upon the cessation of the property’s use. The retirement obligation is not estimable for such easements since the Registrants plan to use their facilities indefinitely. The retirement obligation would only be recognized if and when the Registrants abandon or cease the use of specific easements, which is not expected.

Organization and Summary of S_3

Organization and Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2021
Reconciliation of Cash, Cash Equivalents and Restricted Cash	December 31, 2021 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 403.4 $ 0.1 $ 2.5 Restricted Cash 48.0 30.4 17.6 Total Cash, Cash Equivalents and Restricted Cash $ 451.4 $ 30.5 $ 20.1 December 31, 2020 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 392.7 $ 0.1 $ 5.8 Restricted Cash 45.6 28.7 16.9 Total Cash, Cash Equivalents and Restricted Cash $ 438.3 $ 28.8 $ 22.7
Significant Customers	Significant Customers of AEP Texas: Reliant Energy, Direct Energy and TXU Energy (a) 2021 2020 2019 Percentage of Total Revenues 43 % 46 % 48 % Percentage of Accounts Receivable – Customers 41 % 40 % 43 % (a) In January 2021, NRG Energy, parent company of Reliant Energy, completed a deal to purchase Direct Energy from Centrica. Significant Customers of AEPTCo: AEP Subsidiaries 2021 2020 2019 Percentage of Total Revenues 79 % 78 % 79 % Percentage of Total Accounts Receivable 81 % 78 % 78 %
Target Asset Allocations	Pension Plan Assets Target Equity 25 % Fixed Income 59 % Other Investments 15 % Cash and Cash Equivalents 1 % OPEB Plans Assets Target Equity 59 % Fixed Income 40 % Cash and Cash Equivalents 1 %
Basic and Diluted EPS Calculations	Years Ended December 31, 2021 2020 2019 (in millions, except per-share data) $/share $/share $/share Earnings Attributable to AEP Common Shareholders $ 2,488.1 $ 2,200.1 $ 1,921.1 Weighted-Average Number of Basic AEP Common Shares Outstanding 500.5 $ 4.97 495.7 $ 4.44 493.7 $ 3.89 Weighted-Average Dilutive Effect of Stock-Based Awards 1.3 (0.01) 1.5 (0.02) 1.6 (0.01) Weighted-Average Number of Diluted AEP Common Shares Outstanding 501.8 $ 4.96 497.2 $ 4.42 495.3 $ 3.88
Supplementary Information	2021 Depreciation and Amortization AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Depreciation and Amortization of Property, Plant and Equipment $ 2,717.1 $ 327.2 $ 297.3 $ 547.0 $ 424.9 $ 301.1 $ 185.9 $ 292.9 Amortization of Certain Securitized Assets 64.2 64.2 — — — — — — Amortization of Regulatory Assets and Liabilities 44.4 (4.4) — (0.8) 21.1 2.2 10.7 2.1 Total Depreciation and Amortization $ 2,825.7 $ 387.0 $ 297.3 $ 546.2 $ 446.0 $ 303.3 $ 196.6 $ 295.0 2020 Depreciation and Amortization AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Depreciation and Amortization of Property, Plant and Equipment $ 2,487.5 $ 364.2 $ 249.0 $ 507.8 $ 393.3 $ 275.0 $ 171.9 $ 271.2 Amortization of Certain Securitized Assets 171.3 171.3 — — — — — — Amortization of Regulatory Assets and Liabilities 24.0 (5.7) — (0.3) 18.3 1.6 1.6 1.5 Total Depreciation and Amortization $ 2,682.8 $ 529.8 $ 249.0 $ 507.5 $ 411.6 $ 276.6 $ 173.5 $ 272.7 2019 Depreciation and Amortization AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Depreciation and Amortization of Property, Plant and Equipment $ 2,203.7 $ 365.9 $ 176.0 $ 466.5 $ 330.6 $ 229.4 $ 162.5 $ 247.9 Amortization of Certain Securitized Assets 280.7 258.7 — — — 22.0 — — Amortization of Regulatory Assets and Liabilities 30.1 (2.3) — 0.3 20.0 (10.5) 7.0 1.2 Total Depreciation and Amortization $ 2,514.5 $ 622.3 $ 176.0 $ 466.8 $ 350.6 $ 240.9 $ 169.5 $ 249.1 Years Ended December 31, Cash Flow Information 2021 2020 2019 (in millions) Cash Paid (Received) for: Interest, Net of Capitalized Amounts $ 1,137.2 $ 1,029.1 $ 1,022.5 Income Taxes 13.2 (49.1) 6.1 Noncash Investing and Financing Activities: Acquisitions Under Finance Leases 287.6 44.2 87.5 Construction Expenditures Included in Current Liabilities as of December 31, 1,180.4 975.4 1,341.1 Construction Expenditures Included in Noncurrent Liabilities as of December 31, — 5.5 — Acquisition of Nuclear Fuel Included in Current Liabilities as of December 31, — 33.4 0.1 Expected Reimbursement for Spent Nuclear Fuel Dry Cask Storage 1.7 2.6 0.3 Noncash Contribution of Assets to Cedar Creek Project (9.3) — — Noncontrolling Interest Assumed - Dry Lake Solar Project 35.3 — — Noncontrolling Interest Assumed with Sempra Renewables LLC and Santa Rita East Acquisition — — 253.4 Liabilities Assumed with Sempra Renewable LLC and Santa Rita East Acquisition — — 32.4 Forward Equity Purchase Contracts Included in Current and Noncurrent Liabilities as of December 31, — 110.6 47.3

Comprehensive Income (Tables)

Comprehensive Income (Tables)	12 Months Ended
Comprehensive Income (Tables)	Dec. 31, 2021
Changes in Accumulated Other Comprehensive Income (Loss) by Component	AEP Cash Flow Hedges Pension and OPEB For the Year Ended December 31, 2021 Commodity Interest Rate Amortization of Deferred Costs Changes in Funded Status Total (in millions) Balance in AOCI as of December 31, 2020 $ (60.6) $ (47.5) $ 123.7 $ (100.7) $ (85.1) Change in Fair Value Recognized in AOCI 488.2 21.1 (a) — 27.5 536.8 Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (b) 0.7 — — — 0.7 Purchased Electricity for Resale (b) (334.8) — — — (334.8) Interest Expense (b) — 6.5 — — 6.5 Amortization of Prior Service Cost (Credit) — — (19.4) — (19.4) Amortization of Actuarial (Gains) Losses — — 9.1 — 9.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit (334.1) 6.5 (10.3) — (337.9) Income Tax (Expense) Benefit (70.2) 1.4 (2.2) — (71.0) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (263.9) 5.1 (8.1) — (266.9) Net Current Period Other Comprehensive Income (Loss) 224.3 26.2 (8.1) 27.5 269.9 Balance in AOCI as of December 31, 2021 $ 163.7 $ (21.3) $ 115.6 $ (73.2) $ 184.8 AEP Cash Flow Hedges Pension and OPEB For the Year Ended December 31, 2020 Commodity Interest Rate Amortization of Deferred Costs Changes in Funded Status Total (in millions) Balance in AOCI as of December 31, 2019 $ (103.5) $ (11.5) $ 130.7 $ (163.4) $ (147.7) Change in Fair Value Recognized in AOCI (89.2) (39.9) (a) — 62.7 (66.4) Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (b) (0.4) — — — (0.4) Purchased Electricity for Resale (b) 167.6 — — — 167.6 Interest Expense (b) — 4.9 — — 4.9 Amortization of Prior Service Cost (Credit) — — (19.2) — (19.2) Amortization of Actuarial (Gains) Losses — — 10.3 — 10.3 Reclassifications from AOCI, before Income Tax (Expense) Benefit 167.2 4.9 (8.9) — 163.2 Income Tax (Expense) Benefit 35.1 1.0 (1.9) — 34.2 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 132.1 3.9 (7.0) — 129.0 Net Current Period Other Comprehensive Income (Loss) 42.9 (36.0) (7.0) 62.7 62.6 Balance in AOCI as of December 31, 2020 $ (60.6) $ (47.5) $ 123.7 $ (100.7) $ (85.1) Cash Flow Hedges Pension and OPEB For the Year Ended December 31, 2019 Commodity Interest Rate Amortization of Deferred Costs Changes in Funded Status Total (in millions) Balance in AOCI as of December 31, 2018 $ (23.0) $ (12.6) $ 136.3 $ (221.1) $ (120.4) Change in Fair Value Recognized in AOCI (127.2) (0.2) (a) — 57.7 (69.7) Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (b) (0.2) — — — (0.2) Purchased Electricity for Resale (b) 59.5 — — — 59.5 Interest Expense (b) — 1.5 — — 1.5 Amortization of Prior Service Cost (Credit) — — (19.2) — (19.2) Amortization of Actuarial (Gains) Losses — — 12.1 — 12.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit 59.3 1.5 (7.1) — 53.7 Income Tax (Expense) Benefit 12.6 0.2 (1.5) — 11.3 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 46.7 1.3 (5.6) — 42.4 Net Current Period Other Comprehensive Income (Loss) (80.5) 1.1 (5.6) 57.7 (27.3) Balance in AOCI as of December 31, 2019 $ (103.5) $ (11.5) $ 130.7 $ (163.4) $ (147.7) AEP Texas Pension and OPEB Amortization Changes in Cash Flow Hedge – of Deferred Funded For the Year Ended December 31, 2021 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2020 $ (2.3) $ 5.1 $ (11.7) $ (8.9) Change in Fair Value Recognized in AOCI 0.1 — 1.2 1.3 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.2 — — 1.2 Amortization of Prior Service Cost (Credit) — (0.1) — (0.1) Amortization of Actuarial (Gains) Losses — 0.3 — 0.3 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.2 0.2 — 1.4 Income Tax (Expense) Benefit 0.3 — — 0.3 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.9 0.2 — 1.1 Net Current Period Other Comprehensive Income (Loss) 1.0 0.2 1.2 2.4 Balance in AOCI as of December 31, 2021 $ (1.3) $ 5.3 $ (10.5) $ (6.5) Pension and OPEB Amortization Changes in Cash Flow Hedge – of Deferred Funded For the Year Ended December 31, 2020 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2019 $ (3.4) $ 4.9 $ (14.3) $ (12.8) Change in Fair Value Recognized in AOCI 0.1 — 2.6 2.7 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.3 — — 1.3 Amortization of Prior Service Cost (Credit) — (0.1) — (0.1) Amortization of Actuarial (Gains) Losses — 0.3 — 0.3 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.3 0.2 — 1.5 Income Tax (Expense) Benefit 0.3 — — 0.3 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.0 0.2 — 1.2 Net Current Period Other Comprehensive Income (Loss) 1.1 0.2 2.6 3.9 Balance in AOCI as of December 31, 2020 $ (2.3) $ 5.1 $ (11.7) $ (8.9) Pension and OPEB Amortization Changes in Cash Flow Hedge – of Deferred Funded For the Year Ended December 31, 2019 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2018 $ (4.4) $ 4.7 $ (15.4) $ (15.1) Change in Fair Value Recognized in AOCI — — 1.1 1.1 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.3 — — 1.3 Amortization of Prior Service Cost (Credit) — (0.1) — (0.1) Amortization of Actuarial (Gains) Losses — 0.3 — 0.3 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.3 0.2 — 1.5 Income Tax (Expense) Benefit 0.3 — — 0.3 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.0 0.2 — 1.2 Net Current Period Other Comprehensive Income (Loss) 1.0 0.2 1.1 2.3 Balance in AOCI as of December 31, 2019 $ (3.4) $ 4.9 $ (14.3) $ (12.8) APCo Pension and OPEB Amortization Changes in Cash Flow Hedge – of Deferred Funded For the Year Ended December 31, 2021 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2020 $ (0.8) $ 5.4 $ 2.6 $ 7.2 Change in Fair Value Recognized in AOCI 9.2 — 13.1 22.3 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (1.1) — — (1.1) Amortization of Prior Service Cost (Credit) — (5.3) — (5.3) Reclassifications from AOCI, before Income Tax (Expense) Benefit (1.1) (5.3) — (6.4) Income Tax (Expense) Benefit (0.2) (1.1) — (1.3) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.9) (4.2) — (5.1) Net Current Period Other Comprehensive Income (Loss) 8.3 (4.2) 13.1 17.2 Balance in AOCI as of December 31, 2021 $ 7.5 $ 1.2 $ 15.7 $ 24.4 Pension and OPEB Amortization Changes in Cash Flow Hedges - of Deferred Funded For the Year Ended December 31, 2020 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2019 $ 0.9 $ 9.2 $ (5.1) $ 5.0 Change in Fair Value Recognized in AOCI (0.7) — 7.7 7.0 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (1.3) — — (1.3) Amortization of Prior Service Cost (Credit) — (5.3) — (5.3) Amortization of Actuarial (Gains) Losses — 0.5 — 0.5 Reclassifications from AOCI, before Income Tax (Expense) Benefit (1.3) (4.8) — (6.1) Income Tax (Expense) Benefit (0.3) (1.0) — (1.3) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (1.0) (3.8) — (4.8) Net Current Period Other Comprehensive Income (Loss) (1.7) (3.8) 7.7 2.2 Balance in AOCI as of December 31, 2020 $ (0.8) $ 5.4 $ 2.6 $ 7.2 Pension and OPEB Amortization Changes in Cash Flow Hedges of Deferred Funded For the Year Ended December 31, 2019 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2018 $ 1.8 $ 11.7 $ (18.5) $ (5.0) Change in Fair Value Recognized in AOCI — — 13.4 13.4 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (1.1) — — (1.1) Amortization of Prior Service Cost (Credit) — (5.3) — (5.3) Amortization of Actuarial (Gains) Losses — 2.1 — 2.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit (1.1) (3.2) — (4.3) Income Tax (Expense) Benefit (0.2) (0.7) — (0.9) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.9) (2.5) — (3.4) Net Current Period Other Comprehensive Income (Loss) (0.9) (2.5) 13.4 10.0 Balance in AOCI as of December 31, 2019 $ 0.9 $ 9.2 $ (5.1) $ 5.0 I&M Pension and OPEB Amortization Changes in Cash Flow Hedge – of Deferred Funded For the Year Ended December 31, 2021 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2020 $ (8.3) $ 4.8 $ (3.5) $ (7.0) Change in Fair Value Recognized in AOCI — — 4.2 4.2 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 2.0 — — 2.0 Amortization of Prior Service Cost (Credit) — (0.8) — (0.8) Amortization of Actuarial (Gains) Losses — 0.7 — 0.7 Reclassifications from AOCI, before Income Tax (Expense) Benefit 2.0 (0.1) — 1.9 Income Tax (Expense) Benefit 0.4 — — 0.4 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.6 (0.1) — 1.5 Net Current Period Other Comprehensive Income (Loss) 1.6 (0.1) 4.2 5.7 Balance in AOCI as of December 31, 2021 $ (6.7) $ 4.7 $ 0.7 $ (1.3) Pension and OPEB Amortization Changes in Cash Flow Hedge – of Deferred Funded For the Year Ended December 31, 2020 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2019 $ (9.9) $ 4.9 $ (6.6) $ (11.6) Change in Fair Value Recognized in AOCI — — 3.1 3.1 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 2.0 — — 2.0 Amortization of Prior Service Cost (Credit) — (0.8) — (0.8) Amortization of Actuarial (Gains) Losses — 0.7 — 0.7 Reclassifications from AOCI, before Income Tax (Expense) Benefit 2.0 (0.1) — 1.9 Income Tax (Expense) Benefit 0.4 — — 0.4 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.6 (0.1) — 1.5 Net Current Period Other Comprehensive Income (Loss) 1.6 (0.1) 3.1 4.6 Balance in AOCI as of December 31, 2020 $ (8.3) $ 4.8 $ (3.5) $ (7.0) Pension and OPEB Amortization Changes in Cash Flow Hedge – of Deferred Funded For the Year Ended December 31, 2019 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2018 $ (11.5) $ 5.1 $ (7.4) $ (13.8) Change in Fair Value Recognized in AOCI — — 0.8 0.8 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 2.0 — — 2.0 Amortization of Prior Service Cost (Credit) — (0.8) — (0.8) Amortization of Actuarial (Gains) Losses — 0.6 — 0.6 Reclassifications from AOCI, before Income Tax (Expense) Benefit 2.0 (0.2) — 1.8 Income Tax (Expense) Benefit 0.4 — — 0.4 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.6 (0.2) — 1.4 Net Current Period Other Comprehensive Income (Loss) 1.6 (0.2) 0.8 2.2 Balance in AOCI as of December 31, 2019 $ (9.9) $ 4.9 $ (6.6) $ (11.6) OPCo Cash Flow Hedge – For the Year Ended December 31, 2021 Interest Rate (in millions) Balance in AOCI as of December 31, 2020 $ — Change in Fair Value Recognized in AOCI — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) — Reclassifications from AOCI, before Income Tax (Expense) Benefit — Income Tax (Expense) Benefit — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit — Net Current Period Other Comprehensive Income (Loss) — Balance in AOCI as of December 31, 2021 $ — Cash Flow Hedge – For the Year Ended December 31, 2020 Interest Rate (in millions) Balance in AOCI as of December 31, 2019 $ — Change in Fair Value Recognized in AOCI — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) — Reclassifications from AOCI, before Income Tax (Expense) Benefit — Income Tax (Expense) Benefit — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit — Net Current Period Other Comprehensive Income (Loss) — Balance in AOCI as of December 31, 2020 $ — Cash Flow Hedge – For the Year Ended December 31, 2019 Interest Rate (in millions) Balance in AOCI as of December 31, 2018 $ 1.0 Change in Fair Value Recognized in AOCI — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (1.3) Reclassifications from AOCI, before Income Tax (Expense) Benefit (1.3) Income Tax (Expense) Benefit (0.3) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (1.0) Net Current Period Other Comprehensive Income (Loss) (1.0) Balance in AOCI as of December 31, 2019 $ — PSO Cash Flow Hedge – For the Year Ended December 31, 2021 Interest Rate (in millions) Balance in AOCI as of December 31, 2020 $ 0.1 Change in Fair Value Recognized in AOCI — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (0.1) Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.1) Income Tax (Expense) Benefit — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.1) Net Current Period Other Comprehensive Income (Loss) (0.1) Balance in AOCI as of December 31, 2021 $ — Cash Flow Hedge – For the Year Ended December 31, 2020 Interest Rate (in millions) Balance in AOCI as of December 31, 2019 $ 1.1 Change in Fair Value Recognized in AOCI — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (1.3) Reclassifications from AOCI, before Income Tax (Expense) Benefit (1.3) Income Tax (Expense) Benefit (0.3) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (1.0) Net Current Period Other Comprehensive Income (Loss) (1.0) Balance in AOCI as of December 31, 2020 $ 0.1 Cash Flow Hedge – For the Year Ended December 31, 2019 Interest Rate (in millions) Balance in AOCI as of December 31, 2018 $ 2.1 Change in Fair Value Recognized in AOCI — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (1.3) Reclassifications from AOCI, before Income Tax (Expense) Benefit (1.3) Income Tax (Expense) Benefit (0.3) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (1.0) Net Current Period Other Comprehensive Income (Loss) (1.0) Balance in AOCI as of December 31, 2019 $ 1.1 SWEPCo Pension and OPEB Amortization Changes in Cash Flow Hedge – of Deferred Funded For the Year Ended December 31, 2021 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2020 $ (0.3) $ (2.8) $ 5.0 $ 1.9 Change in Fair Value Recognized in AOCI — — 4.9 4.9 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.9 — — 1.9 Amortization of Prior Service Cost (Credit) — (2.0) — (2.0) Amortization of Actuarial (Gains) Losses — — — — Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.9 (2.0) — (0.1) Income Tax (Expense) Benefit 0.4 (0.4) — — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.5 (1.6) — (0.1) Net Current Period Other Comprehensive Income (Loss) 1.5 (1.6) 4.9 4.8 Balance in AOCI as of December 31, 2021 $ 1.2 $ (4.4) $ 9.9 $ 6.7 Pension and OPEB Amortization Changes in Cash Flow Hedge – of Deferred Funded For the Year Ended December 31, 2020 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2019 $ (1.8) $ (1.3) $ 1.8 $ (1.3) Change in Fair Value Recognized in AOCI — — 3.2 3.2 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.9 — — 1.9 Amortization of Prior Service Cost (Credit) — (2.0) — (2.0) Amortization of Actuarial (Gains) Losses — 0.1 — 0.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.9 (1.9) — — Income Tax (Expense) Benefit 0.4 (0.4) — — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.5 (1.5) — — Net Current Period Other Comprehensive Income (Loss) 1.5 (1.5) 3.2 3.2 Balance in AOCI as of December 31, 2020 $ (0.3) $ (2.8) $ 5.0 $ 1.9 Pension and OPEB Amortization Changes in Cash Flow Hedge – of Deferred Funded For the Year Ended December 31, 2019 Interest Rate Costs Status Total (in millions) Balance in AOCI as of December 31, 2018 $ (3.3) $ (0.2) $ (1.9) $ (5.4) Change in Fair Value Recognized in AOCI — — 3.7 3.7 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.9 — — 1.9 Amortization of Prior Service Cost (Credit) — (2.0) — (2.0) Amortization of Actuarial (Gains) Losses — 0.6 — 0.6 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.9 (1.4) — 0.5 Income Tax (Expense) Benefit 0.4 (0.3) — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.5 (1.1) — 0.4 Net Current Period Other Comprehensive Income (Loss) 1.5 (1.1) 3.7 4.1 Balance in AOCI as of December 31, 2019 $ (1.8) $ (1.3) $ 1.8 $ (1.3) (a) The change in fair value includes $(7) million, $6 million and $4 million related to AEP's investment in joint venture wind farms acquired as part of the purchase of Sempra Renewables LLC for the years ended December 31, 2021, 2020 and 2019, respectively. See “Sempra Renewables LLC” section of Note 17 for additional information. (b) Amounts reclassified to the referenced line item on the statements of income.

Effects of Regulation (Tables)

Effects of Regulation (Tables)	12 Months Ended
Effects of Regulation (Tables)	Dec. 31, 2021
Regulated Generating Units to be Retired	Plant Net Book Value Accelerated Depreciation Regulatory Asset Cost of Removal Projected Current Authorized Annual (dollars in millions) Northeastern Plant, Unit 3 $ 167.2 $ 128.1 $ 20.0 (b) 2026 (c) $ 14.9 Pirkey Power Plant 120.0 87.0 39.3 2023 (d) 13.5 Welsh Plant, Units 1 and 3 475.2 45.9 58.4 (e) 2028 (f) 36.4 (a) Represents the amount of annual depreciation that has been collected from customers over the prior 12-month period. (b) Includes Northeastern Plant, Unit 4, which was retired in 2016. Removal of Northeastern Plant, Unit 4, will be performed with Northeastern Plant, Unit 3, after retirement. (c) Northeastern Plant, Unit 3 is currently being recovered through 2040. (d) Pirkey Power Plant is currently being recovered through 2025 in the Louisiana jurisdiction and through 2045 in the Arkansas and Texas jurisdictions. (e) Includes Welsh Plant, Unit 2, which was retired in 2016. Removal of Welsh Plant, Unit 2, will be performed with Welsh Plant, Units 1 and 3, after retirement.
Regulatory Assets	AEP December 31, Remaining Recovery Period 2021 (a) 2020 Current Regulatory Assets (in millions) Under-recovered Fuel Costs - earns a return $ 409.4 $ 41.4 1 year Under-recovered Fuel Costs - does not earn a return 175.7 49.3 1 year Unrecovered Winter Storm Fuel Costs - earns a return (b) 62.7 — 1 year Total Current Regulatory Assets $ 647.8 $ 90.7 Noncurrent Regulatory Assets Regulatory assets pending final regulatory approval: Regulatory Assets Currently Earning a Return Unrecovered Winter Storm Fuel Costs $ 367.5 $ — Pirkey Power Plant Accelerated Depreciation 87.0 12.2 Dolet Hills Power Station Accelerated Depreciation 72.3 71.2 Welsh Plant, Units 1 and 3 Accelerated Depreciation 45.9 3.6 Plant Retirement Costs - Unrecovered Plant, Louisiana 35.2 35.2 Dolet Hills Power Station Fuel Costs - Louisiana 30.9 — Kentucky Deferred Purchased Power Expenses — 41.3 Oklaunion Power Station Accelerated Depreciation — 34.4 Other Regulatory Assets Pending Final Regulatory Approval 9.2 22.8 Total Regulatory Assets Currently Earning a Return 648.0 220.7 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 256.9 134.2 Plant Retirement Costs - Asset Retirement Obligation Costs 25.9 25.9 COVID-19 11.2 24.9 Other Regulatory Assets Pending Final Regulatory Approval 43.9 36.5 Total Regulatory Assets Currently Not Earning a Return 337.9 221.5 Total Regulatory Assets Pending Final Regulatory Approval 985.9 442.2 Regulatory assets approved for recovery: Regulatory Assets Currently Earning a Return Unrecovered Winter Storm Fuel Costs 679.3 — (c) Plant Retirement Costs - Unrecovered Plant (d) 522.2 713.1 25 years Rockport Plant Dry Sorbent Injection System and Selective Catalytic Reduction 66.6 34.4 7 years Meter Replacement Costs 44.9 55.5 6 years Ohio Distribution Decoupling 41.6 46.6 2 years Environmental Control Projects 36.2 38.6 19 years Cook Plant Uprate Project 27.7 30.2 12 years Storm-Related Costs 17.4 11.5 3 years Plant Retirement Costs - Asset Retirement Obligation Costs — 107.1 Other Regulatory Assets Approved for Recovery 99.2 94.4 various Total Regulatory Assets Currently Earning a Return 1,535.1 1,131.4 Regulatory Assets Currently Not Earning a Return Pension and OPEB Funded Status 677.0 1,088.6 12 years Plant Retirement Costs - Asset Retirement Obligation Costs 293.2 212.7 21 years Unamortized Loss on Reacquired Debt 111.2 120.0 27 years Unrealized Loss on Forward Commitments 100.8 111.3 11 years Plant Retirement Costs - Unrecovered Plant, Texas 51.9 16.1 25 years Peak Demand Reduction/Energy Efficiency 40.8 27.0 5 years Virginia Transmission Rate Adjustment Clause 37.2 18.8 2 years Cook Plant Nuclear Refueling Outage Levelization 32.0 39.5 3 years Texas Transmission Cost Recovery Factor 30.6 4.6 2 years Vegetation Management 29.3 67.8 4 years Postemployment Benefits 29.1 29.1 3 years PJM/SPP Annual Formula Rate True-up 17.6 33.0 2 years Fuel and Purchased Power Adjustment Rider 12.1 24.0 2 years OVEC Purchased Power — 27.4 Other Regulatory Assets Approved for Recovery 158.5 133.5 various Total Regulatory Assets Currently Not Earning a Return 1,621.3 1,953.4 Total Regulatory Assets Approved for Recovery 3,156.4 3,084.8 Total Noncurrent Regulatory Assets $ 4,142.3 $ 3,527.0 (a) 2021 amounts exclude $485 million of regulatory assets classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (b) Unrecovered Winter Storm Fuel Costs are pending final regulatory approval as of December 31, 2021. The current asset balance represents amounts expected to be recovered in the Arkansas and Louisiana jurisdictions over the next 12 months. See “February 2021 Severe Winter Weather Impacts in SPP” section of SWEPCo Rate Matters in Note 4 for additional information. (c) In February 2022, the OCC approved PSO’s securitization of the Unrecovered Winter Storm Fuel Costs. The timing of securitization is to be determined. See ”February 2021 Severe Winter Weather Impacts in SPP” section of PSO Rate Matters in Note 4 for additional information. (d) Northeastern Plant, Unit 3 is approved for recovery through 2040, but expected to retire in 2026. PSO records a regulatory asset for accelerated depreciation. See “Regulated Generating Units to be Retired” section above for additional information. AEP Texas December 31, Remaining Regulatory Assets: 2021 2020 (in millions) Noncurrent Regulatory Assets Regulatory assets pending final regulatory approval: Regulatory Assets Currently Earning a Return Advanced Metering System $ — $ 16.3 Total Regulatory Assets Currently Earning a Return — 16.3 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 22.4 0.8 Vegetation Management Program 5.2 3.8 Texas Retail Electric Provider Bad Debt Expense 4.1 — COVID-19 2.1 10.5 Other Regulatory Assets Pending Final Regulatory Approval 7.4 1.5 Total Regulatory Assets Currently Not Earning a Return 41.2 16.6 Total Regulatory Assets Pending Final Regulatory Approval 41.2 32.9 Regulatory assets approved for recovery: Regulatory Assets Currently Earning a Return Meter Replacement Costs 22.7 29.3 5 years Advanced Metering System 10.6 — 1 year Other Regulatory Assets Approved for Recovery 2.1 — various Total Regulatory Assets Currently Earning a Return 35.4 29.3 Regulatory Assets Currently Not Earning a Return Pension and OPEB Funded Status 119.0 145.0 12 years Texas Transmission Cost Recovery Factor 30.6 4.6 2 years Vegetation Management Program 17.4 22.4 4 years Peak Demand Reduction/Energy Efficiency 14.5 7.7 2 years Storm-Related Costs 12.8 17.1 3 years Other Regulatory Assets Approved for Recovery 4.3 7.8 various Total Regulatory Assets Currently Not Earning a Return 198.6 204.6 Total Regulatory Assets Approved for Recovery 234.0 233.9 Total Noncurrent Regulatory Assets $ 275.2 $ 266.8 AEPTCo December 31, Remaining Regulatory Assets: 2021 2020 (in millions) Noncurrent Regulatory Assets Regulatory assets approved for recovery: Regulatory Assets Currently Not Earning a Return PJM/SPP Annual Formula Rate True-up $ 8.5 $ 15.1 2 years Total Regulatory Assets Approved for Recovery 8.5 15.1 Total Noncurrent Regulatory Assets $ 8.5 $ 15.1 APCo December 31, Remaining Regulatory Assets: 2021 2020 (in millions) Current Regulatory Assets Under-recovered Fuel Costs - earns a return $ 127.2 $ 3.3 1 year Under-recovered Fuel Costs - does not earn a return 74.1 2.0 1 year Total Current Regulatory Assets $ 201.3 $ 5.3 Noncurrent Regulatory Assets Regulatory assets pending final regulatory approval: Regulatory Assets Currently Earning a Return COVID-19 - Virginia $ 6.8 $ 3.7 Total Regulatory Assets Currently Earning a Return 6.8 3.7 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 68.8 3.4 Plant Retirement Costs - Asset Retirement Obligation Costs 25.9 25.9 Environmental Expense Deferral - Virginia — 9.3 Other Regulatory Assets Pending Final Regulatory Approval 3.6 1.5 Total Regulatory Assets Currently Not Earning a Return 98.3 40.1 Total Regulatory Assets Pending Final Regulatory Approval 105.1 43.8 Regulatory assets approved for recovery: Regulatory Assets Currently Earning a Return Plant Retirement Costs - Unrecovered Plant 110.0 122.4 22 years Other Regulatory Assets Approved for Recovery 0.4 1.0 various Total Regulatory Assets Currently Earning a Return 110.4 123.4 Regulatory Assets Currently Not Earning a Return Plant Retirement Costs - Asset Retirement Obligation Costs 293.1 202.7 15 years Unamortized Loss on Reacquired Debt 78.2 82.1 24 years Pension and OPEB Funded Status 62.7 114.4 12 years Virginia Transmission Rate Adjustment Clause 37.2 18.8 2 years Peak Demand Reduction/Energy Efficiency 17.8 16.8 5 years Environmental Compliance Costs 13.7 — 2 years Postemployment Benefits 13.3 13.5 3 years Vegetation Management Program - West Virginia 11.9 45.4 2 years PJM Annual Formula Rate True-up 3.5 12.7 2 years Other Regulatory Assets Approved for Recovery 10.7 12.7 various Total Regulatory Assets Currently Not Earning a Return 542.1 519.1 Total Regulatory Assets Approved for Recovery 652.5 642.5 Total Noncurrent Regulatory Assets $ 757.6 $ 686.3 I&M December 31, Remaining Regulatory Assets: 2021 2020 (in millions) Current Regulatory Assets Under-recovered Fuel Costs, Michigan - earns a return $ 6.4 $ 5.4 1 year Total Current Regulatory Assets $ 6.4 $ 5.4 Noncurrent Regulatory Assets Regulatory assets pending final regulatory approval: Regulatory Assets Currently Earning a Return Other Regulatory Assets Pending Final Regulatory Approval $ 0.1 $ 0.5 Total Regulatory Assets Currently Earning a Return 0.1 0.5 Regulatory Assets Currently Not Earning a Return COVID-19 1.7 3.8 Other Regulatory Assets Pending Final Regulatory Approval 1.9 — Total Regulatory Assets Currently Not Earning a Return (a) 3.6 3.8 Total Regulatory Assets Pending Final Regulatory Approval 3.7 4.3 Regulatory assets approved for recovery: Regulatory Assets Currently Earning a Return Plant Retirement Costs - Unrecovered Plant 170.8 191.5 7 years Rockport Plant Dry Sorbent Injection System and Selective Catalytic Reduction 66.6 34.4 7 years Cook Plant Uprate Project 27.7 30.2 12 years Deferred Cook Plant Life Cycle Management Project Costs 13.1 14.1 13 years Cook Plant Turbine 9.7 11.1 17 years Cook Plant Study Costs - Indiana 9.4 10.1 14 years Other Regulatory Assets Approved for Recovery 6.0 7.0 various Total Regulatory Assets Currently Earning a Return 303.3 298.4 Regulatory Assets Currently Not Earning a Return Cook Plant Nuclear Refueling Outage Levelization 32.0 39.5 3 years PJM Costs and Off-system Sales Margin Sharing - Indiana 15.1 — 2 years Unamortized Loss on Reacquired Debt 14.2 15.7 27 years Storm-Related Costs - Indiana 12.6 0.3 2 years Postemployment Benefits 9.0 4.9 3 years Unrealized Loss on Forward Commitments 7.2 — 3 years Pension and OPEB Funded Status — 25.7 Other Regulatory Assets Approved for Recovery 13.8 16.0 various Total Regulatory Assets Currently Not Earning a Return 103.9 102.1 Total Regulatory Assets Approved for Recovery 407.2 400.5 Total Noncurrent Regulatory Assets $ 410.9 $ 404.8 (a) In February 2022, the IURC issued an order approving Indiana jurisdictional COVID-19 costs and certain other regulatory assets totaling $3 million. See “2021 Indiana Base Rate Case” section of Note 4 for additional information. OPCo December 31, Remaining Regulatory Assets: 2021 2020 (in millions) Noncurrent Regulatory Assets Regulatory assets pending final regulatory approval: Regulatory Assets Currently Not Earning a Return Storm-Related Costs $ 3.8 $ 4.0 COVID-19 — 4.4 Total Regulatory Assets Pending Final Regulatory Approval 3.8 8.4 Regulatory assets approved for recovery: Regulatory Assets Currently Earning a Return Ohio Distribution Decoupling 41.6 46.6 2 years Ohio Economic Development Rider 10.1 1.3 2 years Ohio Basic Transmission Cost Rider 5.2 12.3 2 years Total Regulatory Assets Currently Earning a Return 56.9 60.2 Regulatory Assets Currently Not Earning a Return Unrealized Loss on Forward Commitments 92.1 110.0 11 years Pension and OPEB Funded Status 83.3 130.7 12 years Smart Grid Costs 19.3 19.2 2 years Ohio Enhanced Service Reliability Plan 9.5 — 2 years PJM Load Service Entity Formula Rate True-up 7.5 — 2 years Postemployment Benefits 6.2 6.7 3 years Distribution Investment Rider 2.1 7.4 2 years OVEC Purchased Power — 27.4 Other Regulatory Assets Approved for Recovery 12.3 15.8 various Total Regulatory Assets Currently Not Earning a Return 232.3 317.2 Total Regulatory Assets Approved for Recovery 289.2 377.4 Total Noncurrent Regulatory Assets $ 293.0 $ 385.8 PSO December 31, Remaining 2021 2020 Regulatory Assets: (in millions) Current Regulatory Assets Under-recovered Fuel Costs - earns a return $ 194.6 $ 30.1 1 year Total Current Regulatory Assets $ 194.6 $ 30.1 Noncurrent Regulatory Assets Regulatory assets pending final regulatory approval: Regulatory Assets Currently Earning a Return Oklaunion Power Station Accelerated Depreciation $ — $ 34.4 Total Regulatory Assets Currently Earning a Return — 34.4 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 13.9 15.8 COVID-19 0.3 0.3 Total Regulatory Assets Currently Not Earning a Return 14.2 16.1 Total Regulatory Assets Pending Final Regulatory Approval 14.2 50.5 Regulatory assets approved for recovery: Regulatory Assets Currently Earning a Return Unrecovered Winter Storm Fuel Costs 679.3 — (a) Plant Retirement Costs - Unrecovered Plant (b) 227.6 180.8 25 years Environmental Control Projects 25.2 26.5 19 years Meter Replacement Costs 22.2 26.2 6 years Storm-Related Costs 17.4 11.5 3 years Red Rock Generating Facility 7.9 8.2 35 years Other Regulatory Assets Approved for Recovery 1.9 0.5 various Total Regulatory Assets Currently Earning a Return 981.5 253.7 Regulatory Assets Currently Not Earning a Return Pension and OPEB Funded Status 22.9 52.3 12 years Unamortized Loss on Reacquired Debt 5.7 6.1 17 years Other Regulatory Assets Approved for Recovery 13.1 12.4 various Total Regulatory Assets Currently Not Earning a Return 41.7 70.8 Total Regulatory Assets Approved for Recovery 1,023.2 324.5 Total Noncurrent Regulatory Assets $ 1,037.4 $ 375.0 (a) In February 2022, the OCC approved PSO’s securitization of the Unrecovered Winter Storm Fuel Costs. The timing of securitization is to be determined. See ”February 2021 Severe Winter Weather Impacts in SPP” section of PSO Rate Matters in Note 4 for additional information. (b) Northeastern Plant, Unit 3 is approved for recovery through 2040, but expected to retire in 2026. PSO records a regulatory asset for accelerated depreciation. See “Regulated Generating Units to be Retired” section above for additional information. SWEPCo December 31, Remaining 2021 2020 Regulatory Assets: (in millions) Current Regulatory Assets Under-recovered Fuel Costs - earns a return (a) $ 81.2 $ 2.6 1 year Unrecovered Winter Storm Fuel Costs - earns a return (b) 62.7 — 1 year Total Current Regulatory Assets $ 143.9 $ 2.6 Noncurrent Regulatory Assets Regulatory assets pending final regulatory approval: Regulatory Assets Currently Earning a Return Unrecovered Winter Storm Fuel Costs $ 367.5 $ — Pirkey Power Plant Accelerated Depreciation 87.0 12.2 Dolet Hills Power Station Accelerated Depreciation (c) 72.3 71.2 Welsh Plant, Units 1 and 3 Accelerated Depreciation 45.9 3.6 Plant Retirement Costs - Unrecovered Plant, Louisiana 35.2 35.2 Dolet Hills Power Station Fuel Costs - Louisiana 30.9 — Other Regulatory Assets Pending Final Regulatory Approval 2.4 2.2 Total Regulatory Assets Currently Earning a Return 641.2 124.4 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 148.0 99.3 Asset Retirement Obligation - Louisiana 10.3 9.1 Other Regulatory Assets Pending Final Regulatory Approval 18.4 14.5 Total Regulatory Assets Currently Not Earning a Return 176.7 122.9 Total Regulatory Assets Pending Final Regulatory Approval 817.9 247.3 Regulatory assets approved for recovery: Regulatory Assets Currently Earning a Return Plant Retirement Costs - Unrecovered Plant, Arkansas 13.7 14.4 21 years Environmental Controls Projects 11.0 12.1 11 years Other Regulatory Assets Approved for Recovery 5.2 7.1 various Total Regulatory Assets Currently Earning a Return 29.9 33.6 Regulatory Assets Currently Not Earning a Return Pension and OPEB Funded Status 73.8 89.1 12 years Plant Retirement Costs - Unrecovered Plant, Texas 51.9 16.1 25 years Dolet Hills Power Station Fuel Costs - Arkansas 13.0 — 5 years Other Regulatory Assets Approved for Recovery 18.8 17.0 various Total Regulatory Assets Currently Not Earning a Return 157.5 122.2 Total Regulatory Assets Approved for Recovery 187.4 155.8 Total Noncurrent Regulatory Assets $ 1,005.3 $ 403.1 (a) 2021 amount includes Arkansas, Louisiana and Texas jurisdictions. 2020 amount includes Louisiana jurisdiction. (b) Unrecovered Winter Storm Fuel Costs are pending final regulatory approval as of December 31, 2021. The current asset balance represents amounts expected to be recovered in the Arkansas and Louisiana jurisdictions over the next 12 months. See “February 2021 Severe Winter Weather Impacts in SPP” section of SWEPCo Rate Matters in Note 4 for additional information. (c) 2021 amount includes Arkansas and Louisiana jurisdictions. 2020 amount includes Arkansas, Louisiana and Texas jurisdictions.
Regulatory Liabilities	AEP December 31, Remaining 2021 (a) 2020 Refund Period Current Regulatory Liabilities (in millions) Over-recovered Fuel Costs - pays a return $ — $ 27.6 Over-recovered Fuel Costs - does not pay a return 1.5 25.0 1 year Total Current Regulatory Liabilities $ 1.5 $ 52.6 Noncurrent Regulatory Liabilities and Regulatory liabilities pending final regulatory determination: Regulatory Liabilities Currently Paying a Return Other Regulatory Liabilities Pending Final Regulatory Determination $ — $ 2.5 Total Regulatory Liabilities Currently Paying a Return — 2.5 Regulatory Liabilities Currently Not Paying a Return Other Regulatory Liabilities Pending Final Regulatory Determination 0.2 1.5 Total Regulatory Liabilities Currently Not Paying a Return 0.2 1.5 Income Tax Related Regulatory Liabilities (b) Excess ADIT Associated with Certain Depreciable Property — 291.6 Excess ADIT that is Not Subject to Rate Normalization Requirements (c) (d) 262.2 193.3 Total Income Tax Related Regulatory Liabilities 262.2 484.9 Total Regulatory Liabilities Pending Final Regulatory Determination 262.4 488.9 Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs 3,172.1 3,061.9 (e) Deferred Investment Tax Credits 2.1 4.1 32 years Other Regulatory Liabilities Approved for Payment 33.1 25.2 various Total Regulatory Liabilities Currently Paying a Return 3,207.3 3,091.2 Regulatory Liabilities Currently Not Paying a Return Excess Nuclear Decommissioning Funding 1,939.7 1,476.6 (f) Deferred Investment Tax Credits 248.5 216.7 35 years Spent Nuclear Fuel 49.5 43.1 (f) PJM Transmission Enhancement Refund 42.9 56.2 4 years 2017-2019 Virginia Triennial Revenue Provision 41.6 44.2 27 years Unrealized Gain on Forward Commitments 37.2 11.7 3 years Peak Demand Reduction/Energy Efficiency 28.6 26.3 2 years Transition and Restoration Charges - Texas 26.3 48.2 8 years Other Regulatory Liabilities Approved for Payment 90.9 82.9 various Total Regulatory Liabilities Currently Not Paying a Return 2,505.2 2,005.9 Income Tax Related Regulatory Liabilities (b) Excess ADIT Associated with Certain Depreciable Property 3,556.7 3,485.7 (g) Excess ADIT that is Not Subject to Rate Normalization Requirements 386.5 714.9 7 years Income Taxes Subject to Flow Through (1,231.8) (1,407.9) 52 years Total Income Tax Related Regulatory Liabilities 2,711.4 2,792.7 Total Regulatory Liabilities Approved for Payment 8,423.9 7,889.8 Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits $ 8,686.3 $ 8,378.7 (a) 2021 amounts exclude $148 million of regulatory liabilities classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (b) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (c) 2021 and 2020 amounts include approximately $173 million and $173 million, respectively, related to AEP Transmission Holdco’s investment in ETT and Transource Energy. AEP Transmission Holdco expects to amortize the balance commensurate with the return of Excess ADIT to ETT and Transource Energy’s customers. (d) 2021 amount includes $70 million for Excess ADIT as a result of changes in various state income tax rates. See the “Federal and State Tax Legislation” section of Note 12 for additional information. (e) Relieved as removal costs are incurred. (f) Relieved when plant is decommissioned. (g) Refunded using ARAM. AEP Texas December 31, Remaining Regulatory Liabilities: 2021 2020 (in millions) Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits Regulatory liabilities pending final regulatory determination: Regulatory Liabilities Currently Paying a Return Other Regulatory Liabilities Pending Final Regulatory Determination $ — $ 2.5 Total Regulatory Liabilities Currently Paying a Return — 2.5 Income Tax Related Regulatory Liabilities (a) Excess ADIT that is Not Subject to Rate Normalization Requirements 13.0 (8.2) Total Income Tax Related Regulatory Liabilities 13.0 (8.2) Total Regulatory Liabilities Pending Final Regulatory Determination 13.0 (5.7) Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs 744.7 718.3 (b) Other Regulatory Liabilities Approved for Payment 4.8 5.3 various Total Regulatory Liabilities Currently Paying a Return 749.5 723.6 Regulatory Liabilities Currently Not Paying a Return Transition and Restoration Charges 26.3 48.2 8 years Deferred Investment Tax Credits 6.8 8.5 12 years Other Regulatory Liabilities Approved for Payment 1.1 1.2 various Total Regulatory Liabilities Currently Not Paying a Return 34.2 57.9 Income Tax Related Regulatory Liabilities (a) Excess ADIT Associated with Certain Depreciable Property 498.8 506.0 (c) Excess ADIT that is Not Subject to Rate Normalization Requirements — 41.7 Income Taxes Subject to Flow Through (53.5) (52.7) 35 years Total Income Tax Related Regulatory Liabilities 445.3 495.0 Total Regulatory Liabilities Approved for Payment 1,229.0 1,276.5 Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits $ 1,242.0 $ 1,270.8 (a) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (b) Relieved as removal costs are incurred. (c) Refunded using ARAM. AEPTCo December 31, Remaining Regulatory Liabilities: 2021 (a) 2020 (in millions) Noncurrent Regulatory Liabilities Regulatory liabilities pending final regulatory determination: Income Tax Related Regulatory Liabilities (b) Excess ADIT that is Not Subject to Rate Normalization Requirements (c) $ 8.7 $ — Total Regulatory Liabilities Pending Final Regulatory Determination 8.7 — Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs 271.4 198.6 (d) Total Regulatory Liabilities Currently Paying a Return 271.4 198.6 Income Tax Related Regulatory Liabilities (b) Excess ADIT Associated with Certain Depreciable Property 522.6 531.5 (e) Excess ADIT that is Not Subject to Rate Normalization Requirements (26.2) (30.6) 7 years Income Taxes Subject to Flow Through (132.4) (117.7) 36 years Total Income Tax Related Regulatory Liabilities 364.0 383.2 Total Regulatory Liabilities Approved for Payment 635.4 581.8 Total Noncurrent Regulatory Liabilities $ 644.1 $ 581.8 (a) 2021 amounts exclude $8 million of regulatory liabilities classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (b) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (c) Amount represents regulatory liabilities for Excess ADIT as a result of changes in various state income tax rates. See the “Federal and State Tax Legislation” section of Note 12 for additional information. (d) Relieved as removal costs are incurred. (e) Refunded using ARAM. APCo December 31, Remaining Regulatory Liabilities: 2021 2020 (in millions) Noncurrent Regulatory Liabilities and Regulatory liabilities pending final regulatory determination: Income Tax Related Regulatory Liabilities (a) Excess ADIT that is Not Subject to Rate Normalization Requirements (b) $ 4.5 $ — Total Regulatory Liabilities Pending Final Regulatory Determination 4.5 — Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs 703.3 678.9 (c) Deferred Investment Tax Credits 0.3 0.3 32 years Total Regulatory Liabilities Currently Paying a Return 703.6 679.2 Regulatory Liabilities Currently Not Paying a Return 2017-2019 Virginia Triennial Revenue Provision 41.6 44.2 27 years Unrealized Gain on Forward Commitments 28.2 5.5 3 years PJM Transmission Enhancement Refund 13.0 16.3 4 years Other Regulatory Liabilities Approved for Payment 15.0 6.8 various Total Regulatory Liabilities Currently Not Paying a Return 97.8 72.8 Income Tax Related Regulatory Liabilities (a) Excess ADIT Associated with Certain Depreciable Property 663.6 690.0 (d) Excess ADIT that is Not Subject to Rate Normalization Requirements 83.6 139.1 7 years Income Taxes Subject to Flow Through (314.3) (356.4) 23 years Total Income Tax Related Regulatory Liabilities 432.9 472.7 Total Regulatory Liabilities Approved for Payment 1,234.3 1,224.7 Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits $ 1,238.8 $ 1,224.7 (a) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (b) Amount represents regulatory liabilities for Excess ADIT as a result of a change in the state income tax apportionment formula in West Virginia. See the “Federal and State Tax Legislation” section of Note 12 for additional information. (c) Relieved as removal costs are incurred. (d) Refunded using ARAM. I&M December 31, Remaining Regulatory Liabilities: 2021 2020 (in millions) Current Regulatory Liabilities Over-recovered Fuel Costs, Indiana - does not pay a return $ 1.5 $ 20.8 1 year Total Current Regulatory Liabilities $ 1.5 $ 20.8 Noncurrent Regulatory Liabilities and Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs $ 179.7 $ 168.2 (a) Other Regulatory Liabilities Approved for Payment 21.9 17.4 various Total Regulatory Liabilities Currently Paying a Return 201.6 185.6 Regulatory Liabilities Currently Not Paying a Return Excess Nuclear Decommissioning Funding 1,939.7 1,476.6 (b) Spent Nuclear Fuel 49.5 43.1 (b) Pension OPEB Funded Status 27.6 — 12 years Deferred Investment Tax Credits 22.4 21.3 29 years Rockport Plant, Unit 2 Selective Catalytic Reduction 10.6 8.9 2 years PJM Transmission Enhancement Refund 7.9 9.9 4 years PJM Costs and Off-system Sales Margin Sharing - Indiana — 13.3 Other Regulatory Liabilities Approved for Payment 6.0 28.4 various Total Regulatory Liabilities Currently Not Paying a Return 2,063.7 1,601.5 Income Tax Related Regulatory Liabilities (c) Excess ADIT Associated with Certain Depreciable Property 433.6 450.6 (d) Excess ADIT that is Not Subject to Rate Normalization Requirements 90.2 136.2 3 years Income Taxes Subject to Flow Through (341.2) (332.0) 20 years Total Income Tax Related Regulatory Liabilities 182.6 254.8 Total Regulatory Liabilities Approved for Payment 2,447.9 2,041.9 Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits $ 2,447.9 $ 2,041.9 (a) Relieved as removal costs are incurred. (b) Relieved when plant is decommissioned. (c) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (d) Refunded using ARAM. OPCo December 31, Remaining 2021 2020 Regulatory Liabilities: (in millions) Current Regulatory Liabilities Over-recovered Fuel Costs - does not pay a return $ — $ 3.9 Total Current Regulatory Liabilities $ — $ 3.9 Noncurrent Regulatory Liabilities and Regulatory liabilities pending final regulatory determination: Regulatory Liabilities Currently Not Paying a Return Other Regulatory Liabilities Pending Final Regulatory Determination $ 0.2 $ 0.2 Total Regulatory Liabilities Pending Final Regulatory Determination 0.2 0.2 Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs 467.6 458.4 (a) Total Regulatory Liabilities Currently Paying a Return 467.6 458.4 Regulatory Liabilities Currently Not Paying a Return Peak Demand Reduction/Energy Efficiency 22.5 19.9 2 years PJM Transmission Enhancement Refund 19.6 24.5 4 years Over-recovered Fuel Costs 15.2 — 11 years OVEC Purchased Power 14.8 — 2 years Ohio Enhanced Service Reliability Plan — 5.7 Other Regulatory Liabilities Approved for Payment 0.4 0.7 various Total Regulatory Liabilities Currently Not Paying a Return 72.5 50.8 Income Tax Related Regulatory Liabilities (b) Excess ADIT Associated with Certain Depreciable Property 325.0 334.6 (c) Excess ADIT that is Not Subject to Rate Normalization Requirements 190.8 223.9 7 years Income Taxes Subject to Flow Through (35.2) (62.7) 30 years Total Income Tax Related Regulatory Liabilities 480.6 495.8 Total Regulatory Liabilities Approved for Payment 1,020.7 1,005.0 Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits $ 1,020.9 $ 1,005.2 (a) Relieved as removal costs are incurred. (b) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (c) Refunded using ARAM. PSO December 31, Remaining 2021 2020 Regulatory Liabilities: (in millions) Noncurrent Regulatory Liabilities and Regulatory liabilities pending final regulatory determination: Income Tax Related Regulatory Liabilities (a) Excess ADIT that is Not Subject to Rate Normalization Requirements (b) $ 56.2 $ — Total Regulatory Liabilities Pending Final Regulatory Determination $ 56.2 $ — Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs $ 300.2 $ 289.9 (c) Total Regulatory Liabilities Currently Paying a Return 300.2 289.9 Regulatory Liabilities Currently Not Paying a Return Deferred Investment Tax Credits 50.8 51.0 23 years Other Regulatory Liabilities Approved for Payment 4.3 1.3 various Total Regulatory Liabilities Currently Not Paying a Return 55.1 52.3 Income Tax Related Regulatory Liabilities (a) Excess ADIT Associated with Certain Depreciable Property 389.3 397.0 (d) Excess ADIT that is Not Subject to Rate Normalization Requirements 46.4 71.3 3 years Income Taxes Subject to Flow Through (11.9) (8.3) 28 years Total Income Tax Related Regulatory Liabilities 423.8 460.0 Total Regulatory Liabilities Approved for Payment 779.1 802.2 Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits $ 835.3 $ 802.2 (a) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (b) Amount represents regulatory liabilities for Excess ADIT as a result of a change in the state income tax rate. See the “Federal and State Tax Legislation” section of Note 12 for additional information. (c) Relieved as removal costs are incurred. (d) Refunded using ARAM. SWEPCo December 31, Remaining 2021 2020 Regulatory Liabilities: (in millions) Current Regulatory Liabilities Over-recovered Fuel Costs - pays a return (a) $ — $ 37.6 Total Current Regulatory Liabilities $ — $ 37.6 Noncurrent Regulatory Liabilities and Regulatory liabilities pending final regulatory determination: Income Tax Related Regulatory Liabilities (b) Excess ADIT Associated with Certain Depreciable Property $ — $ 291.6 Excess ADIT that is Not Subject to Rate Normalization Requirements — 21.8 Total Regulatory Liabilities Pending Final Regulatory Determination — 313.4 Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs 461.3 470.9 (c) Other Regulatory Liabilities Approved for Payment 2.4 2.4 various Total Regulatory Liabilities Currently Paying a Return 463.7 473.3 Regulatory Liabilities Currently Not Paying a Return Vegetation Management Costs - Texas 4.8 0.1 2 years Unrealized Gains on Forward Commitments 3.7 0.2 2 years Peak Demand Reduction/Energy Efficiency 2.6 5.2 2 years Other Regulatory Liabilities Approved for Payment 1.9 2.7 various Total Regulatory Liabilities Currently Not Paying a Return 13.0 8.2 Income Tax Related Regulatory Liabilities (b) Excess ADIT Associated with Certain Depreciable Property 609.0 332.5 (d) Excess ADIT that is Not Subject to Rate Normalization Requirements 7.0 11.5 1 year Income Taxes Subject to Flow Through (285.8) (275.5) 27 years Total Income Tax Related Regulatory Liabilities 330.2 68.5 Total Regulatory Liabilities Approved for Payment 806.9 550.0 Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits $ 806.9 $ 863.4 (a) 2020 amount includes Arkansas and Texas jurisdictions. (b) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (c) Relieved as removal costs are incurred. (d) Refunded using ARAM.

Commitments, Guarantees and C_2

Commitments, Guarantees and Contingencies (Tables)	12 Months Ended
Commitments, Guarantees and Contingencies (Tables)	Dec. 31, 2021
Contractual Commitments	Contractual Commitments - AEP Less Than 2-3 Years 4-5 Years After Total (in millions) Fuel Purchase Contracts (a)(b)(c) $ 706.4 $ 584.9 $ 167.8 $ 301.8 $ 1,760.9 Energy and Capacity Purchase Contracts 147.8 309.5 291.7 664.4 1,413.4 Total $ 854.2 $ 894.4 $ 459.5 $ 966.2 $ 3,174.3 Contractual Commitments - APCo Less Than 2-3 Years 4-5 Years After Total (in millions) Fuel Purchase Contracts (a)(c) $ 266.9 $ 171.8 $ 18.7 $ 18.4 $ 475.8 Energy and Capacity Purchase Contracts 40.4 81.8 80.4 150.0 352.6 Total $ 307.3 $ 253.6 $ 99.1 $ 168.4 $ 828.4 Contractual Commitments - I&M Less Than 2-3 Years 4-5 Years After Total (in millions) Fuel Purchase Contracts (a) $ 147.7 $ 245.7 $ 149.1 $ 283.3 $ 825.8 Energy and Capacity Purchase Contracts 167.2 212.6 203.3 305.9 889.0 Total $ 314.9 $ 458.3 $ 352.4 $ 589.2 $ 1,714.8 Contractual Commitments - OPCo Less Than 2-3 Years 4-5 Years After Total (in millions) Energy and Capacity Purchase Contracts $ 34.6 $ 69.1 $ 65.4 $ 180.0 $ 349.1 Contractual Commitments - PSO Less Than 2-3 Years 4-5 Years After Total (in millions) Fuel Purchase Contracts (a) $ 48.2 $ 23.0 $ — $ — $ 71.2 Energy and Capacity Purchase Contracts 32.2 67.3 67.9 125.9 293.3 Total $ 80.4 $ 90.3 $ 67.9 $ 125.9 $ 364.5 Contractual Commitments - SWEPCo Less Than 2-3 Years 4-5 Years After Total (in millions) Fuel Purchase Contracts (a) $ 158.8 $ 91.3 $ — $ — $ 250.1 Energy and Capacity Purchase Contracts 4.2 8.4 8.4 — 21.0 Total $ 163.0 $ 99.7 $ 8.4 $ — $ 271.1 (a) Represents contractual commitments to purchase coal, natural gas, uranium and other consumables as fuel for electric generation along with related transportation of the fuel. (b) Includes $22 million of purchase fuel contracts for KPCo commitments that are expected to occur prior to the anticipated closing of the sale transaction in the second quarter of 2022. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
Maximum Future Payments for Letters of Credit Issued Under the Uncommitted Facilities	Company Amount Maturity (in millions) AEP $ 168.5 January 2022 to December 2022 AEP Texas 2.2 July 2022

Acquisitions, Assets and Liab_2

Acquisitions, Assets and Liabilities Held for Sale, Dispositions and Impairments (Tables)	12 Months Ended
	Dec. 31, 2021
Purchase Price Allocation of an Acquisition [Table Text Block]	Purchase Price Allocation of Sempra Renewables LLC at Acquisition Date - April 22nd, 2019 Assets: Liabilities and Equity: Net Purchase Price (in millions) Current Assets $ 8.8 Current Liabilities $ 12.9 Property, Plant and Equipment 238.1 Asset Retirement Obligations 5.7 Investment in Joint Ventures 404.0 Total Liabilities 18.6 Other Noncurrent Assets 82.9 Noncontrolling Interest 134.8 Total Assets $ 733.8 Liabilities and Noncontrolling Interest $ 153.4 $ 580.4
Assets and Liabilities Held for Sale [Table Text Block]	December 31, 2021 AEP AEPTCo (in millions) ASSETS Accounts Receivable and Accrued Unbilled Revenues $ 33.2 $ 1.5 Fuel, Materials and Supplies 30.6 — Property, Plant and Equipment, Net 2,302.7 165.3 Regulatory Assets 484.7 — Other Classes of Assets that are not Major 68.5 1.1 Assets Held for Sale $ 2,919.7 $ 167.9 LIABILITIES Accounts Payable $ 53.4 $ 1.1 Long-term Debt Due Within One Year 200.0 — Customer Deposits 32.4 — Deferred Income Taxes 441.6 15.4 Long-term Debt 903.1 — Regulatory Liabilities and Deferred Investment Tax Credits 148.1 7.6 Other Classes of Liabilities that are not Major 102.3 3.5 Liabilities Held for Sale $ 1,880.9 $ 27.6

Benefit Plans (Tables)

Benefit Plans (Tables)	12 Months Ended
Benefit Plans (Tables)	Dec. 31, 2021
Health Care Trend Rates	December 31, Health Care Trend Rates 2021 2020 Initial 6.25 % 6.50 % Ultimate 4.50 % 4.50 % Year Ultimate Reached 2029 2029
Reconciliation of Changes in Benefit Obligations and Fair Value of Assets	AEP Pension Plans OPEB 2021 2020 2021 2020 Change in Benefit Obligation (in millions) Benefit Obligation as of January 1, $ 5,544.5 $ 5,236.8 $ 1,210.9 $ 1,225.4 Service Cost 129.2 111.9 9.5 10.0 Interest Cost 137.2 167.9 30.5 39.8 Actuarial (Gain) Loss (173.9) 434.7 (120.1) 39.3 Plan Amendments — — (5.4) (11.4) Benefit Payments (450.0) (406.8) (126.0) (131.0) Participant Contributions — — 41.3 38.2 Medicare Subsidy — — 0.6 0.6 Benefit Obligation as of December 31, $ 5,187.0 $ 5,544.5 $ 1,041.3 $ 1,210.9 Change in Fair Value of Plan Assets Fair Value of Plan Assets as of January 1, $ 5,556.6 $ 5,015.4 $ 1,946.7 $ 1,781.8 Actual Gain on Plan Assets 239.2 832.4 176.5 253.0 Company Contributions (a) 7.1 115.6 5.8 4.7 Participant Contributions — — 41.3 38.2 Benefit Payments (450.0) (406.8) (126.0) (131.0) Fair Value of Plan Assets as of December 31, $ 5,352.9 $ 5,556.6 $ 2,044.3 $ 1,946.7 Funded Status as of December 31, $ 165.9 $ 12.1 $ 1,003.0 $ 735.8 (a) Contributions to the qualified pension plan were $0 and $110 million for the years ended December 31, 2021 and 2020, respectively. Contributions to the non-qualified pension plans were $7 million and $6 million for the years ended December 31, 2021 and 2020, respectively. AEP Texas Pension Plans OPEB 2021 2020 2021 2020 Change in Benefit Obligation (in millions) Benefit Obligation as of January 1, $ 453.2 $ 441.2 $ 96.3 $ 97.8 Service Cost 11.8 10.0 0.7 0.8 Interest Cost 11.2 13.9 2.4 3.2 Actuarial (Gain) Loss (10.9) 28.1 (12.3) 2.4 Plan Amendments — — (0.5) (1.0) Benefit Payments (45.5) (40.0) (9.3) (10.0) Participant Contributions — — 3.2 3.1 Benefit Obligation as of December 31, $ 419.8 $ 453.2 $ 80.5 $ 96.3 Change in Fair Value of Plan Assets Fair Value of Plan Assets as of January 1, $ 474.0 $ 435.1 $ 162.3 $ 148.1 Actual Gain on Plan Assets 16.0 67.2 12.5 21.1 Company Contributions 0.4 11.7 0.1 — Participant Contributions — — 3.2 3.1 Benefit Payments (45.5) (40.0) (9.3) (10.0) Fair Value of Plan Assets as of December 31, $ 444.9 $ 474.0 $ 168.8 $ 162.3 Funded Status as of December 31, $ 25.1 $ 20.8 $ 88.3 $ 66.0 APCo Pension Plans OPEB 2021 2020 2021 2020 Change in Benefit Obligation (in millions) Benefit Obligation as of January 1, $ 670.8 $ 647.2 $ 198.2 $ 203.5 Service Cost 11.9 10.5 1.0 1.0 Interest Cost 16.4 20.3 4.9 6.6 Actuarial (Gain) Loss (28.5) 40.0 (21.4) 5.6 Plan Amendments — — (0.9) (1.8) Benefit Payments (48.9) (47.2) (21.3) (23.2) Participant Contributions — — 6.6 6.3 Medicare Subsidy — — 0.2 0.2 Benefit Obligation as of December 31, $ 621.7 $ 670.8 $ 167.3 $ 198.2 Change in Fair Value of Plan Assets Fair Value of Plan Assets as of January 1, $ 701.3 $ 637.0 $ 293.0 $ 271.0 Actual Gain on Plan Assets 30.9 104.5 21.9 36.8 Company Contributions — 7.0 2.1 2.1 Participant Contributions — — 6.6 6.3 Benefit Payments (48.9) (47.2) (21.3) (23.2) Fair Value of Plan Assets as of December 31, $ 683.3 $ 701.3 $ 302.3 $ 293.0 Funded Status as of December 31, $ 61.6 $ 30.5 $ 135.0 $ 94.8 I&M Pension Plans OPEB 2021 2020 2021 2020 Change in Benefit Obligation (in millions) Benefit Obligation as of January 1, $ 653.3 $ 616.1 $ 141.4 $ 142.9 Service Cost 17.5 15.4 1.3 1.4 Interest Cost 16.2 19.7 3.5 4.7 Actuarial (Gain) Loss (29.5) 44.3 (16.8) 5.1 Plan Amendments — — (0.7) (1.6) Benefit Payments (45.4) (42.2) (15.3) (15.9) Participant Contributions — — 5.2 4.8 Benefit Obligation as of December 31, $ 612.1 $ 653.3 $ 118.6 $ 141.4 Change in Fair Value of Plan Assets Fair Value of Plan Assets as of January 1, $ 698.1 $ 630.5 $ 238.2 $ 216.3 Actual Gain on Plan Assets 28.8 103.3 20.6 33.0 Company Contributions — 6.5 — — Participant Contributions — — 5.2 4.8 Benefit Payments (45.4) (42.2) (15.3) (15.9) Fair Value of Plan Assets as of December 31, $ 681.5 $ 698.1 $ 248.7 $ 238.2 Funded Status as of December 31, $ 69.4 $ 44.8 $ 130.1 $ 96.8 OPCo Pension Plans OPEB 2021 2020 2021 2020 Change in Benefit Obligation (in millions) Benefit Obligation as of January 1, $ 510.3 $ 487.8 $ 126.4 $ 130.2 Service Cost 11.4 9.7 0.8 0.9 Interest Cost 12.5 15.4 3.0 4.2 Actuarial (Gain) Loss (24.1) 33.4 (15.6) 3.1 Plan Amendments — — (0.6) (1.3) Benefit Payments (39.4) (36.0) (13.6) (15.0) Participant Contributions — — 4.5 4.3 Benefit Obligation as of December 31, $ 470.7 $ 510.3 $ 104.9 $ 126.4 Change in Fair Value of Plan Assets Fair Value of Plan Assets as of January 1, $ 543.1 $ 499.1 $ 213.0 $ 197.1 Actual Gain on Plan Assets 21.1 79.9 16.1 26.6 Company Contributions — 0.1 — — Participant Contributions — — 4.5 4.3 Benefit Payments (39.4) (36.0) (13.6) (15.0) Fair Value of Plan Assets as of December 31, $ 524.8 $ 543.1 $ 220.0 $ 213.0 Funded Status as of December 31, $ 54.1 $ 32.8 $ 115.1 $ 86.6 PSO Pension Plans OPEB 2021 2020 2021 2020 Change in Benefit Obligation (in millions) Benefit Obligation as of January 1, $ 279.9 $ 267.5 $ 64.0 $ 64.7 Service Cost 8.0 7.3 0.6 0.7 Interest Cost 6.7 8.5 1.6 2.1 Actuarial (Gain) Loss (17.2) 17.7 (6.8) 1.9 Plan Amendments — — (0.3) (0.7) Benefit Payments (24.8) (21.1) (7.0) (6.8) Participant Contributions — — 2.3 2.1 Benefit Obligation as of December 31, $ 252.6 $ 279.9 $ 54.4 $ 64.0 Change in Fair Value of Plan Assets Fair Value of Plan Assets as of January 1, $ 299.8 $ 276.2 $ 107.8 $ 98.0 Actual Gain on Plan Assets 11.1 44.6 10.9 14.5 Company Contributions 0.1 0.1 — — Participant Contributions — — 2.3 2.1 Benefit Payments (24.8) (21.1) (7.0) (6.8) Fair Value of Plan Assets as of December 31, $ 286.2 $ 299.8 $ 114.0 $ 107.8 Funded Status as of December 31, $ 33.6 $ 19.9 $ 59.6 $ 43.8 SWEPCo Pension Plans OPEB 2021 2020 2021 2020 Change in Benefit Obligation (in millions) Benefit Obligation as of January 1, $ 334.5 $ 314.2 $ 77.1 $ 77.4 Service Cost 11.2 9.9 0.8 0.8 Interest Cost 8.5 10.2 1.9 2.5 Actuarial (Gain) Loss (3.5) 27.4 (9.2) 2.5 Plan Amendments — — (0.4) (0.8) Benefit Payments (33.0) (27.2) (7.6) (7.7) Participant Contributions — — 2.6 2.4 Benefit Obligation as of December 31, $ 317.7 $ 334.5 $ 65.2 $ 77.1 Change in Fair Value of Plan Assets Fair Value of Plan Assets as of January 1, $ 326.9 $ 296.9 $ 129.9 $ 117.2 Actual Gain on Plan Assets 14.3 48.2 11.7 18.0 Company Contributions 0.1 9.0 — — Participant Contributions — — 2.6 2.4 Benefit Payments (33.0) (27.2) (7.6) (7.7) Fair Value of Plan Assets as of December 31, $ 308.3 $ 326.9 $ 136.6 $ 129.9 Funded (Underfunded) Status as of December 31, $ (9.4) $ (7.6) $ 71.4 $ 52.8
Benefit Amounts Recognized on the Balance Sheets	Pension Plans OPEB December 31, AEP 2021 2020 2021 2020 (in millions) Deferred Charges and Other Noncurrent Assets – Prepaid Benefit Costs $ 244.3 $ 93.5 $ 1,040.8 $ 771.9 Other Current Liabilities – Accrued Short-term Benefit Liability (7.6) (6.7) (2.7) (2.4) Employee Benefits and Pension Obligations – Accrued Long-term Benefit Liability (70.8) (74.7) (35.1) (33.7) Funded Status $ 165.9 $ 12.1 $ 1,003.0 $ 735.8 Pension Plans OPEB December 31, AEP Texas 2021 2020 2021 2020 (in millions) Deferred Charges and Other Noncurrent Assets – Prepaid Benefit Costs $ 28.7 $ 24.7 $ 88.3 $ 66.0 Other Current Liabilities – Accrued Short-term Benefit Liability (0.3) (0.4) — — Deferred Credits and Other Noncurrent Liabilities – Accrued Long-term Benefit Liability (3.3) (3.5) — — Funded Status $ 25.1 $ 20.8 $ 88.3 $ 66.0 Pension Plans OPEB December 31, APCo 2021 2020 2021 2020 (in millions) Employee Benefits and Pension Assets – Prepaid Benefit Costs $ 62.4 $ 31.0 $ 158.1 $ 119.1 Other Current Liabilities – Accrued Short-term Benefit Liability — — (1.8) (1.8) Employee Benefits and Pension Obligations – Accrued Long-term Benefit Liability (0.8) (0.5) (21.3) (22.5) Funded Status $ 61.6 $ 30.5 $ 135.0 $ 94.8 Pension Plans OPEB December 31, I&M 2021 2020 2021 2020 (in millions) Deferred Charges and Other Noncurrent Assets – Prepaid Benefit Costs $ 71.4 $ 46.5 $ 130.1 $ 96.8 Other Current Liabilities – Accrued Short-term Benefit Liability (0.1) — — — Deferred Credits and Other Noncurrent Liabilities – Accrued Long-term Benefit Liability (1.9) (1.7) — — Funded Status $ 69.4 $ 44.8 $ 130.1 $ 96.8 Pension Plans OPEB December 31, OPCo 2021 2020 2021 2020 (in millions) Deferred Charges and Other Noncurrent Assets – Prepaid Benefit Costs $ 54.8 $ 33.3 $ 115.1 $ 86.6 Deferred Credits and Other Noncurrent Liabilities – Accrued Long-term Benefit Liability (0.7) (0.5) — — Funded Status $ 54.1 $ 32.8 $ 115.1 $ 86.6 Pension Plans OPEB December 31, PSO 2021 2020 2021 2020 (in millions) Employee Benefits and Pension Assets – Prepaid Benefit Costs $ 35.5 $ 21.9 $ 59.6 $ 43.8 Other Current Liabilities – Accrued Short-term Benefit Liability (0.1) (0.1) — — Deferred Credits and Other Noncurrent Liabilities – Accrued Long-term Benefit Liability (1.8) (1.9) — — Funded Status $ 33.6 $ 19.9 $ 59.6 $ 43.8 Pension Plans OPEB December 31, SWEPCo 2021 2020 2021 2020 (in millions) Deferred Charges and Other Noncurrent Assets – Prepaid Benefit Costs $ — $ — $ 71.4 $ 52.8 Other Current Liabilities – Accrued Short-term Benefit Liability (0.1) (0.1) — — Employee Benefits and Pension Obligations – Accrued Long-term Benefit Liability (9.3) (7.5) — — Funded (Underfunded) Status $ (9.4) $ (7.6) $ 71.4 $ 52.8
Amounts Included in AOCI and Regulatory Assets	AEP Pension Plans OPEB December 31, 2021 2020 2021 2020 Components (in millions) Net Actuarial (Gain) Loss $ 894.7 $ 1,179.6 $ (103.6) $ 101.9 Prior Service Cost (Credit) 0.2 0.2 (161.9) (227.3) Recorded as Regulatory Assets $ 878.0 $ 1,182.4 $ (195.1) $ (99.0) Deferred Income Taxes 3.6 (0.5) (14.7) (5.5) Net of Tax AOCI 13.3 (2.1) (55.7) (20.9) AEP Texas Pension Plans OPEB December 31, 2021 2020 2021 2020 Components (in millions) Net Actuarial (Gain) Loss $ 144.7 $ 160.5 $ (5.2) $ 12.3 Prior Service Credit — — (13.7) (19.3) Recorded as Regulatory Assets $ 136.7 $ 151.3 $ (17.7) $ (6.3) Deferred Income Taxes 1.8 2.0 (0.2) (0.1) Net of Tax AOCI 6.2 7.2 (1.0) (0.6) APCo Pension Plans OPEB December 31, 2021 2020 2021 2020 Components (in millions) Net Actuarial (Gain) Loss $ 83.9 $ 126.3 $ (18.9) $ 11.1 Prior Service Credit — — (23.8) (33.2) Recorded as Regulatory Assets $ 82.5 $ 124.7 $ (19.8) $ (10.3) Deferred Income Taxes 0.3 0.3 (4.9) (2.5) Net of Tax AOCI 1.1 1.3 (18.0) (9.3) I&M Pension Plans OPEB December 31, 2021 2020 2021 2020 Components (in millions) Net Actuarial (Gain) Loss $ (1.6) $ 39.5 $ (10.7) $ 15.6 Prior Service Credit — — (22.1) (31.0) Recorded as Regulatory Assets/Liabilities (a) $ 3.1 $ 40.3 $ (30.7) $ (14.6) Deferred Income Taxes (1.0) (0.1) (0.4) (0.2) Net of Tax AOCI (3.7) (0.7) (1.7) (0.6) (a) Recorded as a Regulatory Liability as of December 31, 2021 and recorded as a Regulatory Asset as of December 31, 2020. OPCo Pension Plans OPEB December 31, 2021 2020 2021 2020 Components (in millions) Net Actuarial (Gain) Loss $ 118.1 $ 150.0 $ (18.5) $ 3.6 Prior Service Credit — — (16.3) (22.9) Recorded as Regulatory Assets $ 118.1 $ 150.0 $ (34.8) $ (19.3) PSO Pension Plans OPEB December 31, 2021 2020 2021 2020 Components (in millions) Net Actuarial (Gain) Loss $ 35.0 $ 55.9 $ (2.1) $ 10.5 Prior Service Credit — — (10.0) (14.1) Recorded as Regulatory Assets $ 35.0 $ 55.9 $ (12.1) $ (3.6) SWEPCo Pension Plans OPEB December 31, 2021 2020 2021 2020 Components (in millions) Net Actuarial (Gain) Loss $ 76.4 $ 86.9 $ (3.5) $ 11.5 Prior Service Credit — — (12.3) (17.2) Recorded as Regulatory Assets $ 76.4 $ 86.9 $ (8.9) $ (3.0) Deferred Income Taxes — — (1.4) (0.5) Net of Tax AOCI — — (5.5) (2.2)
Components of Change in Amounts Included in AOCI and Regulatory Assets	AEP Pension Plans OPEB 2021 2020 2021 2020 Components (in millions) Actuarial Gain During the Year $ (183.4) $ (132.9) $ (205.5) $ (118.0) Amortization of Actuarial Loss (101.5) (93.7) — (5.9) Prior Service Credit — — (5.5) (11.4) Amortization of Prior Service Credit — — 70.9 69.8 Change for the Year Ended December 31, $ (284.9) $ (226.6) $ (140.1) $ (65.5) AEP Texas Pension Plans OPEB 2021 2020 2021 2020 Components (in millions) Actuarial Gain During the Year $ (7.5) $ (16.4) $ (17.5) $ (10.7) Amortization of Actuarial Loss (8.3) (7.8) — (0.5) Prior Service Credit — — (0.4) (1.0) Amortization of Prior Service Credit — — 6.0 5.9 Change for the Year Ended December 31, $ (15.8) $ (24.2) $ (11.9) $ (6.3) APCo Pension Plans OPEB 2021 2020 2021 2020 Components (in millions) Actuarial Gain During the Year $ (30.4) $ (30.8) $ (30.0) $ (16.8) Amortization of Actuarial Loss (12.0) (11.2) — (0.9) Prior Service Credit — — (0.9) (1.8) Amortization of Prior Service Credit — — 10.3 10.2 Change for the Year Ended December 31, $ (42.4) $ (42.0) $ (20.6) $ (9.3) I&M Pension Plans OPEB 2021 2020 2021 2020 Components (in millions) Actuarial Gain During the Year $ (29.4) $ (25.7) $ (26.3) $ (16.4) Amortization of Actuarial Loss (11.7) (10.8) — (0.7) Prior Service Credit — — (0.7) (1.5) Amortization of Prior Service Credit — — 9.6 9.5 Change for the Year Ended December 31, $ (41.1) $ (36.5) $ (17.4) $ (9.1) OPCo Pension Plans OPEB 2021 2020 2021 2020 Components (in millions) Actuarial Gain During the Year $ (22.8) $ (20.2) $ (22.1) $ (12.9) Amortization of Actuarial Loss (9.1) (8.5) — (0.7) Prior Service Credit — — (0.6) (1.3) Amortization of Prior Service Credit — — 7.2 7.0 Change for the Year Ended December 31, $ (31.9) $ (28.7) $ (15.5) $ (7.9) PSO Pension Plans OPEB 2021 2020 2021 2020 Components (in millions) Actuarial Gain During the Year $ (16.0) $ (12.4) $ (12.6) $ (7.4) Amortization of Actuarial Loss (4.9) (4.7) — (0.3) Prior Service Credit — — (0.3) (0.7) Amortization of Prior Service Credit — — 4.4 4.4 Change for the Year Ended December 31, $ (20.9) $ (17.1) $ (8.5) $ (4.0) SWEPCo Pension Plans OPEB 2021 2020 2021 2020 Components (in millions) Actuarial Gain During the Year $ (4.3) $ (5.2) $ (15.0) $ (9.2) Amortization of Actuarial Loss (6.2) (5.7) — (0.4) Prior Service Credit — — (0.4) (0.8) Amortization of Prior Service Credit — — 5.3 5.2 Change for the Year Ended December 31, $ (10.5) $ (10.9) $ (10.1) $ (5.2)
Allocated Assets of Investments	Pension Plan OPEB December 31, Company 2021 2020 2021 2020 AEP Texas 8.3 % 8.5 % 8.3 % 8.3 % APCo 12.8 % 12.6 % 14.8 % 15.1 % I&M 12.7 % 12.6 % 12.2 % 12.2 % OPCo 9.8 % 9.8 % 10.8 % 10.9 % PSO 5.3 % 5.4 % 5.6 % 5.5 % SWEPCo 5.8 % 5.9 % 6.7 % 6.7 %
Accumulated Benefit Obligation	Accumulated Benefit Obligation AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Qualified Pension Plan $ 4,822.5 $ 391.4 $ 597.0 $ 575.2 $ 440.0 $ 232.1 $ 291.4 Nonqualified Pension Plans 69.7 3.3 0.4 1.2 0.3 1.5 1.3 Total as of December 31, 2021 $ 4,892.2 $ 394.7 $ 597.4 $ 576.4 $ 440.3 $ 233.6 $ 292.7 Accumulated Benefit Obligation AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Qualified Pension Plan $ 5,171.3 $ 424.5 $ 645.8 $ 615.8 $ 479.2 $ 258.3 $ 307.1 Nonqualified Pension Plans 72.9 3.6 0.2 0.8 0.2 1.6 1.4 Total as of December 31, 2020 $ 5,244.2 $ 428.1 $ 646.0 $ 616.6 $ 479.4 $ 259.9 $ 308.5
Underfunded Projected Benefit Obligation	AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Projected Benefit Obligation $ 78.4 $ 3.6 $ 0.8 $ 1.9 $ 0.7 $ 1.9 $ 317.7 Fair Value of Plan Assets — — — — — — 308.3 Underfunded Projected Benefit Obligation as of December 31, 2021 $ (78.4) $ (3.6) $ (0.8) $ (1.9) $ (0.7) $ (1.9) $ (9.4) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Projected Benefit Obligation $ 81.4 $ 3.9 $ 0.5 $ 1.7 $ 0.6 $ 2.0 $ 334.5 Fair Value of Plan Assets — — — — — — 326.9 Underfunded Projected Benefit Obligation as of December 31, 2020 $ (81.4) $ (3.9) $ (0.5) $ (1.7) $ (0.6) $ (2.0) $ (7.6)
Underfunded Accumulated Benefit Obligation	AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Accumulated Benefit Obligation $ 69.7 $ 3.3 $ 0.4 $ 1.2 $ 0.3 $ 1.5 $ 1.3 Fair Value of Plan Assets — — — — — — — Underfunded Accumulated Benefit Obligation as of December 31, 2021 $ (69.7) $ (3.3) $ (0.4) $ (1.2) $ (0.3) $ (1.5) $ (1.3) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Accumulated Benefit Obligation $ 72.9 $ 3.6 $ 0.2 $ 0.8 $ 0.2 $ 1.6 $ 1.4 Fair Value of Plan Assets — — — — — — — Underfunded Accumulated Benefit Obligation as of December 31, 2020 $ (72.9) $ (3.6) $ (0.2) $ (0.8) $ (0.2) $ (1.6) $ (1.4)
Estimated Contributions and Payments to the Pension and OPEB Plans	Company Pension Plans OPEB (in millions) AEP $ 133.6 $ 3.4 AEP Texas 5.9 0.1 APCo 1.4 1.8 I&M 1.1 — PSO 0.1 — SWEPCo 6.5 —
Estimated Payments Expected to be Made by the Pension and OPEB Plans	Pension Plans AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) 2022 $ 378.1 $ 36.3 $ 43.9 $ 41.3 $ 35.1 $ 20.3 $ 24.7 2023 380.8 35.9 45.0 40.9 33.7 21.3 25.4 2024 381.1 35.8 45.5 42.1 32.9 20.5 25.5 2025 373.7 34.9 43.1 42.0 33.0 20.4 25.8 2026 373.6 34.7 43.5 42.2 32.4 20.0 27.3 Years 2027 to 2031, in Total 1,722.9 145.5 202.9 201.8 149.1 87.1 112.4 OPEB Benefit Payments AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) 2022 $ 123.9 $ 9.6 $ 20.5 $ 15.2 $ 13.5 $ 7.1 $ 7.7 2023 115.4 9.1 19.1 14.1 12.5 6.7 7.4 2024 119.4 9.8 19.7 14.7 12.9 7.0 7.9 2025 117.9 9.8 19.2 14.5 12.7 7.0 8.0 2026 116.0 9.8 18.8 14.4 12.3 6.8 7.9 Years 2027 to 2031, in Total 545.1 44.7 87.5 66.8 57.1 29.7 37.1 OPEB Medicare AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) 2022 $ 0.2 $ — $ 0.1 $ — $ — $ — $ — 2023 0.3 — 0.1 — — — — 2024 0.3 — 0.1 — — — — 2025 0.3 — 0.1 — — — — 2026 0.3 — 0.1 — — — — Years 2027 to 2031, in Total 1.5 — 0.5 — — — —
Components of Net Periodic Benefit Cost	AEP Pension Plans OPEB Years Ended December 31, 2021 2020 2019 2021 2020 2019 (in millions) Service Cost $ 129.2 $ 111.9 $ 95.5 $ 9.5 $ 10.0 $ 9.5 Interest Cost 137.2 167.9 204.4 30.5 39.8 50.5 Expected Return on Plan Assets (229.7) (264.9) (296.0) (91.1) (95.6) (93.7) Amortization of Prior Service Credit — — — (70.9) (69.8) (69.1) Amortization of Net Actuarial Loss 101.5 93.7 57.6 — 5.9 22.1 Settlements — — — — — — Net Periodic Benefit Cost (Credit) 138.2 108.6 61.5 (122.0) (109.7) (80.7) Capitalized Portion (55.7) (47.0) (38.6) (4.1) (4.2) (3.8) Net Periodic Benefit Cost (Credit) Recognized in Expense $ 82.5 $ 61.6 $ 22.9 $ (126.1) $ (113.9) $ (84.5) AEP Texas Pension Plans OPEB Years Ended December 31, 2021 2020 2019 2021 2020 2019 (in millions) Service Cost $ 11.8 $ 10.0 $ 8.6 $ 0.7 $ 0.8 $ 0.8 Interest Cost 11.2 13.9 17.5 2.4 3.2 4.0 Expected Return on Plan Assets (19.5) (22.7) (25.8) (7.5) (8.0) (7.8) Amortization of Prior Service Credit — — — (6.0) (5.9) (5.9) Amortization of Net Actuarial Loss 8.3 7.8 4.9 — 0.5 1.8 Net Periodic Benefit Cost (Credit) 11.8 9.0 5.2 (10.4) (9.4) (7.1) Capitalized Portion (6.6) (5.5) (4.5) (0.4) (0.4) (0.4) Net Periodic Benefit Cost (Credit) Recognized in Expense $ 5.2 $ 3.5 $ 0.7 $ (10.8) $ (9.8) $ (7.5) APCo Pension Plans OPEB Years Ended December 31, 2021 2020 2019 2021 2020 2019 (in millions) Service Cost $ 11.9 $ 10.5 $ 9.4 $ 1.0 $ 1.0 $ 1.0 Interest Cost 16.4 20.3 25.2 4.9 6.6 8.7 Expected Return on Plan Assets (29.1) (33.6) (37.4) (13.5) (14.4) (14.6) Amortization of Prior Service Credit — — — (10.3) (10.2) (10.1) Amortization of Net Actuarial Loss 12.0 11.2 7.0 — 0.9 3.7 Net Periodic Benefit Cost (Credit) 11.2 8.4 4.2 (17.9) (16.1) (11.3) Capitalized Portion (5.2) (4.5) (4.0) (0.4) (0.4) (0.4) Net Periodic Benefit Cost (Credit) Recognized in Expense $ 6.0 $ 3.9 $ 0.2 $ (18.3) $ (16.5) $ (11.7) I&M Pension Plans OPEB Years Ended December 31, 2021 2020 2019 2021 2020 2019 (in millions) Service Cost $ 17.5 $ 15.4 $ 13.4 $ 1.3 $ 1.4 $ 1.4 Interest Cost 16.2 19.7 23.8 3.5 4.7 5.8 Expected Return on Plan Assets (28.9) (33.3) (36.8) (11.1) (11.7) (11.4) Amortization of Prior Service Credit — — — (9.6) (9.5) (9.4) Amortization of Net Actuarial Loss 11.7 10.8 6.6 — 0.7 2.7 Net Periodic Benefit Cost (Credit) 16.5 12.6 7.0 (15.9) (14.4) (10.9) Capitalized Portion (4.9) (4.3) (3.4) (0.4) (0.4) (0.4) Net Periodic Benefit Cost (Credit) Recognized in Expense $ 11.6 $ 8.3 $ 3.6 $ (16.3) $ (14.8) $ (11.3) OPCo Pension Plans OPEB Years Ended December 31, 2021 2020 2019 2021 2020 2019 (in millions) Service Cost $ 11.4 $ 9.7 $ 7.9 $ 0.8 $ 0.9 $ 0.8 Interest Cost 12.5 15.4 19.1 3.0 4.2 5.5 Expected Return on Plan Assets (22.3) (26.3) (29.3) (9.7) (10.5) (10.8) Amortization of Prior Service Credit — — — (7.2) (7.0) (6.9) Amortization of Net Actuarial Loss 9.1 8.5 5.3 — 0.7 2.5 Net Periodic Benefit Cost (Credit) 10.7 7.3 3.0 (13.1) (11.7) (8.9) Capitalized Portion (6.2) (5.0) (3.7) (0.4) (0.5) (0.4) Net Periodic Benefit Cost (Credit) Recognized in Expense $ 4.5 $ 2.3 $ (0.7) $ (13.5) $ (12.2) $ (9.3) PSO Pension Plans OPEB Years Ended December 31, 2021 2020 2019 2021 2020 2019 (in millions) Service Cost $ 8.0 $ 7.3 $ 6.5 $ 0.6 $ 0.7 $ 0.6 Interest Cost 6.7 8.5 10.6 1.6 2.1 2.6 Expected Return on Plan Assets (12.3) (14.5) (16.3) (5.0) (5.2) (5.1) Amortization of Prior Service Credit — — — (4.4) (4.4) (4.3) Amortization of Net Actuarial Loss 4.9 4.7 2.9 — 0.3 1.2 Net Periodic Benefit Cost (Credit) 7.3 6.0 3.7 (7.2) (6.5) (5.0) Capitalized Portion (3.4) (2.8) (2.4) (0.3) (0.3) (0.2) Net Periodic Benefit Cost (Credit) Recognized in Expense $ 3.9 $ 3.2 $ 1.3 $ (7.5) $ (6.8) $ (5.2) SWEPCo Pension Plans OPEB Years Ended December 31, 2021 2020 2019 2021 2020 2019 (in millions) Service Cost $ 11.2 $ 9.9 $ 8.6 $ 0.8 $ 0.8 $ 0.8 Interest Cost 8.5 10.2 12.4 1.9 2.5 3.1 Expected Return on Plan Assets (13.5) (15.7) (17.7) (6.1) (6.3) (5.9) Amortization of Prior Service Credit — — — (5.3) (5.2) (5.2) Amortization of Net Actuarial Loss 6.2 5.7 3.4 — 0.4 1.4 Net Periodic Benefit Cost (Credit) 12.4 10.1 6.7 (8.7) (7.8) (5.8) Capitalized Portion (4.1) (3.4) (2.9) (0.3) (0.3) (0.3) Net Periodic Benefit Cost (Credit) Recognized in Expense $ 8.3 $ 6.7 $ 3.8 $ (9.0) $ (8.1) $ (6.1)
Cost for Matching Contributions to the Retirement Savings Plans	Year Ended December 31, Company 2021 2020 2019 (in millions) AEP $ 79.9 $ 81.8 $ 76.4 AEP Texas 6.4 6.4 5.9 APCo 7.6 7.7 7.5 I&M 10.9 11.3 11.0 OPCo 7.2 7.3 6.6 PSO 4.6 4.9 4.6 SWEPCo 6.4 6.7 6.2
Benefit Obligations [Member]
Actuarial Assumptions	Pension Plans OPEB December 31, Assumption 2021 2020 2021 2020 Discount Rate 2.90 % 2.50 % 2.90 % 2.55 % Interest Crediting Rate 4.00 % 4.00 % NA NA NA Not applicable. Pension Plans December 31, Assumption – Rate of Compensation Increase (a) 2021 2020 AEP 5.10 % 5.00 % AEP Texas 5.10 % 5.05 % APCo 4.85 % 4.85 % I&M 5.00 % 5.00 % OPCo 5.30 % 5.25 % PSO 5.10 % 5.05 % SWEPCo 4.95 % 4.90 % (a) Rates are for base pay only. In addition, an amount is added to reflect target incentive compensation for exempt employees and overtime and incentive pay for nonexempt employees.
Benefit Costs [Member]
Actuarial Assumptions	Pension Plans OPEB Year Ended December 31, Assumption 2021 2020 2019 2021 2020 2019 Discount Rate 2.50 % 3.25 % 4.30 % 2.55 % 3.30 % 4.30 % Interest Crediting Rate 4.00 % 4.00 % 4.00 % NA NA NA Expected Return on Plan Assets 4.75 % 5.75 % 6.25 % 4.75 % 5.50 % 6.25 % NA Not applicable. Pension Plans Year Ended December 31, Assumption – Rate of Compensation Increase (a) 2021 2020 2019 AEP 5.10 % 5.00 % 4.95 % AEP Texas 5.10 % 5.05 % 5.00 % APCo 4.85 % 4.85 % 4.75 % I&M 5.00 % 5.00 % 4.95 % OPCo 5.30 % 5.25 % 5.20 % PSO 5.10 % 5.05 % 5.05 % SWEPCo 4.95 % 4.90 % 4.90 % (a) Rates are for base pay only. In addition, an amount is added to reflect target incentive compensation for exempt employees and overtime and incentive pay for nonexempt employees.
Pension Plans [Member]
Assets within Fair Value Hierarchy	Asset Class Level 1 Level 2 Level 3 Other Total Year End (in millions) Equities (a): Domestic $ 388.9 $ — $ — $ — $ 388.9 7.2 % International 465.7 — — — 465.7 8.7 % Common Collective Trusts (c) — — — 463.9 463.9 8.7 % Subtotal – Equities 854.6 — — 463.9 1,318.5 24.6 % Fixed Income (a): United States Government and Agency Securities 0.1 1,557.6 — — 1,557.7 29.1 % Corporate Debt — 1,295.9 — — 1,295.9 24.2 % Foreign Debt — 259.4 — — 259.4 4.8 % State and Local Government — 57.1 — — 57.1 1.1 % Other – Asset Backed — 1.3 — — 1.3 — % Subtotal – Fixed Income 0.1 3,171.3 — — 3,171.4 59.2 % Infrastructure (c) — — — 92.1 92.1 1.7 % Real Estate (c) — — — 232.6 232.6 4.4 % Alternative Investments (c) — — — 448.8 448.8 8.4 % Cash and Cash Equivalents (c) — 64.3 — 53.4 117.7 2.2 % Other – Pending Transactions and Accrued Income (b) — — — (28.2) (28.2) (0.5) % Total $ 854.7 $ 3,235.6 $ — $ 1,262.6 $ 5,352.9 100.0 % (a) Includes investment securities loaned to borrowers under the securities lending program. See the “Investments Held in Trust for Future Liabilities” section of Note 1 for additional information. (b) Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement. (c) Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share. Asset Class Level 1 Level 2 Level 3 Other Total Year End (in millions) Equities (a): Domestic $ 542.3 $ — $ — $ — $ 542.3 9.7 % International 676.3 — — — 676.3 12.2 % Common Collective Trusts (c) — — — 650.0 650.0 11.7 % Subtotal – Equities 1,218.6 — — 650.0 1,868.6 33.6 % Fixed Income (a): United States Government and Agency Securities (1.4) 1,134.1 — — 1,132.7 20.4 % Corporate Debt — 1,425.0 — — 1,425.0 25.6 % Foreign Debt — 214.0 — — 214.0 3.9 % State and Local Government — 56.0 — — 56.0 1.0 % Other – Asset Backed — 0.8 — — 0.8 — % Subtotal – Fixed Income (1.4) 2,829.9 — — 2,828.5 50.9 % Infrastructure (c) — — — 91.1 91.1 1.6 % Real Estate (c) — — — 231.6 231.6 4.2 % Alternative Investments (c) — — — 431.8 431.8 7.8 % Cash and Cash Equivalents (c) — 49.3 — 58.2 107.5 1.9 % Other – Pending Transactions and Accrued Income (b) — — — (2.5) (2.5) — % Total $ 1,217.2 $ 2,879.2 $ — $ 1,460.2 $ 5,556.6 100.0 % (a) Includes investment securities loaned to borrowers under the securities lending program. See the “Investments Held in Trust for Future Liabilities” section of Note 1 for additional information. (b) Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement. (c) Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share.
Other Postretirement Benefit Plans [Member]
Assets within Fair Value Hierarchy	Asset Class Level 1 Level 2 Level 3 Other Total Year End (in millions) Equities: Domestic $ 474.0 $ — $ — $ — $ 474.0 23.2 % International 296.3 — — — 296.3 14.5 % Common Collective Trusts (b) — — — 265.0 265.0 13.0 % Subtotal – Equities 770.3 — — 265.0 1,035.3 50.7 % Fixed Income: Common Collective Trust – Debt (b) — — — 167.7 167.7 8.2 % United States Government and Agency Securities — 222.4 — — 222.4 10.9 % Corporate Debt — 233.2 — — 233.2 11.4 % Foreign Debt — 39.8 — — 39.8 2.0 % State and Local Government 91.9 13.6 — — 105.5 5.1 % Subtotal – Fixed Income 91.9 509.0 — 167.7 768.6 37.6 % Trust Owned Life Insurance: International Equities — 23.4 — — 23.4 1.1 % United States Bonds — 171.3 — — 171.3 8.4 % Subtotal – Trust Owned Life Insurance — 194.7 — — 194.7 9.5 % Cash and Cash Equivalents (b) 33.0 — — 6.7 39.7 1.9 % Other – Pending Transactions and Accrued Income (a) — — — 6.0 6.0 0.3 % Total $ 895.2 $ 703.7 $ — $ 445.4 $ 2,044.3 100.0 % (a) Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement. (b) Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share. Asset Class Level 1 Level 2 Level 3 Other Total Year End (in millions) Equities: Domestic $ 399.9 $ — $ — $ — $ 399.9 20.6 % International 290.7 — — — 290.7 14.9 % Common Collective Trusts (b) — — — 264.7 264.7 13.6 % Subtotal – Equities 690.6 — — 264.7 955.3 49.1 % Fixed Income: Common Collective Trust – Debt (b) — — — 186.4 186.4 9.6 % United States Government and Agency Securities (0.2) 199.7 — — 199.5 10.2 % Corporate Debt — 248.7 — — 248.7 12.8 % Foreign Debt — 34.9 — — 34.9 1.8 % State and Local Government 73.9 13.1 — — 87.0 4.5 % Subtotal – Fixed Income 73.7 496.4 — 186.4 756.5 38.9 % Trust Owned Life Insurance: International Equities — 64.8 — — 64.8 3.3 % United States Bonds — 135.9 — — 135.9 7.0 % Subtotal – Trust Owned Life Insurance — 200.7 — — 200.7 10.3 % Cash and Cash Equivalents (b) 26.3 — — 5.7 32.0 1.6 % Other – Pending Transactions and Accrued Income (a) — — — 2.2 2.2 0.1 % Total $ 790.6 $ 697.1 $ — $ 459.0 $ 1,946.7 100.0 % (a) Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement. (b) Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share.

Business Segments (Tables)

Business Segments (Tables)	12 Months Ended
Business Segments (Tables)	Dec. 31, 2021
Reportable Segment Information	Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation & Marketing Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) 2021 Revenues from: External Customers $ 9,852.2 $ 4,464.1 $ 351.1 $ 2,108.3 $ 16.3 $ — $ 16,792.0 Other Operating Segments 146.3 28.8 1,175.1 55.4 55.9 (1,461.5) — Total Revenues $ 9,998.5 $ 4,492.9 $ 1,526.2 $ 2,163.7 $ 72.2 $ (1,461.5) $ 16,792.0 Asset Impairments and Other Related Charges $ 11.6 $ — $ — $ — $ — $ — $ 11.6 Depreciation and Amortization 1,747.6 690.3 306.0 80.9 0.9 — 2,825.7 Interest Expense 574.2 300.9 146.3 15.6 180.8 (18.7) 1,199.1 Income Tax Expense (Benefit) (11.2) 77.5 159.6 (48.8) (61.6) — 115.5 Equity Earnings (Loss) of Unconsolidated Subsidiaries 3.4 — 75.0 (10.6) 23.9 — 91.7 Net Income (Loss) $ 1,116.7 $ 543.4 $ 682.0 $ 210.2 $ (64.2) $ — $ 2,488.1 Gross Property Additions $ 2,963.1 $ 1,766.0 $ 1,468.6 $ 232.8 $ 25.5 $ (29.2) $ 6,426.8 Total Property, Plant and Equipment $ 48,368.9 $ 22,700.7 $ 13,213.0 $ 2,105.4 $ 418.4 $ — $ 86,806.4 Accumulated Depreciation and Amortization 15,471.6 4,102.4 801.8 241.0 188.3 — 20,805.1 Total Property, Plant and Equipment – Net $ 32,897.3 $ 18,598.3 $ 12,411.2 $ 1,864.4 $ 230.1 $ — $ 66,001.3 Total Assets (e) $ 46,974.2 $ 21,120.2 $ 13,873.3 $ 4,263.6 $ 5,846.5 (b) $ (4,409.1) (c) $ 87,668.7 Investments in Equity Method Investees $ 33.5 $ 2.5 $ 830.4 $ 487.8 $ 93.3 $ — $ 1,447.5 Long-term Debt Due Within One Year: Nonaffiliated $ 1,022.4 $ 716.1 $ 106.4 $ — $ 308.9 (d) $ — $ 2,153.8 Long-term Debt: Affiliated 65.0 — — — — (65.0) — Nonaffiliated 12,964.4 7,433.2 4,442.7 — 6,460.4 (d) — 31,300.7 Total Long-term Debt $ 14,051.8 $ 8,149.3 $ 4,549.1 $ — $ 6,769.3 $ (65.0) $ 33,454.5 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation & Marketing Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) 2020 Revenues from: External Customers $ 8,753.2 $ 4,238.7 $ 297.4 $ 1,621.0 $ 8.2 $ — $ 14,918.5 Other Operating Segments 126.2 107.2 901.4 104.6 88.6 (1,328.0) — Total Revenues $ 8,879.4 $ 4,345.9 $ 1,198.8 $ 1,725.6 $ 96.8 $ (1,328.0) $ 14,918.5 Depreciation and Amortization $ 1,600.5 $ 751.1 $ 257.6 $ 72.8 $ 0.8 $ — $ 2,682.8 Interest Expense 565.0 289.2 133.2 24.0 196.4 (42.1) 1,165.7 Income Tax Expense (Benefit) (7.0) 29.7 130.8 (108.0) (5.0) — 40.5 Equity Earnings of Unconsolidated Subsidiaries 2.9 — 82.4 3.2 2.6 — 91.1 Net Income (Loss) $ 1,064.5 $ 496.4 $ 508.5 $ 216.9 $ (89.6) $ — $ 2,196.7 Gross Property Additions $ 2,291.2 $ 2,108.1 $ 1,649.3 $ 197.0 $ 16.0 $ (15.3) $ 6,246.3 Total Property, Plant and Equipment $ 49,023.3 $ 21,145.0 $ 11,827.2 $ 1,910.2 $ 407.3 $ — $ 84,313.0 Accumulated Depreciation and Amortization 15,586.2 3,879.3 595.7 166.1 184.1 — 20,411.4 Total Property, Plant and Equipment – Net $ 33,437.1 $ 17,265.7 $ 11,231.5 $ 1,744.1 $ 223.2 $ — $ 63,901.6 Total Assets $ 42,752.7 $ 19,765.9 $ 12,627.3 $ 3,585.9 $ 5,987.1 (b) $ (3,961.7) (c) $ 80,757.2 Investments in Equity Method Investees $ 37.1 $ 2.1 $ 831.3 $ 467.0 $ 68.8 $ — $ 1,406.3 Long-term Debt Due Within One Year: Nonaffiliated $ 1,034.6 $ 588.8 $ 52.3 $ — $ 410.4 (d) $ — $ 2,086.1 Long-term Debt: Affiliated 65.0 — — — — (65.0) — Nonaffiliated 12,375.6 6,661.9 4,075.7 — 5,873.2 (d) — 28,986.4 Total Long-term Debt $ 13,475.2 $ 7,250.7 $ 4,128.0 $ — $ 6,283.6 $ (65.0) $ 31,072.5 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation & Marketing Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) 2019 Revenues from: External Customers $ 9,245.7 $ 4,319.0 $ 260.2 $ 1,721.8 $ 14.7 $ — $ 15,561.4 Other Operating Segments 121.4 163.5 813.0 135.8 81.1 (1,314.8) — Total Revenues $ 9,367.1 $ 4,482.5 $ 1,073.2 $ 1,857.6 $ 95.8 $ (1,314.8) $ 15,561.4 Asset Impairments and Other Related Charges $ 92.9 $ 32.5 $ — $ 31.0 $ — $ — $ 156.4 Depreciation and Amortization 1,447.0 789.5 183.4 69.5 0.6 24.5 (f) 2,514.5 Interest Expense 568.3 243.3 103.3 30.0 193.7 (66.1) (f) 1,072.5 Income Tax Expense (Benefit) (97.7) (25.2) 136.2 (53.8) 27.6 — (12.9) Equity Earnings (Loss) of Unconsolidated Subsidiaries 3.0 — 72.8 (3.8) 0.1 — 72.1 Net Income (Loss) $ 985.6 $ 451.0 $ 520.1 $ 104.1 $ (141.0) $ — $ 1,919.8 Gross Property Additions $ 2,437.4 $ 2,074.3 $ 1,458.9 $ 1,005.1 $ 14.5 $ (20.4) $ 6,969.8 Total Assets $ 41,228.8 $ 18,757.5 $ 11,143.5 $ 3,123.8 $ 5,440.0 (b) $ (3,801.3) (c)(f) $ 75,892.3 Investments in Equity Method Investees $ 41.7 $ 2.5 $ 787.5 $ 459.5 $ 65.4 $ — $ 1,356.6 Long-term Debt Due Within One Year: Affiliated $ 20.0 $ — $ — $ — $ — $ (20.0) $ — Nonaffiliated 704.7 392.2 — — 501.8 (d) — 1,598.7 Long-term Debt: Affiliated 39.0 — — — — (39.0) — Nonaffiliated 12,162.0 6,248.1 3,593.8 — 3,122.9 (d) — 25,126.8 Total Long-term Debt $ 12,925.7 $ 6,640.3 $ 3,593.8 $ — $ 3,624.7 $ (59.0) $ 26,725.5 (a) Corporate and Other primarily includes the purchasing of receivables from certain AEP utility subsidiaries. This segment also includes Parent’s guarantee revenue received from affiliates, investment income, interest income, interest expense and other nonallocated costs. (b) Includes elimination of AEP Parent’s investments in wholly-owned subsidiary companies. (c) Reconciling Adjustments for Total Assets primarily include elimination of intercompany advances to affiliates and intercompany accounts receivable. (d) Amounts reflect the impact of fair value hedge accounting. See “Accounting for Fair Value Hedging Strategies” section of Note 10 for additional information. (e) Amount includes Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (f) Includes eliminations due to an intercompany finance lease. State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo 2021 (in millions) Revenues from: External Customers $ 315.1 $ — $ — $ 315.1 Sales to AEP Affiliates 1,153.9 — — 1,153.9 Other Revenues 0.3 — — 0.3 Total Revenues $ 1,469.3 $ — $ — $ 1,469.3 Depreciation and Amortization $ 297.3 $ — $ — $ 297.3 Interest Income 0.1 158.1 (157.7) (a) 0.5 Allowance for Equity Funds Used During Construction 67.2 — — 67.2 Interest Expense 141.2 157.7 (157.7) (a) 141.2 Income Tax Expense 144.1 — — 144.1 Net Income $ 591.5 $ 0.2 (b) $ — $ 591.7 Gross Property Additions $ 1,442.7 $ — $ — $ 1,442.7 Total Transmission Property $ 12,708.5 $ — $ — $ 12,708.5 Accumulated Depreciation and Amortization 772.8 — — 772.8 Total Transmission Property - Net $ 11,935.7 $ — $ — $ 11,935.7 Notes Receivable - Affiliated $ — $ 4,343.9 $ (4,343.9) (c) $ — Total Assets (f) $ 12,564.3 $ 4,389.5 (d) $ (4,429.4) (e) $ 12,524.4 Total Long-Term Debt $ 4,390.0 $ 4,343.9 $ (4,390.0) (c) $ 4,343.9 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo 2020 (in millions) Revenues from: External Customers $ 248.8 $ — $ — $ 248.8 Sales to AEP Affiliates 896.3 — — 896.3 Other Revenues 0.6 — — 0.6 Total Revenues $ 1,145.7 $ — $ — $ 1,145.7 Depreciation and Amortization $ 249.0 $ — $ — $ 249.0 Interest Income 0.9 149.6 (148.1) (a) 2.4 Allowance for Equity Funds Used During Construction 74.0 — — 74.0 Interest Expense 127.8 148.1 (148.1) (a) 127.8 Income Tax Expense 106.5 0.2 — 106.7 Net Income $ 422.3 $ 1.1 (b) $ — $ 423.4 Gross Property Additions $ 1,621.9 $ — $ — $ 1,621.9 Total Transmission Property $ 11,345.6 $ — $ — $ 11,345.6 Accumulated Depreciation and Amortization 572.8 — — 572.8 Total Transmission Property - Net $ 10,772.8 $ — $ — $ 10,772.8 Notes Receivable - Affiliated $ — $ 3,948.5 $ (3,948.5) (c) $ — Total Assets $ 11,185.1 $ 4,084.0 (d) $ (4,023.1) (e) $ 11,246.0 Total Long-Term Debt $ 3,990.0 $ 3,948.5 $ (3,990.0) (c) $ 3,948.5 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo 2019 (in millions) Revenues from: External Customers $ 214.6 $ — $ — $ 214.6 Sales to AEP Affiliates 806.7 — — 806.7 Other Revenue 0.1 — — 0.1 Total Revenues $ 1,021.4 $ — $ — $ 1,021.4 Depreciation and Amortization $ 176.0 $ — $ — $ 176.0 Interest Income 1.3 123.8 (122.1) (a) 3.0 Allowance for Equity Funds Used During Construction 84.3 — — 84.3 Interest Expense 97.4 122.1 (122.1) (a) 97.4 Income Tax Expense 117.1 0.3 — 117.4 Net Income $ 438.6 $ 1.1 (b) $ — $ 439.7 Gross Property Additions $ 1,419.5 $ — $ — $ 1,419.5 Total Assets $ 9,865.0 $ 3,519.1 (d) $ (3,493.3) (e) $ 9,890.8 Total Long-Term Debt $ 3,465.0 $ 3,427.3 $ (3,465.0) (c) $ 3,427.3 (a) Elimination of intercompany interest income/interest expense on affiliated debt arrangement. (b) Includes elimination of AEPTCo Parent’s equity earnings in the State Transcos. (c) Elimination of intercompany debt. (d) Includes elimination of AEPTCo Parent’s investments in the State Transcos. (e) Primarily relates to elimination of Notes Receivable from the State Transcos. (f) Amount includes Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.

Derivatives and Hedging (Tables

Derivatives and Hedging (Tables)	12 Months Ended
Derivatives and Hedging (Tables)	Dec. 31, 2021
Notional Volume of Derivative Instruments	December 31, 2021 Primary Risk Unit of AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power MWhs 287.9 — 33.1 13.6 2.7 11.9 3.4 Natural Gas MMBtus 34.1 — — — — 1.3 5.1 Heating Oil and Gasoline Gallons 7.4 1.9 1.1 0.7 1.5 0.8 1.0 Interest Rate USD $ 116.5 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt USD $ 950.0 $ — $ — $ — $ — $ — $ — December 31, 2020 Primary Risk Unit of AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power MWhs 331.3 — 46.9 19.7 3.0 11.9 4.0 Natural Gas MMBtus 26.9 — — — — — 7.9 Heating Oil and Gasoline Gallons 6.9 1.8 1.1 0.6 1.4 0.7 0.9 Interest Rate USD $ 129.8 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt USD $ 1,150.0 $ — $ 200.0 $ — $ — $ — $ —
Fair Value of Derivative Instruments	AEP December 31, 2021 Risk Hedging Contracts Gross Amounts Gross Net Amounts of Balance Sheet Location Commodity (a) Commodity (a) Interest Rate (a) (in millions) Current Risk Management Assets (d) $ 513.4 $ 176.0 $ 1.2 $ 690.6 $ (496.2) $ 194.4 Long-term Risk Management Assets 370.5 89.1 — 459.6 (192.6) 267.0 Total Assets 883.9 265.1 1.2 1,150.2 (688.8) 461.4 Current Risk Management Liabilities (e) 395.7 40.9 — 436.6 (361.2) 75.4 Long-term Risk Management Liabilities 243.9 16.7 38.1 298.7 (68.4) 230.3 Total Liabilities 639.6 57.6 38.1 735.3 (429.6) 305.7 Total MTM Derivative Contract Net Assets (Liabilities) $ 244.3 $ 207.5 $ (36.9) $ 414.9 $ (259.2) $ 155.7 December 31, 2020 Risk Hedging Contracts Gross Amounts Gross Net Amounts of Balance Sheet Location Commodity (a) Commodity (a) Interest Rate (a) (in millions) Current Risk Management Assets $ 239.1 $ 21.1 $ 5.0 $ 265.2 $ (170.5) $ 94.7 Long-term Risk Management Assets 275.9 18.0 — 293.9 (51.7) 242.2 Total Assets 515.0 39.1 5.0 559.1 (222.2) 336.9 Current Risk Management Liabilities 193.0 54.4 3.4 250.8 (172.0) 78.8 Long-term Risk Management Liabilities 222.2 60.1 4.1 286.4 (53.6) 232.8 Total Liabilities 415.2 114.5 7.5 537.2 (225.6) 311.6 Total MTM Derivative Contract Net Assets (Liabilities) $ 99.8 $ (75.4) $ (2.5) $ 21.9 $ 3.4 $ 25.3 AEP Texas December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts - in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 0.6 $ (0.6) $ — Long-term Risk Management Assets — — — Total Assets 0.6 (0.6) — Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — — — Total Liabilities — — — Total MTM Derivative Net Assets (Liabilities) $ 0.6 $ (0.6) $ — December 31, 2020 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts - in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 0.4 $ (0.4) $ — Long-term Risk Management Assets — — — Total Assets 0.4 (0.4) — Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — — — Total Liabilities — — — Total MTM Derivative Net Assets (Liabilities) $ 0.4 $ (0.4) $ — APCo December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts - in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 47.5 $ (5.5) $ 42.0 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets 0.2 (0.2) — Total Assets 47.7 (5.7) 42.0 Other Current Liabilities - Current Risk Management Liabilities 7.2 (6.4) 0.8 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities 0.2 (0.2) — Total Liabilities 7.4 (6.6) 0.8 Total MTM Derivative Net Assets $ 40.3 $ 0.9 $ 41.2 December 31, 2020 Risk Gross Amounts of Risk Gross Amounts Net Amounts of Assets/ Management Hedging Management Offset in the Liabilities Presented in Contracts - Contracts Assets/Liabilities Statement of the Statement of Balance Sheet Location Commodity (a) Interest Rate (a) Recognized Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 38.8 $ 2.4 $ 41.2 $ (18.8) $ 22.4 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets 0.7 — 0.7 (0.6) 0.1 Total Assets 39.5 2.4 41.9 (19.4) 22.5 Other Current Liabilities - Current Risk Management Liabilities 19.7 3.4 23.1 (18.5) 4.6 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities 0.6 — 0.6 (0.5) 0.1 Total Liabilities 20.3 3.4 23.7 (19.0) 4.7 Total MTM Derivative Contract Net Assets (Liabilities) $ 19.2 $ (1.0) $ 18.2 $ (0.4) $ 17.8 I&M December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts - in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 11.1 $ (7.8) $ 3.3 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets 0.2 (0.2) — Total Assets 11.3 (8.0) 3.3 Current Risk Management Liabilities 14.8 (9.8) 5.0 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities 0.2 (0.2) — Total Liabilities 15.0 (10.0) 5.0 Total MTM Derivative Contract Net Assets (Liabilities) $ (3.7) $ 2.0 $ (1.7) December 31, 2020 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts - in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 17.2 $ (13.6) $ 3.6 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets 0.5 (0.4) 0.1 Total Assets 17.7 (14.0) 3.7 Current Risk Management Liabilities 12.1 (12.0) 0.1 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities 0.4 (0.3) 0.1 Total Liabilities 12.5 (12.3) 0.2 Total MTM Derivative Contract Net Assets (Liabilities) $ 5.2 $ (1.7) $ 3.5 OPCo December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts - in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 0.5 $ (0.5) $ — Long-term Risk Management Assets — — — Total Assets 0.5 (0.5) — Current Risk Management Liabilities 6.7 — 6.7 Long-term Risk Management Liabilities 85.8 — 85.8 Total Liabilities 92.5 — 92.5 Total MTM Derivative Contract Net Liabilities $ (92.0) $ (0.5) $ (92.5) December 31, 2020 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts - in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 0.3 $ (0.3) $ — Long-term Risk Management Assets — — — Total Assets 0.3 (0.3) — Current Risk Management Liabilities 8.7 — 8.7 Long-term Risk Management Liabilities 101.6 — 101.6 Total Liabilities 110.3 — 110.3 Total MTM Derivative Contract Net Liabilities $ (110.0) $ (0.3) $ (110.3) PSO December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts - in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 12.4 $ (0.3) $ 12.1 Long-term Risk Management Assets — — — Total Assets 12.4 (0.3) 12.1 Current Risk Management Liabilities 3.7 — 3.7 Long-term Risk Management Liabilities — — — Total Liabilities 3.7 — 3.7 Total MTM Derivative Net Assets (Liabilities) $ 8.7 $ (0.3) $ 8.4 December 31, 2020 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts - in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 10.5 $ (0.2) $ 10.3 Long-term Risk Management Assets — — — Total Assets 10.5 (0.2) 10.3 Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — — — Total Liabilities — — — Total MTM Derivative Net Assets (Liabilities) $ 10.5 $ (0.2) $ 10.3 SWEPCo December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts - in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 10.1 $ (0.3) $ 9.8 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets 1.1 — 1.1 Total Assets 11.2 (0.3) 10.9 Current Risk Management Liabilities 2.1 — 2.1 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities — — — Total Liabilities 2.1 — 2.1 Total MTM Derivative Net Assets (Liabilities) $ 9.1 $ (0.3) $ 8.8 December 31, 2020 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts - in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 3.4 $ (0.2) $ 3.2 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets — — — Total Assets 3.4 (0.2) 3.2 Current Risk Management Liabilities 0.7 — 0.7 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities 1.0 — 1.0 Total Liabilities 1.7 — 1.7 Total MTM Derivative Net Assets (Liabilities) $ 1.7 $ (0.2) $ 1.5 (a) Derivative instruments within these categories are disclosed as gross. These instruments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with the accounting guidance for “Derivatives and Hedging.” (b) Amounts include counterparty netting of risk management and hedging contracts and associated cash collateral in accordance with the accounting guidance for “Derivatives and Hedging.” (c) All derivative contracts subject to a master netting arrangement or similar agreement are offset in the statement of financial position. (d) Amount excludes Risk Management Assets of $6 million classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (e) Amount excludes Risk Management Liabilities of $0.1 million classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
Amount of Gain (Loss) Recognized on Risk Management Contracts	Year Ended December 31, 2021 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ (0.6) $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 169.1 — — — — — — Electric Generation, Transmission and Distribution Revenues — — (0.5) (0.1) — — — Purchased Electricity for Resale 2.0 — 1.8 — — — — Other Operation 2.8 0.8 0.3 0.3 0.5 0.3 0.4 Maintenance 3.4 1.0 0.5 0.3 0.6 0.4 0.5 Regulatory Assets (a) (9.1) — (2.7) (14.8) 10.0 (3.6) 3.6 Regulatory Liabilities (a) 156.4 0.2 55.9 (3.9) — 48.9 37.0 Total Gain (Loss) on Risk Management Contracts $ 324.0 $ 2.0 $ 55.3 $ (18.2) $ 11.1 $ 46.0 $ 41.5 Year Ended December 31, 2020 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 0.8 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 9.5 — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.4 0.1 — — 0.1 Purchased Electricity for Resale 1.4 — 1.2 0.1 — — — Other Operation (2.0) (0.6) (0.2) (0.2) (0.3) (0.2) (0.3) Maintenance (2.9) (0.8) (0.4) (0.3) (0.5) (0.3) (0.4) Regulatory Assets (a) (4.8) — — (0.1) (6.6) — 1.4 Regulatory Liabilities (a) 114.9 0.4 20.3 12.4 12.4 39.1 20.2 Total Gain (Loss) on Risk Management Contracts $ 116.9 $ (1.0) $ 21.3 $ 12.0 $ 5.0 $ 38.6 $ 21.0 Year Ended December 31, 2019 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 0.7 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 25.1 — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.1 0.5 — — 0.1 Purchased Electricity for Resale 1.9 — 1.6 0.1 — — — Other Operation (0.8) (0.2) (0.1) (0.1) (0.2) (0.1) (0.1) Maintenance (0.8) (0.2) (0.2) (0.1) (0.2) (0.1) (0.1) Regulatory Assets (a) (3.7) 0.7 0.3 0.3 (3.7) 1.2 (1.5) Regulatory Liabilities (a) 102.6 — 2.4 24.5 10.1 34.6 26.6 Total Gain on Risk Management Contracts $ 125.0 $ 0.3 $ 4.1 $ 25.2 $ 6.0 $ 35.6 $ 25.0 (a) Represents realized and unrealized gains and losses subject to regulatory accounting treatment recorded as either current or noncurrent on the balance sheets.
Impact of Fair Value Hedges on Balance Sheet	Carrying Amount of the Hedged Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of the Hedged Assets/(Liabilities) December 31, 2021 December 31, 2020 December 31, 2021 December 31, 2020 (in millions) Long-term Debt (a) (b) $ (952.3) $ (995.9) $ (8.5) $ (51.7) (a) Amounts included on the balance sheets within Long-term Debt Due within One Year and Long-term Debt, respectively. (b) Amounts include $(46) million and $(53) million as of December 31, 2021 and 2020, respectively, for the fair value hedge adjustment of hedged debt obligations for which hedge accounting has been discontinued.
Gain (Loss) on Hedging Instruments	Years Ended December 31, 2021 2020 2019 (in millions) Gain (Loss) on Interest Rate Contracts: Fair Value Hedging Instruments (a) $ (35.5) $ 41.1 $ 31.9 Fair Value Portion of Long-term Debt (a) 35.5 (41.1) (31.9) (a) Gain (Loss) is included in Interest Expense on the statements of income.
Impact of Cash Flow Hedges on the Balance Sheet	Impact of Cash Flow Hedges on AEP’s Balance Sheets December 31, 2021 December 31, 2020 Commodity Interest Rate Commodity Interest Rate (in millions) AOCI Gain (Loss) Net of Tax $ 163.7 $ (21.3) $ (60.6) $ (47.5) Portion Expected to be Reclassed to Net Income During the Next Twelve Months 106.7 (3.3) (27.1) (5.7) Impact of Cash Flow Hedges on the Registrant Subsidiaries’ Balance Sheets December 31, 2021 December 31, 2020 Interest Rate Expected to be Expected to be Reclassified to Reclassified to Net Income During Net Income During AOCI Gain (Loss) the Next AOCI Gain (Loss) the Next Company Net of Tax Twelve Months Net of Tax Twelve Months (in millions) AEP Texas $ (1.3) $ (1.1) $ (2.3) $ (1.1) APCo 7.5 0.8 (0.8) 0.4 I&M (6.7) (1.6) (8.3) (1.6) PSO — — 0.1 0.1 SWEPCo 1.2 0.1 (0.3) (1.5)
Liabilities Subject to Cross Default Provisions	December 31, 2021 Liabilities for Additional Contracts with Cross Settlement Default Provisions Liability if Cross Prior to Contractual Amount of Cash Default Provision Company Netting Arrangements Collateral Posted is Triggered (in millions) AEP $ 159.5 $ — $ 115.4 APCo 0.5 — 0.3 I&M 0.3 — 0.2 PSO 1.7 — 1.7 SWEPCo 2.7 — 2.7 December 31, 2020 Liabilities for Additional Contracts with Cross Settlement Default Provisions Liability if Cross Prior to Contractual Amount of Cash Default Provision Company Netting Arrangements Collateral Posted is Triggered (in millions) AEP $ 188.4 $ — $ 169.2 APCo 4.3 — 3.5 I&M 0.5 — 0.1 SWEPCo 1.8 — 1.8

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
Fair Value Measurements (Tables)	Dec. 31, 2021
Book Values and Fair Values of Long-term Debt	December 31, 2021 2020 Company Book Value Fair Value Book Value Fair Value (in millions) AEP (a)(b)(c) $ 33,454.5 $ 37,564.7 $ 31,072.5 $ 37,457.0 AEP Texas 5,180.8 5,663.8 4,820.4 5,682.6 AEPTCo 4,343.9 4,968.2 3,948.5 4,984.3 APCo 4,938.9 6,037.1 4,834.1 6,391.8 I&M 3,195.0 3,748.0 3,029.9 3,775.3 OPCo 2,968.5 3,437.5 2,430.2 3,154.9 PSO 1,913.5 2,163.7 1,373.8 1,732.1 SWEPCo 3,395.2 3,792.9 2,636.4 3,210.1 (a) The fair value amounts include debt related to AEP’s Equity Units and had a fair value of $1.7 billion and $1.7 billion as of December 31, 2021 and 2020, respectively. See “Equity Units” section of Note 14 for additional information. (b) The 2021 book value amount excludes Long-term Debt of $1.1 billion classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
Other Temporary Investments	December 31, 2021 Gross Gross Unrealized Unrealized Fair Other Temporary Investments and Restricted Cash Cost Gains Losses Value (in millions) Restricted Cash (a) $ 48.0 $ — $ — $ 48.0 Other Cash Deposits 10.0 — — 10.0 Fixed Income Securities – Mutual Funds (b) 154.3 0.5 — 154.8 Equity Securities – Mutual Funds 19.7 35.9 — 55.6 Total Other Temporary Investments and Restricted Cash $ 232.0 $ 36.4 $ — $ 268.4 December 31, 2020 Gross Gross Unrealized Unrealized Fair Other Temporary Investments and Restricted Cash Cost Gains Losses Value (in millions) Restricted Cash (a) $ 45.6 $ — $ — $ 45.6 Other Cash Deposits 22.7 — — 22.7 Fixed Income Securities – Mutual Funds (b) 120.7 2.8 — 123.5 Equity Securities – Mutual Funds 25.9 28.7 — 54.6 Total Other Temporary Investments and Restricted Cash $ 214.9 $ 31.5 $ — $ 246.4 (a) Primarily represents amounts held for the repayment of debt. (b) Primarily short and intermediate maturities which may be sold and do not contain maturity dates.
Debt and Equity Securities Within Other Temporary Investments	Years Ended December 31, 2021 2020 2019 (in millions) Proceeds from Investment Sales $ 15.0 $ 50.9 $ 21.2 Purchases of Investments 26.9 41.6 45.0 Gross Realized Gains on Investment Sales 3.6 3.8 — Gross Realized Losses on Investment Sales — 0.2 0.4
Nuclear Trust Fund Investments	December 31, 2021 2020 Gross Other-Than- Gross Other-Than- Fair Unrealized Temporary Fair Unrealized Temporary Value Gains Impairments Value Gains Impairments (in millions) Cash and Cash Equivalents $ 84.7 $ — $ — $ 25.8 $ — $ — Fixed Income Securities: United States Government 1,156.4 66.3 (7.9) 1,025.6 98.5 (7.1) Corporate Debt 76.7 6.7 (2.1) 86.3 9.6 (1.7) State and Local Government 7.3 0.4 (0.1) 114.3 0.9 (0.4) Subtotal Fixed Income Securities 1,240.4 73.4 (10.1) 1,226.2 109.0 (9.2) Equity Securities - Domestic (a) 2,541.9 1,901.3 — 2,054.7 1,400.8 — Spent Nuclear Fuel and Decommissioning Trusts $ 3,867.0 $ 1,974.7 $ (10.1) $ 3,306.7 $ 1,509.8 $ (9.2) (a) Amount reported as Gross Unrealized Gains includes unrealized gains of $1.9 billion and $1.4 billion and unrealized losses of $4 million and $9 million as of December 31, 2021 and 2020, respectively.
Securities Activity Within the Decommissioning and SNF Trusts	Years Ended December 31, 2021 2020 2019 (in millions) Proceeds from Investment Sales $ 1,886.4 $ 1,593.4 $ 1,473.0 Purchases of Investments 1,928.2 1,637.2 1,531.0 Gross Realized Gains on Investment Sales 103.2 26.4 76.5 Gross Realized Losses on Investment Sales 16.5 26.1 24.3
Contractual Maturities, Fair Value of Debt Securities	Fair Value of Fixed Income Securities (in millions) Within 1 year $ 302.4 After 1 year through 5 years 431.2 After 5 years through 10 years 227.7 After 10 years 279.1 Total $ 1,240.4
Fair Value, Assets and Liabilities Measured on Recurring Basis	AEP December 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments and Restricted Cash Restricted Cash $ 48.0 $ — $ — $ — $ 48.0 Other Cash Deposits (a) — — — 10.0 10.0 Fixed Income Securities – Mutual Funds 154.8 — — — 154.8 Equity Securities – Mutual Funds (b) 55.6 — — — 55.6 Total Other Temporary Investments and Restricted Cash 258.4 — — 10.0 268.4 Risk Management Assets Risk Management Commodity Contracts (c) (d) (i) 7.4 648.5 226.3 (642.4) 239.8 Cash Flow Hedges: Commodity Hedges (c) — 242.9 19.2 (41.7) 220.4 Fair Value Hedges — 1.2 — — 1.2 Total Risk Management Assets 7.4 892.6 245.5 (684.1) 461.4 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 77.7 — — 7.0 84.7 Fixed Income Securities: United States Government — 1,156.4 — — 1,156.4 Corporate Debt — 76.7 — — 76.7 State and Local Government — 7.3 — — 7.3 Subtotal Fixed Income Securities — 1,240.4 — — 1,240.4 Equity Securities – Domestic (b) 2,541.9 — — — 2,541.9 Total Spent Nuclear Fuel and Decommissioning Trusts 2,619.6 1,240.4 — 7.0 3,867.0 Other Investments (h) 28.8 14.9 — — 43.7 Total Assets $ 2,914.2 $ 2,147.9 $ 245.5 $ (667.1) $ 4,640.5 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (d) (j) $ 5.3 $ 485.0 $ 147.6 $ (383.2) $ 254.7 Cash Flow Hedges: Commodity Hedges (c) — 54.0 0.6 (41.7) 12.9 Fair Value Hedges — 38.1 — — 38.1 Total Risk Management Liabilities $ 5.3 $ 577.1 $ 148.2 $ (424.9) $ 305.7 AEP December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments and Restricted Cash Restricted Cash $ 45.6 $ — $ — $ — $ 45.6 Other Cash Deposits (a) 12.2 — — 10.5 22.7 Fixed Income Securities – Mutual Funds 123.5 — — — 123.5 Equity Securities – Mutual Funds (b) 54.6 — — — 54.6 Total Other Temporary Investments and Restricted Cash 235.9 — — 10.5 246.4 Risk Management Assets Risk Management Commodity Contracts (c) (f) 0.9 258.8 252.4 (190.0) 322.1 Cash Flow Hedges: Commodity Hedges (c) — 34.4 3.9 (28.5) 9.8 Interest Rate Hedges — 2.4 — — 2.4 Fair Value Hedges — 2.6 — — 2.6 Total Risk Management Assets 0.9 298.2 256.3 (218.5) 336.9 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 16.8 — — 9.0 25.8 Fixed Income Securities: United States Government — 1,025.6 — — 1,025.6 Corporate Debt — 86.3 — — 86.3 State and Local Government — 114.3 — — 114.3 Subtotal Fixed Income Securities — 1,226.2 — — 1,226.2 Equity Securities – Domestic (b) 2,054.7 — — — 2,054.7 Total Spent Nuclear Fuel and Decommissioning Trusts 2,071.5 1,226.2 — 9.0 3,306.7 Other Investments (h) — — 31.8 — 31.8 Total Assets $ 2,308.3 $ 1,524.4 $ 288.1 $ (199.0) $ 3,921.8 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (f) $ 0.9 $ 244.2 $ 167.2 $ (193.4) $ 218.9 Cash Flow Hedges: Commodity Hedges (c) — 106.1 7.6 (28.5) 85.2 Interest Rate Hedges — 3.4 — — 3.4 Fair Value Hedges — 4.1 — — 4.1 Total Risk Management Liabilities $ 0.9 $ 357.8 $ 174.8 $ (221.9) $ 311.6 AEP Texas December 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 30.4 $ — $ — $ — $ 30.4 Risk Management Assets Risk Management Commodity Contracts (c) — 0.6 — (0.6) — Total Assets $ 30.4 $ 0.6 $ — $ (0.6) $ 30.4 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 28.7 $ — $ — $ — $ 28.7 Risk Management Assets Risk Management Commodity Contracts (c) — 0.4 — (0.4) — Total Assets $ 28.7 $ 0.4 $ — $ (0.4) $ 28.7 APCo December 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 17.6 $ — $ — $ — $ 17.6 Risk Management Assets Risk Management Commodity Contracts (c) (g) — 5.8 42.0 (5.8) 42.0 Total Assets $ 17.6 $ 5.8 $ 42.0 $ (5.8) $ 59.6 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 7.2 $ 0.3 $ (6.7) $ 0.8 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 16.9 $ — $ — $ — $ 16.9 Risk Management Assets Risk Management Commodity Contracts (c) (g) — 19.4 19.9 (19.2) 20.1 Cash Flow Hedges: Interest Rate Hedges — 2.4 — — 2.4 Total Risk Management Assets — 21.8 19.9 (19.2) 22.5 Total Assets $ 16.9 $ 21.8 $ 19.9 $ (19.2) $ 39.4 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 19.5 $ 0.6 $ (18.8) $ 1.3 Cash Flow Hedges: Interest Rate Hedges — 3.4 — — 3.4 Total Risk Management Liabilities $ — $ 22.9 $ 0.6 $ (18.8) $ 4.7 I&M December 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 3.8 $ 7.6 $ (8.1) $ 3.3 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 77.7 — — 7.0 84.7 Fixed Income Securities: United States Government — 1,156.4 — — 1,156.4 Corporate Debt — 76.7 — — 76.7 State and Local Government — 7.3 — — 7.3 Subtotal Fixed Income Securities — 1,240.4 — — 1,240.4 Equity Securities - Domestic (b) 2,541.9 — — — 2,541.9 Total Spent Nuclear Fuel and Decommissioning Trusts 2,619.6 1,240.4 — 7.0 3,867.0 Total Assets $ 2,619.6 $ 1,244.2 $ 7.6 $ (1.1) $ 3,870.3 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 6.7 $ 8.3 $ (10.0) $ 5.0 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 15.1 $ 2.5 $ (13.9) $ 3.7 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 16.8 — — 9.0 25.8 Fixed Income Securities: United States Government — 1,025.6 — — 1,025.6 Corporate Debt — 86.3 — — 86.3 State and Local Government — 114.3 — — 114.3 Subtotal Fixed Income Securities — 1,226.2 — — 1,226.2 Equity Securities - Domestic (b) 2,054.7 — — — 2,054.7 Total Spent Nuclear Fuel and Decommissioning Trusts 2,071.5 1,226.2 — 9.0 3,306.7 Total Assets $ 2,071.5 $ 1,241.3 $ 2.5 $ (4.9) $ 3,310.4 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 12.0 $ 0.4 $ (12.2) $ 0.2 OPCo December 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.5 $ — $ (0.5) $ — Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 92.5 $ — $ 92.5 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.3 $ — $ (0.3) $ — Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 110.3 $ — $ 110.3 PSO December 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.3 $ 12.2 $ (0.4) $ 12.1 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 3.7 $ 0.1 $ (0.1) $ 3.7 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.2 $ 10.3 $ (0.2) $ 10.3 SWEPCo December 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.3 $ 11.0 $ (0.4) $ 10.9 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 2.1 $ 0.1 $ (0.1) $ 2.1 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.1 $ 3.3 $ (0.2) $ 3.2 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 1.7 $ — $ 1.7 (a) Amounts in “Other” column primarily represent cash deposits in bank accounts with financial institutions or third-parties. Level 1 and Level 2 amounts primarily represent investments in money market funds. (b) Amounts represent publicly-traded equity securities and equity-based mutual funds. (c) Amounts in “Other” column primarily represent counterparty netting of risk management and hedging contracts and associated cash collateral under the accounting guidance for “Derivatives and Hedging.” (d) The December 31, 2021 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $1 million in 2022 and $1 million in periods 2023-2025; Level 2 matures $42 million in 2022, $109 million in periods 2023-2025, $10 million in periods 2026-2027 and $3 million in periods 2028-2033; Level 3 matures $82 million in 2022, $10 million in periods 2023-2025, $9 million in periods 2026-2027 and $(17) million in periods 2028-2033. Risk management commodity contracts are substantially comprised of power contracts. (e) Amounts in “Other” column primarily represent accrued interest receivables from financial institutions. Level 1 amounts primarily represent investments in money market funds. (f) The December 31, 2020 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 2 matures $3 million in periods 2022-2024, $11 million in periods 2025-2026 and $1 million in periods 2027-2033; Level 3 matures $47 million in 2021, $37 million in periods 2022-2024, $14 million in periods 2025-2026 and $(13) million in periods 2027-2033. Risk management commodity contracts are substantially comprised of power contracts. (g) Substantially comprised of power contracts for the Registrant Subsidiaries. (h) See “Warrants Held in Investee” section of Note 10 for additional information. (i) Amount excludes Risk Management Assets of $6 million classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (j) Amount excludes Risk Management Liabilities of $0.1 million classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
Changes in Fair Value of Net Trading Derivatives Classified as Level 3	Year Ended December 31, 2021 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of December 31, 2020 $ 113.3 $ 19.3 $ 2.1 $ (110.3) $ 10.3 $ 1.6 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 48.6 8.3 (0.1) 2.4 16.1 9.5 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (45.2) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 24.2 — — — — — Settlements (89.0) (28.0) (2.2) 6.3 (26.4) (15.5) Transfers into Level 3 (d) (e) (3.8) — — — — — Transfers out of Level 3 (e) (34.4) — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 89.4 42.1 (0.5) 9.1 12.1 15.3 Assets and Liabilities Held for Sale related to KPCo (g) (h) (5.8) — — — — — Balance as of December 31, 2021 $ 97.3 $ 41.7 $ (0.7) $ (92.5) $ 12.1 $ 10.9 Year Ended December 31, 2020 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of December 31, 2019 $ 109.9 $ 37.7 $ 5.8 $ (103.6) $ 15.8 $ 1.4 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 39.5 13.2 2.5 (1.6) 11.9 2.8 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) 35.3 — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 13.8 — — — — — Settlements (113.1) (51.6) (8.6) 8.9 (27.6) (6.6) Transfers into Level 3 (d) (e) (3.8) — — — — — Transfers out of Level 3 (e) 5.6 0.7 0.4 — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 26.1 19.3 2.0 (14.0) 10.2 4.0 Balance as of December 31, 2020 $ 113.3 $ 19.3 $ 2.1 $ (110.3) $ 10.3 $ 1.6 Year Ended December 31, 2019 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of December 31, 2018 $ 131.2 $ 57.8 $ 8.9 $ (99.4) $ 9.5 $ 2.3 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 15.8 (13.9) 4.7 (0.9) 13.5 6.0 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (0.1) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) (15.1) — — — — — Settlements (117.6) (42.5) (13.0) 6.6 (23.0) (9.6) Transfers into Level 3 (d) (e) (0.6) (0.5) (0.3) — — — Transfers out of Level 3 (e) 35.6 (0.7) (0.4) — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 60.7 37.5 5.9 (9.9) 15.8 2.7 Balance as of December 31, 2019 $ 109.9 $ 37.7 $ 5.8 $ (103.6) $ 15.8 $ 1.4 (a) Included in revenues on the statements of income. (b) Represents the change in fair value between the beginning of the reporting period and the settlement of the risk management commodity contract. (c) Included in cash flow hedges on the statements of comprehensive income. (d) Represents existing assets or liabilities that were previously categorized as Level 2. (e) Transfers are recognized based on their value at the beginning of the reporting period that the transfer occurred. (f) Relates to the net gains (losses) of those contracts that are not reflected on the statements of income. These changes in fair value are recorded as regulatory liabilities for net gains and as regulatory assets for net losses or accounts payable. (g) Amount excludes Risk Management Assets of $6.4 million classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (h) Amount excludes Risk Management Liabilities of $0.6 million classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
Significant Unobservable Inputs for Level 3	AEP December 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (c) (in millions) Energy Contracts (g) $ 164.4 $ 135.2 Discounted Cash Flow Forward Market Price (a) $ 10.30 $ 76.70 $ 37.11 Natural Gas Contracts 3.6 — Discounted Cash Flow Forward Market Price (b) 3.11 4.02 3.47 FTRs (e) (f) 77.5 13.0 Discounted Cash Flow Forward Market Price (a) (23.93) 26.38 0.86 Total $ 245.5 $ 148.2 December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (in millions) Energy Contracts $ 213.5 $ 169.7 Discounted Cash Flow Forward Market Price (a) (c) $ 5.33 $ 100.47 $ 32.73 Natural Gas Contracts — 1.7 Discounted Cash Flow Forward Market Price (b) (c) 2.18 2.77 2.40 FTRs 42.8 3.4 Discounted Cash Flow Forward Market Price (a) (c) (15.08) 9.66 0.19 Other Investments 31.8 — Black-Scholes Model Liquidity Adjustment (d) 10 % 20 % 15 % Total $ 288.1 $ 174.8 APCo December 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ — $ 0.3 Discounted Cash Flow Forward Market Price $ 32.20 $ 56.54 $ 44.77 FTRs 42.0 — Discounted Cash Flow Forward Market Price (0.30) 26.38 2.63 Total $ 42.0 $ 0.3 December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ 1.0 $ 0.6 Discounted Cash Flow Forward Market Price $ 10.84 $ 41.09 $ 25.08 FTRs 18.9 — Discounted Cash Flow Forward Market Price 0.04 5.61 1.13 Total $ 19.9 $ 0.6 I&M December 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ — $ 0.2 Discounted Cash Flow Forward Market Price $ 32.20 $ 56.54 $ 44.77 FTRs 7.6 8.1 Discounted Cash Flow Forward Market Price (5.45) 17.78 (0.12) Total $ 7.6 $ 8.3 December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ 0.6 $ 0.3 Discounted Cash Flow Forward Market Price $ 10.84 $ 41.09 $ 25.08 FTRs 1.9 0.1 Discounted Cash Flow Forward Market Price (1.96) 3.69 0.33 Total $ 2.5 $ 0.4 OPCo December 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ — $ 92.5 Discounted Cash Flow Forward Market Price $ 14.26 $ 52.98 $ 30.68 December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ — $ 110.3 Discounted Cash Flow Forward Market Price $ 16.19 $ 46.98 $ 28.30 PSO December 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) FTRs $ 12.2 $ 0.1 Discounted Cash Flow Forward Market Price $ (18.39) $ 1.87 $ (2.57) December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) FTRs $ 10.3 $ — Discounted Cash Flow Forward Market Price $ (6.93) $ 0.48 $ (1.93) SWEPCo December 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (c) (in millions) Natural Gas Contracts $ 3.6 $ — Discounted Cash Flow Forward Market Price (b) $ 3.11 $ 4.02 $ 3.47 FTRs 7.4 0.1 Discounted Cash Flow Forward Market Price (a) (18.39) 1.87 (2.57) Total $ 11.0 $ 0.1 December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (c) (in millions) Natural Gas Contracts $ — $ 1.7 Discounted Cash Flow Forward Market Price (b) $ 2.18 $ 2.77 $ 2.41 FTRs 3.3 — Discounted Cash Flow Forward Market Price (a) (6.93) 0.48 (1.93) Total $ 3.3 $ 1.7 (a) Represents market prices in dollars per MWh. (b) Represents market prices in dollars per MMBtu. (c) The weighted-average is the product of the forward market price of the underlying commodity and volume weighted by term. (d) Represents percentage discount applied to the publically available share price. (e) Amount excludes Risk Management Assets of $6 million classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (f) Amount excludes Risk Management Liabilities of $0.5 million classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (g) Amount excludes Risk Management Liabilities of $0.1 million classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
Sensitivity of Fair Value Measurements	Uncertainty of Fair Value Measurements Significant Unobservable Input Position Change in Input Impact on Fair Value Forward Market Price Buy Increase (Decrease) Higher (Lower) Forward Market Price Sell Increase (Decrease) Lower (Higher) Liquidity Adjustment Buy Increase (Decrease) Lower (Higher)

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
Income Taxes (Tables)	Dec. 31, 2021
Details of Income Taxes as Reported	Year Ended December 31, 2021 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Federal: Current $ (27.8) $ (1.2) $ 69.8 $ 5.0 $ 26.9 $ 6.8 $ (109.6) $ (16.7) Deferred 182.6 40.5 54.1 14.9 (35.5) 25.2 105.6 26.2 Total Federal 154.8 39.3 123.9 19.9 (8.6) 32.0 (4.0) 9.5 State and Local: Current 6.0 3.0 5.8 2.2 (0.6) (3.1) — 0.4 Deferred (a) (45.3) 0.8 14.4 — (1.4) 5.5 8.1 (10.5) Total State and Local (39.3) 3.8 20.2 2.2 (2.0) 2.4 8.1 (10.1) Income Tax Expense (Benefit) $ 115.5 $ 43.1 $ 144.1 $ 22.1 $ (10.6) $ 34.4 $ 4.1 $ (0.6) (a) Benefit at AEP is primarily due to an out of period adjustment related to Deferred Income Taxes and Income Tax Expense (Benefit). Management concluded the misstatement and subsequent correction was not material to prior or current period financial statements. Year Ended December 31, 2020 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Federal: Current $ (138.2) $ 5.2 $ 22.2 $ 21.4 $ 11.3 $ (26.6) $ (11.4) $ (13.6) Deferred 146.9 (15.4) 65.4 (27.1) (20.6) 74.0 8.3 19.6 Total Federal 8.7 (10.2) 87.6 (5.7) (9.3) 47.4 (3.1) 6.0 State and Local: Current (16.7) (0.1) 2.8 9.3 1.9 (5.4) 0.1 (8.2) Deferred 48.5 (0.9) 16.3 0.7 (0.1) 3.2 8.2 11.6 Total State and Local 31.8 (1.0) 19.1 10.0 1.8 (2.2) 8.3 3.4 Income Tax Expense (Benefit) $ 40.5 $ (11.2) $ 106.7 $ 4.3 $ (7.5) $ 45.2 $ 5.2 $ 9.4 Year Ended December 31, 2019 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Federal: Current $ (7.4) $ (31.8) $ 23.7 $ 36.7 $ 48.1 $ (10.0) $ 25.5 $ 6.9 Deferred (71.6) (24.7) 71.7 (126.1) (57.1) 40.6 (26.0) (10.0) Total Federal (79.0) (56.5) 95.4 (89.4) (9.0) 30.6 (0.5) (3.1) State and Local: Current 4.4 2.9 2.4 12.0 (2.4) 1.1 0.2 0.8 Deferred 61.7 — 19.6 (0.6) 0.8 3.2 7.8 (2.4) Total State and Local 66.1 2.9 22.0 11.4 (1.6) 4.3 8.0 (1.6) Income Tax Expense (Benefit) $ (12.9) $ (53.6) $ 117.4 $ (78.0) $ (10.6) $ 34.9 $ 7.5 $ (4.7)
Reconciliation of Federal Statutory Tax Rate to Reported Tax Rate	AEP Years Ended December 31, 2021 2020 2019 (in millions) Net Income $ 2,488.1 $ 2,196.7 $ 1,919.8 Less: Equity Earnings – Dolet Hills (3.4) (2.9) (3.0) Income Tax Expense (Benefit) 115.5 40.5 (12.9) Pretax Income $ 2,600.2 $ 2,234.3 $ 1,903.9 Income Taxes on Pretax Income at Statutory Rate (21%) $ 546.0 $ 469.2 $ 399.8 Increase (Decrease) in Income Taxes Resulting from the Following Items: Reversal of Origination Flow-Through 25.9 26.5 20.4 Investment Tax Credit Amortization (22.0) (18.8) (13.0) Production Tax Credits (98.8) (83.1) (59.6) State and Local Income Taxes, Net 39.4 25.1 52.2 Removal Costs (20.0) (18.6) (22.2) AFUDC (30.6) (32.5) (37.1) Tax Adjustments (a) (55.1) — — Tax Reform Excess ADIT Reversal (255.6) (268.2) (353.2) CARES Act — (48.0) — Other (13.7) (11.1) (0.2) Income Tax Expense (Benefit) $ 115.5 $ 40.5 $ (12.9) Effective Income Tax Rate 4.4 % 1.8 % (0.7) % (a) Represents an out of period adjustment related to Deferred Income Taxes and Income Tax Expense (Benefit). Management concluded the misstatement and subsequent correction was not material to prior or current period financial statements. AEP Texas Years Ended December 31, 2021 2020 2019 (in millions) Net Income $ 289.8 $ 241.0 $ 178.3 Income Tax Expense (Benefit) 43.1 (11.2) (53.6) Pretax Income $ 332.9 $ 229.8 $ 124.7 Income Taxes on Pretax Income at Statutory Rate (21%) $ 69.9 $ 48.3 $ 26.2 Increase (Decrease) in Income Taxes Resulting from the Following Items: State and Local Income Taxes, Net 2.4 (0.8) 2.3 AFUDC (4.5) (4.1) (3.2) Parent Company Loss Benefit (3.2) (4.5) (3.8) Tax Reform Excess ADIT Reversal (21.3) (47.9) (73.4) Other (0.2) (2.2) (1.7) Income Tax Expense (Benefit) $ 43.1 $ (11.2) $ (53.6) Effective Income Tax Rate 12.9 % (4.9) % (43.0) % AEPTCo Years Ended December 31, 2021 2020 2019 (in millions) Net Income $ 591.7 $ 423.4 $ 439.7 Income Tax Expense 144.1 106.7 117.4 Pretax Income $ 735.8 $ 530.1 $ 557.1 Income Taxes on Pretax Income at Statutory Rate (21%) $ 154.5 $ 111.3 $ 117.0 Increase (Decrease) in Income Taxes Resulting from the Following Items: State and Local Income Taxes, Net 19.8 15.1 17.4 AFUDC (14.1) (15.5) (17.7) Parent Company Loss Benefit (18.3) (7.0) (4.2) Other 2.2 2.8 4.9 Income Tax Expense $ 144.1 $ 106.7 $ 117.4 Effective Income Tax Rate 19.6 % 20.1 % 21.1 % APCo Years Ended December 31, 2021 2020 2019 (in millions) Net Income $ 348.9 $ 369.7 $ 306.3 Income Tax Expense (Benefit) 22.1 4.3 (78.0) Pretax Income $ 371.0 $ 374.0 $ 228.3 Income Taxes on Pretax Income at Statutory Rate (21%) $ 77.9 $ 78.5 $ 47.9 Increase (Decrease) in Income Taxes Resulting from the Following Items: Reversal of Origination Flow-Through 11.7 12.7 10.8 State and Local Income Taxes, Net 2.1 7.9 9.0 Removal Costs (7.3) (5.7) (6.4) AFUDC (4.6) (4.5) (5.2) Parent Company Loss Benefit — (6.2) (4.1) Tax Adjustments (a) 4.5 — — Tax Reform Excess ADIT Reversal (60.5) (72.3) (130.4) Federal Return to Provision (1.6) (7.2) (1.0) Other (0.1) 1.1 1.4 Income Tax Expense (Benefit) $ 22.1 $ 4.3 $ (78.0) Effective Income Tax Rate 6.0 % 1.1 % (34.2) % (a) Represents an out of period adjustment related to Deferred Income Taxes and Income Tax Expense (Benefit). Management concluded the misstatement and subsequent correction was not material to prior or current period financial statements. I&M Years Ended December 31, 2021 2020 2019 (in millions) Net Income $ 279.8 $ 284.8 $ 269.4 Income Tax Benefit (10.6) (7.5) (10.6) Pretax Income $ 269.2 $ 277.3 $ 258.8 Income Taxes on Pretax Income at Statutory Rate (21%) $ 56.5 $ 58.2 $ 54.3 Increase (Decrease) in Income Taxes Resulting from the Following Items: Reversal of Origination Flow-Through 3.5 1.6 4.0 Investment Tax Credit Amortization (6.4) (4.5) (3.6) State and Local Income Taxes, Net (1.3) 1.5 (1.2) Removal Costs (9.7) (10.5) (12.8) AFUDC (2.7) (2.4) (4.1) Parent Company Loss Benefit (2.8) (6.4) (3.3) Tax Reform Excess ADIT Reversal (46.3) (46.8) (42.5) Other (1.4) 1.8 (1.4) Income Tax Benefit $ (10.6) $ (7.5) $ (10.6) Effective Income Tax Rate (3.9) % (2.7) % (4.1) % OPCo Years Ended December 31, 2021 2020 2019 (in millions) Net Income $ 253.6 $ 271.4 $ 297.1 Income Tax Expense 34.4 45.2 34.9 Pretax Income $ 288.0 $ 316.6 $ 332.0 Income Taxes on Pretax Income at Statutory Rate (21%) $ 60.5 $ 66.5 $ 69.7 Increase (Decrease) in Income Taxes Resulting from the Following Items: Reversal of Origination Flow-Through 2.2 3.7 (1.4) State and Local Income Taxes, Net — (1.7) 3.4 AFUDC (2.3) (2.6) (3.8) Tax Adjustments (a) 8.9 — — Tax Reform Excess ADIT Reversal (32.6) (27.2) (27.3) Federal Return to Provision (1.2) 6.5 (3.7) Other (1.1) — (2.0) Income Tax Expense $ 34.4 $ 45.2 $ 34.9 Effective Income Tax Rate 11.9 % 14.3 % 10.5 % (a) Represents an out of period adjustment related to Deferred Income Taxes and Income Tax Expense (Benefit). Management concluded the misstatement and subsequent correction was not material to prior or current period financial statements. PSO Years Ended December 31, 2021 2020 2019 (in millions) Net Income $ 141.1 $ 123.0 $ 137.6 Income Tax Expense 4.1 5.2 7.5 Pretax Income $ 145.2 $ 128.2 $ 145.1 Income Taxes on Pretax Income at Statutory Rate (21%) $ 30.5 $ 26.9 $ 30.5 Increase (Decrease) in Income Taxes Resulting from the Following Items: Investment Tax Credit Amortization (1.8) (2.1) (0.5) Production Tax Credits (6.0) — — State and Local Income Taxes, Net 6.4 6.5 6.3 Parent Company Loss Benefit — (0.2) (2.1) Tax Reform Excess ADIT Reversal (25.4) (25.5) (24.5) Other 0.4 (0.4) (2.2) Income Tax Expense $ 4.1 $ 5.2 $ 7.5 Effective Income Tax Rate 2.8 % 4.1 % 5.2 % SWEPCo Years Ended December 31, 2021 2020 2019 (in millions) Net Income $ 242.1 $ 183.7 $ 162.2 Less: Equity Earnings – Dolet Hills (3.4) (2.9) (3.0) Income Tax Expense (Benefit) (0.6) 9.4 (4.7) Pretax Income $ 238.1 $ 190.2 $ 154.5 Income Taxes on Pretax Income at Statutory Rate (21%) $ 50.0 $ 39.9 $ 32.4 Increase (Decrease) in Income Taxes Resulting from the Following Items: Reversal of Origination Flow-Through 1.8 1.9 1.9 Depletion (2.7) (3.4) (3.4) Production Tax Credits (7.2) — — State and Local Income Taxes, Net (8.0) 2.7 (1.3) Parent Company Loss Benefit — (5.6) (1.6) Tax Reform Excess ADIT Reversal (31.1) (21.9) (29.9) Other (3.4) (4.2) (2.8) Income Tax Expense (Benefit) $ (0.6) $ 9.4 $ (4.7) Effective Income Tax Rate (0.3) % 4.9 % (3.0) %
Reconciliation of Significant Temporary Differences	AEP December 31, 2021 2020 (in millions) Deferred Tax Assets $ 3,277.0 $ 3,259.7 Deferred Tax Liabilities (11,479.5) (11,500.6) Net Deferred Tax Liabilities $ (8,202.5) $ (8,240.9) Property Related Temporary Differences $ (7,020.3) $ (7,340.5) Amounts Due to Customers for Future Income Taxes 1,033.0 1,075.8 Deferred State Income Taxes (1,116.7) (1,317.6) Securitized Assets (128.8) (140.0) Regulatory Assets (645.4) (391.6) Accrued Nuclear Decommissioning (743.2) (626.4) Net Operating Loss Carryforward 285.7 112.9 Tax Credit Carryforward 439.8 323.6 Operating Lease Liability 114.2 183.7 Investment in Partnership (392.1) (362.0) All Other, Net (28.7) 241.2 Net Deferred Tax Liabilities $ (8,202.5) $ (8,240.9) AEP Texas December 31, 2021 2020 (in millions) Deferred Tax Assets $ 173.8 $ 183.6 Deferred Tax Liabilities (1,262.7) (1,200.3) Net Deferred Tax Liabilities $ (1,088.9) $ (1,016.7) Property Related Temporary Differences $ (1,060.2) $ (1,039.6) Amounts Due to Customers for Future Income Taxes 110.0 114.4 Deferred State Income Taxes (32.2) (29.1) Securitized Transition Assets (84.4) (90.2) Regulatory Assets (45.1) (47.4) Operating Lease Liability 15.8 18.0 All Other, Net 7.2 57.2 Net Deferred Tax Liabilities $ (1,088.9) $ (1,016.7) AEPTCo December 31, 2021 2020 (in millions) Deferred Tax Assets $ 158.8 $ 166.5 Deferred Tax Liabilities (1,121.7) (1,073.4) Net Deferred Tax Liabilities $ (962.9) $ (906.9) Property Related Temporary Differences $ (997.0) $ (937.8) Amounts Due to Customers for Future Income Taxes 118.2 118.9 Deferred State Income Taxes (94.5) (98.3) Net Operating Loss Carryforward 8.1 13.2 All Other, Net 2.3 (2.9) Net Deferred Tax Liabilities $ (962.9) $ (906.9) APCo December 31, 2021 2020 (in millions) Deferred Tax Assets $ 495.1 $ 500.6 Deferred Tax Liabilities (2,299.8) (2,250.5) Net Deferred Tax Liabilities $ (1,804.7) $ (1,749.9) Property Related Temporary Differences $ (1,476.5) $ (1,412.0) Amounts Due to Customers for Future Income Taxes 182.1 198.3 Deferred State Income Taxes (288.8) (336.5) Securitized Assets (39.3) (44.7) Regulatory Assets (177.0) (114.8) Operating Lease Liability 14.2 16.7 All Other, Net (19.4) (56.9) Net Deferred Tax Liabilities $ (1,804.7) $ (1,749.9) I&M December 31, 2021 2020 (in millions) Deferred Tax Assets $ 1,072.2 $ 989.5 Deferred Tax Liabilities (2,172.4) (2,053.9) Net Deferred Tax Liabilities $ (1,100.2) $ (1,064.4) Property Related Temporary Differences $ (286.2) $ (409.2) Amounts Due to Customers for Future Income Taxes 135.5 147.9 Deferred State Income Taxes (222.0) (211.1) Regulatory Assets (23.6) (16.5) Accrued Nuclear Decommissioning (743.2) (626.4) Operating Lease Liability 13.5 46.6 All Other, Net 25.8 4.3 Net Deferred Tax Liabilities $ (1,100.2) $ (1,064.4) OPCo December 31, 2021 2020 (in millions) Deferred Tax Assets $ 204.4 $ 210.8 Deferred Tax Liabilities (1,205.3) (1,165.9) Net Deferred Tax Liabilities $ (1,000.9) $ (955.1) Property Related Temporary Differences $ (1,042.0) $ (1,016.0) Amounts Due to Customers for Future Income Taxes 117.7 121.1 Deferred State Income Taxes (58.8) (40.7) Regulatory Assets (39.8) (53.7) Operating Lease Liability 17.2 19.4 All Other, Net 4.8 14.8 Net Deferred Tax Liabilities $ (1,000.9) $ (955.1) PSO December 31, 2021 2020 (in millions) Deferred Tax Assets $ 170.0 $ 239.8 Deferred Tax Liabilities (952.3) (928.3) Net Deferred Tax Liabilities $ (782.3) $ (688.5) Property Related Temporary Differences $ (708.6) $ (661.8) Amounts Due to Customers for Future Income Taxes 111.5 118.5 Deferred State Income Taxes (83.2) (107.7) Regulatory Assets (228.0) (39.1) Net Operating Loss Carryforward 111.4 12.9 All Other, Net 14.6 (11.3) Net Deferred Tax Liabilities $ (782.3) $ (688.5) SWEPCo December 31, 2021 2020 (in millions) Deferred Tax Assets $ 336.4 $ 338.1 Deferred Tax Liabilities (1,424.0) (1,355.7) Net Deferred Tax Liabilities $ (1,087.6) $ (1,017.6) Property Related Temporary Differences $ (989.6) $ (985.1) Amounts Due to Customers for Future Income Taxes 154.8 162.7 Deferred State Income Taxes (234.9) (214.7) Regulatory Assets (101.4) (26.2) Net Operating Loss Carryforward 67.4 33.4 All Other, Net 16.1 12.3 Net Deferred Tax Liabilities $ (1,087.6) $ (1,017.6)
State Net Income Tax Operating Loss Carryforwards	State Net Income Tax Operating Loss Years of Company State/Municipality Carryforward Expiration (in millions) AEP Arkansas $ 161.8 2022 - 2031 AEP Colorado 82.8 2041 AEP Illinois 55.2 2031 - 2041 AEP Indiana 304.4 2039 - 2041 AEP Kentucky 230.4 2030 - 2037 AEP Louisiana 566.7 NA AEP Michigan 65.2 2029 - 2031 AEP New Jersey 36.5 2036 - 2041 AEP New Mexico 32.6 2037 - 2039 AEP Ohio Municipal 1,027.9 2022 - 2026 AEP Oklahoma 1,357.1 2034 - 2037 AEP Pennsylvania 82.7 2030 - 2041 AEP Tennessee 53.0 2030 - 2036 AEP Virginia 20.9 2030 - 2037 AEP West Virginia 99.5 2029 - 2037 AEPTCo Oklahoma 107.8 2034 - 2037 APCo West Virginia 62.9 NA OPCo Ohio Municipal 76.0 2022 - 2026 PSO Oklahoma 1,229.8 2034 - 2037 SWEPCo Arkansas 160.7 2022 - 2031 SWEPCo Louisiana 554.7 NA
Summary of Tax Credit Carryforwards	Total Federal Total State Tax Credit Tax Credit Company Carryforward Carryforward (in millions) AEP $ 439.8 $ 38.8 AEP Texas 0.3 — AEPTCo 0.1 — APCo 1.3 — I&M 16.9 — OPCo 0.4 — PSO 6.3 38.8 SWEPCo 7.9 —
Reconciliation of Beginning and Ending Unrecognized Tax Benefits	AEP 2021 2020 2019 (in millions) Balance as of January 1, $ 13.2 $ 24.1 $ 14.6 Increase – Tax Positions Taken During a Prior Period 1.2 0.6 8.8 Decrease – Tax Positions Taken During a Prior Period (3.2) (14.5) (2.1) Increase – Tax Positions Taken During the Current Year 3.1 3.0 2.8 Decrease – Tax Positions Taken During the Current Year — — — Decrease – Settlements with Taxing Authorities — — — Decrease – Lapse of the Applicable Statute of Limitations — — — Balance as of December 31, $ 14.3 $ 13.2 $ 24.1

Leases (Tables)

Leases (Tables)	12 Months Ended
Leases (Tables)	Dec. 31, 2021
Lease Rental Costs	Year Ended December 31, 2021 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Cost $ 275.3 $ 18.4 $ 1.7 $ 19.3 $ 90.2 $ 19.0 $ 8.7 $ 12.1 Finance Lease Cost: Amortization of Right-of-Use Assets 74.7 6.7 — 7.7 12.9 4.9 3.2 11.0 Interest on Lease Liabilities 14.4 1.4 — 2.4 3.0 0.8 0.6 2.5 Total Lease Rental Costs (a) $ 364.4 $ 26.5 $ 1.7 $ 29.4 $ 106.1 $ 24.7 $ 12.5 $ 25.6 Year Ended December 31, 2020 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Cost $ 279.6 $ 17.4 $ 2.6 $ 19.1 $ 101.5 $ 17.1 $ 7.8 $ 9.4 Finance Lease Cost: Amortization of Right-of-Use Assets 61.9 6.3 — 7.4 6.5 4.7 3.5 10.9 Interest on Lease Liabilities 15.4 1.5 — 2.7 3.1 0.9 0.7 2.2 Total Lease Rental Costs (a) $ 356.9 $ 25.2 $ 2.6 $ 29.2 $ 111.1 $ 22.7 $ 12.0 $ 22.5 Year Ended December 31, 2019 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Cost $ 286.0 $ 16.5 $ 2.5 $ 19.5 $ 93.1 $ 18.0 $ 6.8 $ 8.0 Finance Lease Cost: Amortization of Right-of-Use Assets 70.8 5.1 0.1 6.7 5.7 3.5 3.1 11.0 Interest on Lease Liabilities 16.4 1.4 — 2.9 2.9 0.7 0.6 2.9 Total Lease Rental Costs (a) $ 373.2 $ 23.0 $ 2.6 $ 29.1 $ 101.7 $ 22.2 $ 10.5 $ 21.9 (a) Excludes variable and short-term lease costs, which were immaterial.	[1]
Supplemental Balance Sheet Information Related to Leases	December 31, 2021 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo Weighted-Average Remaining Lease Term (years): Operating Leases 10.39 5.91 2.95 5.68 5.87 6.69 20.89 20.24 Finance Leases 2.95 5.51 0.00 4.97 2.10 5.54 6.18 4.53 Weighted-Average Discount Rate: Operating Leases 3.35 % 3.53 % 0.90 % 3.42 % 3.46 % 3.56 % 3.35 % 3.34 % Finance Leases 3.26 % 4.31 % — % 7.16 % 3.02 % 4.19 % 4.23 % 4.68 % December 31, 2020 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo Weighted-Average Remaining Lease Term (years): Operating Leases 5.30 6.51 2.01 6.27 3.50 7.44 7.03 7.54 Finance Leases 5.43 6.07 0.00 5.75 5.79 5.90 6.16 4.95 Weighted-Average Discount Rate: Operating Leases 3.44 % 3.60 % 1.51 % 3.48 % 3.42 % 3.60 % 3.39 % 3.45 % Finance Leases 5.68 % 4.39 % — % 7.33 % 8.29 % 4.25 % 4.35 % 4.77 % Year Ended December 31, 2021 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Cash paid for amounts included in the measurement of lease liabilities: Operating Cash Flows Used for Operating Leases $ 279.9 $ 18.0 $ 1.6 $ 19.3 $ 92.9 $ 19.0 $ 8.7 $ 11.6 Operating Cash Flows Used for Finance Leases 14.3 1.4 — 2.4 2.9 0.8 0.6 2.5 Financing Cash Flows Used for Finance Leases 64.0 6.7 — 7.7 6.8 4.9 3.2 10.9 Non-cash Acquisitions Under Operating Leases $ 117.0 $ 4.4 $ 2.1 $ 4.2 $ 2.6 $ 4.2 $ 33.4 $ 42.9 Year Ended December 31, 2020 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Cash paid for amounts included in the measurement of lease liabilities: Operating Cash Flows Used for Operating Leases $ 280.3 $ 17.1 $ 2.6 $ 19.2 $ 102.2 $ 16.9 $ 7.7 $ 9.4 Operating Cash Flows Used for Finance Leases 15.4 1.5 — 2.7 3.1 0.9 0.7 2.2 Financing Cash Flows Used for Finance Leases 61.7 6.3 — 7.4 6.5 4.7 3.5 10.9 Non-cash Acquisitions Under Operating Leases $ 161.7 $ 15.8 $ 1.8 $ 16.2 $ 18.1 $ 18.1 $ 12.3 $ 18.4
Property, Plant and Equipment and Related Obligations Under Finance Leases	December 31, 2021 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Property, Plant and Equipment Under Finance Leases: Generation $ 388.8 $ — $ — $ 42.8 $ 156.8 $ — $ 0.6 $ 34.3 Other Property, Plant and Equipment 323.8 50.7 — 20.4 42.1 32.1 23.9 55.7 Total Property, Plant and Equipment 712.6 50.7 — 63.2 198.9 32.1 24.5 90.0 Accumulated Amortization 222.4 19.9 — 27.5 38.2 12.8 9.2 47.8 Net Property, Plant and Equipment Under Finance Leases $ 490.2 (a) $ 30.8 $ — $ 35.7 $ 160.7 $ 19.3 $ 15.3 $ 42.2 Obligations Under Finance Leases: Noncurrent Liability $ 196.1 $ 24.2 $ — $ 28.1 $ 31.7 $ 14.9 $ 12.3 $ 38.9 Liability Due Within One Year 304.6 6.6 — 7.6 130.5 4.4 3.0 10.8 Total Obligations Under Finance Leases $ 500.7 (b) $ 30.8 $ — $ 35.7 $ 162.2 $ 19.3 $ 15.3 $ 49.7 (a) Amount excludes $3 million of Net Property, Plant and Equipment Under Finance Leases classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (b) Amount excludes $3 million of Obligations Under Finance Leases classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. December 31, 2020 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Property, Plant and Equipment Under Finance Leases: Generation $ 138.2 $ — $ — $ 42.8 $ 28.8 $ — $ 0.7 $ 37.7 Other Property, Plant and Equipment 322.8 49.7 — 20.3 40.2 31.4 23.0 52.4 Total Property, Plant and Equipment 461.0 49.7 — 63.1 69.0 31.4 23.7 90.1 Accumulated Amortization 176.8 16.6 — 21.4 27.3 9.8 8.7 36.5 Net Property, Plant and Equipment Under Finance Leases $ 284.2 $ 33.1 $ — $ 41.7 $ 41.7 $ 21.6 $ 15.0 $ 53.6 Obligations Under Finance Leases: Noncurrent Liability $ 231.0 $ 26.8 $ — $ 34.4 $ 35.3 $ 16.9 $ 11.9 $ 44.6 Liability Due Within One Year 58.1 6.3 — 7.3 6.4 4.7 3.1 10.7 Total Obligations Under Finance Leases $ 289.1 $ 33.1 $ — $ 41.7 $ 41.7 $ 21.6 $ 15.0 $ 55.3
Operating Lease Assets and Related Obligations	December 31, 2021 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Assets $ 578.3 (a) $ 73.6 $ 2.0 $ 66.9 $ 63.5 $ 81.2 $ 68.9 $ 80.1 Obligations Under Operating Leases: Noncurrent Liability $ 492.8 $ 61.3 $ 1.3 $ 52.4 $ 48.9 $ 68.6 $ 62.2 $ 77.7 Liability Due Within One Year 97.6 14.0 0.9 15.1 15.5 13.1 6.9 8.1 Total Obligations Under Operating Leases $ 590.4 (b) $ 75.3 $ 2.2 $ 67.5 $ 64.4 $ 81.7 $ 69.1 $ 85.8 (a) Amount excludes $11 million of Operating Lease Assets classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. (b) Amount excludes $11 million of Obligations Under Operating Leases classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information. December 31, 2020 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Assets $ 866.4 $ 84.1 $ 1.6 $ 78.8 $ 218.1 $ 92.0 $ 42.6 $ 48.5 Obligations Under Operating Leases: Noncurrent Liability $ 638.4 $ 71.0 $ 0.4 $ 64.4 $ 135.9 $ 79.5 $ 36.2 $ 44.1 Liability Due Within One Year 241.3 14.5 1.2 14.9 85.6 13.1 6.5 7.9 Total Obligations Under Operating Leases $ 879.7 $ 85.5 $ 1.6 $ 79.3 $ 221.5 $ 92.6 $ 42.7 $ 52.0
Finance Lease Liabilities Rolling Future Minimum Lease Payments	Finance Leases AEP (a) AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) 2022 $ 317.3 $ 7.8 $ — $ 9.8 $ 133.7 $ 5.1 $ 3.6 $ 12.6 2023 61.0 7.1 — 9.1 8.6 4.4 3.3 11.8 2024 64.7 5.9 — 8.3 11.6 3.7 2.8 15.9 2025 35.6 4.5 — 7.2 5.9 2.5 2.1 5.6 2026 20.1 3.5 — 2.7 3.5 2.0 1.8 2.3 After 2026 39.2 5.9 — 4.1 10.1 4.0 3.9 6.0 Total Future Minimum Lease Payments 537.9 34.7 — 41.2 173.4 21.7 17.5 54.2 Less: Imputed Interest 37.2 3.9 — 5.5 11.2 2.4 2.2 4.5 Estimated Present Value of Future Minimum Lease Payments $ 500.7 $ 30.8 $ — $ 35.7 $ 162.2 $ 19.3 $ 15.3 $ 49.7 (a) Amount excludes $3 million of Obligations Under Finance Leases classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
Operating Lease Liabilities Rolling Future Minimum Lease Payments	Operating Leases AEP (a) AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) 2022 $ 119.6 $ 16.7 $ 0.9 $ 17.5 $ 17.6 $ 16.2 $ 9.2 $ 13.0 2023 102.2 15.5 0.7 14.8 11.7 15.2 8.9 11.8 2024 89.9 14.1 0.4 11.9 10.4 13.8 8.1 10.0 2025 76.7 11.7 0.2 9.1 9.3 12.1 6.9 8.7 2026 64.0 9.5 — 7.2 7.3 11.0 6.0 7.5 After 2026 272.4 16.9 — 14.1 15.0 24.2 62.6 80.4 Total Future Minimum Lease Payments 724.8 84.4 2.2 74.6 71.3 92.5 101.7 131.4 Less: Imputed Interest 134.4 9.1 — 7.1 6.9 10.8 32.6 45.6 Estimated Present Value of Future Minimum Lease Payments $ 590.4 $ 75.3 $ 2.2 $ 67.5 $ 64.4 $ 81.7 $ 69.1 $ 85.8 (a) Amount excludes $11 million of Obligations Under Operating Leases classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.	[2]
Maximum Potential Loss	Company Maximum (in millions) AEP $ 47.4 AEP Texas 11.1 APCo 6.2 I&M 4.1 OPCo 7.5 PSO 4.6 SWEPCo 5.2
Future Minimum Lease Payments	Future Minimum Lease Payments AEP (a) I&M (in millions) 2022 $ 248.7 $ 124.4 Total Future Minimum Lease Payments $ 248.7 $ 124.4 (a) AEP’s future minimum lease payments include equal shares from AEGCo and I&M.

[1]	Excludes variable and short-term lease costs, which were immaterial.
[2]	Amount excludes $11 million of Obligations Under Operating Leases classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.

Financing Activities (Tables)

Financing Activities (Tables)	12 Months Ended
Financing Activities (Tables)	Dec. 31, 2021
AEP Common Stock	Shares of AEP Common Stock Issued Held in Treasury Balance, December 31, 2018 513,450,036 20,204,160 Issued 923,595 — Balance, December 31, 2019 514,373,631 20,204,160 Issued 2,434,723 — Balance, December 31, 2020 516,808,354 20,204,160 Issued 7,607,821 — Balance, December 31, 2021 524,416,175 20,204,160
Long-term Debt	Weighted-Average Interest Rate Ranges as of Outstanding as of Interest Rate as of December 31, December 31, Company Maturity December 31, 2021 2021 2020 2021 2020 AEP (in millions) Senior Unsecured Notes 2021-2051 3.69% 0.61%-7.00% 0.70%-8.13% $ 27,497.3 $ 25,116.1 Pollution Control Bonds (a) 2021-2036 (b) 2.40% 0.19%-4.55% 0.18%-4.63% 1,804.5 1,936.7 Notes Payable – Nonaffiliated (c) 2021-2032 2.41% 0.79%-6.37% 0.84%-6.37% 211.3 239.1 Securitization Bonds 2023-2029 (d) 2.84% 2.01%-3.77% 2.01%-3.77% 603.5 716.4 Spent Nuclear Fuel Obligation (e) 281.3 281.2 Junior Subordinated Notes (f) 2023-2027 2.81% 1.30%-3.88% 1.30%-3.40% 2,373.0 1,624.1 Other Long-term Debt 2021-2059 1.63% 0.91%-13.72% 0.81%-13.72% 683.6 1,158.9 Total Long-term Debt Outstanding (g) $ 33,454.5 $ 31,072.5 AEP Texas Senior Unsecured Notes 2022-2051 3.67% 2.10%-6.76% 2.10%-6.76% $ 4,135.5 $ 3,687.6 Pollution Control Bonds 2023-2030 (b) 3.42% 0.90%-4.55% 0.90%-4.55% 439.9 439.7 Securitization Bonds 2024-2029 (d) 2.53% 2.06%-2.84% 2.06%-2.84% 404.7 492.6 Other Long-term Debt 2022-2059 1.37% 1.35%-4.50% 1.40%-4.50% 200.7 200.5 Total Long-term Debt Outstanding $ 5,180.8 $ 4,820.4 AEPTCo Senior Unsecured Notes 2021-2051 3.73% 2.75%-5.52% 3.10%-5.52% $ 4,343.9 $ 3,948.5 Total Long-term Debt Outstanding $ 4,343.9 $ 3,948.5 APCo Senior Unsecured Notes 2021-2050 4.70% 2.70%-7.00% 3.30%-7.00% $ 4,083.7 $ 3,937.2 Pollution Control Bonds (a) 2021-2036 (b) 1.67% 0.19%-2.75% 0.19%-4.63% 529.5 546.3 Securitization Bonds 2023-2028 (d) 3.46% 2.01%-3.77% 2.01%-3.77% 198.8 223.8 Other Long-term Debt 2022-2026 1.42% 1.24%-13.72% 1.32%-13.72% 126.9 126.8 Total Long-term Debt Outstanding $ 4,938.9 $ 4,834.1 I&M Senior Unsecured Notes 2023-2051 4.19% 3.20%-6.05% 3.20%-6.05% $ 2,595.5 $ 2,152.2 Pollution Control Bonds (a) 2021-2025 (b) 2.49% 0.75%-3.05% 0.18%-3.05% 188.7 240.5 Notes Payable – Nonaffiliated (c) 2021-2025 0.99% 0.79%-1.24% 0.84%-1.29% 122.2 146.7 Spent Nuclear Fuel Obligation (e) 281.3 281.2 Other Long-term Debt 2021-2025 6.00% 6.00% 1.28%-6.00% 7.3 209.3 Total Long-term Debt Outstanding $ 3,195.0 $ 3,029.9 OPCo Senior Unsecured Notes 2021-2051 3.87% 1.63%-6.60% 2.60%-6.60% $ 2,967.8 $ 2,429.4 Other Long-term Debt 2028 1.15% 1.15% 1.15% 0.7 0.8 Total Long-term Debt Outstanding $ 2,968.5 $ 2,430.2 PSO Senior Unsecured Notes 2021-2051 3.74% 2.20%-6.63% 3.05%-6.63% $ 1,785.5 $ 1,246.3 Other Long-term Debt 2022-2027 1.50% 1.47%-3.00% 1.42%-3.00% 128.0 127.5 Total Long-term Debt Outstanding $ 1,913.5 $ 1,373.8 SWEPCo Senior Unsecured Notes 2022-2051 3.57% 1.65%-6.20% 2.75%-6.20% $ 3,295.1 $ 2,430.8 Notes Payable – Nonaffiliated (c) 2024-2032 5.34% 4.58%-6.37% 4.58%-6.37% 59.1 62.4 Other Long-term Debt 2021-2035 4.68% 4.68% 2.25%-4.68% 41.0 143.2 Total Long-term Debt Outstanding $ 3,395.2 $ 2,636.4 (a) For certain series of Pollution Control Bonds, interest rates are subject to periodic adjustment. Certain series may be purchased on demand at periodic interest adjustment dates. Letters of credit from banks and insurance policies support certain series. Consequently, these bonds have been classified for maturity purposes as Long-term Debt Due Within One Year - Nonaffiliated on the balance sheets. (b) Certain Pollution Control Bonds are subject to redemption earlier than the maturity date. (c) Notes payable represent outstanding promissory notes issued under term loan agreements and credit agreements with a number of banks and other financial institutions. At expiration, all notes then issued and outstanding are due and payable. Interest rates are both fixed and variable. Variable rates generally relate to specified short-term interest rates. (d) Dates represent the scheduled final payment dates for the securitization bonds. The legal maturity date is one to two years later. These bonds have been classified for maturity and repayment purposes based on the scheduled final payment date. (e) Spent Nuclear Fuel Obligation consists of a liability along with accrued interest for disposal of SNF. See “Spent Nuclear Fuel Disposal” section of Note 6 for additional information. (f) See “Equity Units” section below for additional information. (g) 2021 amount excludes $1.1 billion of Total Long-term Debt Outstanding classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
Long-term Debt 5-Year Maturity	AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) 2022 $ 2,153.8 $ 716.0 $ 104.0 $ 480.7 $ 67.0 $ 0.1 $ 125.5 $ 6.2 2023 2,629.9 (a) 278.5 60.0 26.6 289.8 0.1 0.5 6.2 2024 1,462.2 (b) 96.0 95.0 113.5 16.8 0.1 0.6 31.2 2025 1,762.4 324.5 90.0 443.9 195.9 0.1 125.6 6.2 2026 1,497.9 75.0 425.0 30.9 — 0.1 50.6 906.2 After 2026 24,246.7 3,732.0 3,616.0 3,887.4 2,656.3 3,000.2 1,625.3 2,469.3 Principal Amount 33,752.9 5,222.0 4,390.0 4,983.0 3,225.8 3,000.7 1,928.1 3,425.3 Unamortized Discount, Net and Debt Issuance Costs (298.4) (41.2) (46.1) (44.1) (30.8) (32.2) (14.6) (30.1) Total Long-term Debt Outstanding $ 33,454.5 (c) $ 5,180.8 $ 4,343.9 $ 4,938.9 $ 3,195.0 $ 2,968.5 $ 1,913.5 $ 3,395.2 (a) Amount includes $850 million of Junior Subordinated Notes. See “Equity Units” section below for additional information. (b) Amount includes $805 million of Junior Subordinated Notes. See “Equity Units” section below for additional information. (c) Amount excludes $1.1 billion of Total Long-term Debt Outstanding classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
Dividend Payment Restrictions	AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Restricted Retained Earnings $ 2,655.2 (a) $ 791.8 $ — $ 313.4 $ 648.5 $ — $ — $ 577.9 (a) Includes the restrictions of consolidated and non-consolidated subsidiaries.
Lines of Credit and Short-term Debt	December 31, 2021 2020 Company Type of Debt Outstanding Interest Outstanding Interest (in millions) (in millions) AEP Securitized Debt for Receivables (b) $ 750.0 0.19 % $ 592.0 0.85 % AEP Commercial Paper 1,364.0 0.34 % 1,852.3 0.29 % AEP 364-Day Term Loan 500.0 0.81 % — — % SWEPCo Notes Payable — — % 35.0 2.55 % Total Short-term Debt $ 2,614.0 $ 2,479.3 (a) Weighted-average rate. (b) Amount of securitized debt for receivables as accounted for under the “Transfers and Servicing” accounting guidance.
Utility Money Pool Participants' Money Pool Activity and Authorized Borrowing Limits	Year Ended December 31, 2021: Maximum Average Net Loans to Borrowings Maximum Borrowings Average (Borrowings from) Authorized from the Loans to the from the Loans to the the Utility Money Short-term Utility Utility Utility Utility Pool as of Borrowing Company Money Pool Money Pool Money Pool Money Pool December 31, 2021 Limit (in millions) AEP Texas $ 355.5 $ 104.7 $ 172.5 $ 40.0 $ (26.9) $ 500.0 AEPTCo 444.9 117.3 189.1 29.7 (108.0) (b) 820.0 (a) APCo 199.3 616.9 87.5 118.3 (178.5) 500.0 I&M 166.5 368.2 110.4 67.7 (71.8) 500.0 OPCo 259.2 622.9 61.6 127.2 42.0 500.0 PSO 267.7 747.3 134.0 113.1 (72.3) 400.0 SWEPCo 280.3 561.9 142.4 287.4 153.8 400.0 Year Ended December 31, 2020: Maximum Average Net Loans to Borrowings Maximum Borrowings Average (Borrowings from) Authorized from the Loans to the from the Loans to the the Utility Money Short-term Utility Utility Utility Utility Pool as of Borrowing Company Money Pool Money Pool Money Pool Money Pool December 31, 2020 Limit (in millions) AEP Texas $ 320.4 $ 313.4 $ 132.0 $ 139.0 $ (67.1) $ 500.0 AEPTCo 358.4 259.7 116.3 55.0 (155.4) 820.0 (a) APCo 434.3 189.0 242.8 76.3 2.8 500.0 I&M 218.6 13.4 114.5 13.3 (89.7) 500.0 OPCo 353.9 32.8 182.4 25.2 (259.2) 500.0 PSO 155.4 57.1 72.3 28.4 (155.4) 300.0 SWEPCo 178.9 — 113.0 — (124.6) 350.0 (a) Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions. (b) Amount excludes $1 million of Advances from Affiliates classified as Liabilities Held for Sale on the AEP Transco balance sheet. See “Dispositions of KPCo and KTCo” section of Note 7 for additional information.
Nonutility Money Pool Activity	Year Ended December 31, 2021: Maximum Loans Average Loans Loans to the Nonutility to the Nonutility to the Nonutility Money Pool as of Company Money Pool Money Pool December 31, 2021 (in millions) AEP Texas $ 7.1 $ 6.9 $ 6.9 SWEPCo 2.1 2.1 2.1 Year Ended December 31, 2020: Maximum Loans Average Loans Loans to the Nonutility to the Nonutility to the Nonutility Money Pool as of Company Money Pool Money Pool December 31, 2020 (in millions) AEP Texas $ 7.5 $ 7.1 $ 7.1 SWEPCo 2.1 2.1 2.1
Direct Borrowing Activity	Year Ended December 31, 2021: Maximum Maximum Average Average Borrowings from Loans to Authorized Borrowings Loans Borrowings Loans AEP as of AEP as of Short-term from AEP to AEP from AEP to AEP December 31, 2021 December 31, 2021 Borrowing Limit (in millions) $ 14.6 $ 224.2 $ 1.8 $ 118.0 $ 1.5 $ 12.7 $ 50.0 (a) Year Ended December 31, 2020: Maximum Maximum Average Average Borrowings from Loans to Authorized Borrowings Loans Borrowings Loans AEP as of AEP as of Short-term from AEP to AEP from AEP to AEP December 31, 2020 December 31, 2020 Borrowing Limit (in millions) $ 1.4 $ 215.3 $ 1.3 $ 132.6 $ 1.2 $ 109.0 $ 50.0 (a) (a) Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions.
Maximum and Minimum Interest Rates for Funds Either Borrowed from or Loaned to Utility Money Pool	Years Ended December 31, 2021 2020 2019 Maximum Interest Rate 0.48 % 2.70 % 3.43 % Minimum Interest Rate 0.02 % 0.27 % 1.77 %
Average Interest Rates for Funds Borrowed from and Loaned to Utility Money Pool	Average Interest Rate for Funds Borrowed Average Interest Rate for Funds Loaned Company 2021 2020 2019 2021 2020 2019 AEP Texas 0.33 % 1.51 % 2.63 % 0.26 % 0.81 % 2.03 % AEPTCo 0.32 % 1.29 % 2.64 % 0.10 % 1.99 % 2.41 % APCo 0.41 % 2.12 % 2.45 % 0.25 % 0.85 % 2.66 % I&M 0.33 % 1.07 % 2.34 % 0.23 % 1.18 % 2.60 % OPCo 0.27 % 0.99 % 2.67 % 0.14 % 2.06 % 2.68 % PSO 0.34 % 0.92 % 2.85 % 0.07 % 1.95 % 2.27 % SWEPCo 0.26 % 1.27 % 2.72 % 0.18 % — % 2.22 %
Maximum, Minimum and Average Interest Rates for Funds Borrowed from and Loaned to the Nonutility Money Pool	Maximum Interest Rate Minimum Interest Rate Average Interest Rate Year Ended for Funds Loaned to for Funds Loaned to for Funds Loaned to December 31, Company the Nonutility Money Pool the Nonutility Money Pool the Nonutility Money Pool 2021 AEP Texas 0.58 % 0.21 % 0.37 % 2021 SWEPCo 0.58 % 0.21 % 0.37 % 2020 AEP Texas 2.70 % 0.27 % 1.18 % 2020 SWEPCo 2.70 % 0.27 % 1.18 % 2019 AEP Texas 3.02 % 1.91 % 2.56 % 2019 SWEPCo 3.02 % 1.91 % 2.55 %
Maximum Minimum and Average Interest Rates for Funds Borrowed from and Loaned to AEP	Maximum Minimum Maximum Minimum Average Average Interest Rate Interest Rate Interest Rate Interest Rate Interest Rate Interest Rate for Funds for Funds for Funds for Funds for Funds for Funds Year Ended Borrowed from Borrowed from Loaned to Loaned to Borrowed from Loaned to December 31, AEP AEP AEP AEP AEP AEP 2021 0.86 % 0.25 % 0.86 % 0.25 % 0.38 % 0.35 % 2020 2.70 % 0.27 % 2.70 % 0.27 % 1.20 % 1.13 % 2019 3.02 % 1.91 % 3.02 % 1.91 % 2.55 % 2.51 %
Comparative Accounts Receivable Information	Years Ended December 31, 2021 2020 2019 (dollars in millions) Effective Interest Rates on Securitization of Accounts Receivable 0.19 % 0.85 % 2.42 % Net Uncollectible Accounts Receivable Written Off $ 26.5 $ 15.3 $ 26.6
Customer Accounts Receivable Managed Portfolio	December 31, 2021 2020 (in millions) Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts $ 995.2 $ 958.4 Short-term – Securitized Debt of Receivables 750.0 592.0 Delinquent Securitized Accounts Receivable 57.9 62.3 Bad Debt Reserves Related to Securitization 42.8 60.0 Unbilled Receivables Related to Securitization 307.1 296.8
Accounts Receivable and Accrued Unbilled Revenues	December 31, Company 2021 2020 (in millions) APCo $ 153.1 $ 136.0 I&M 156.9 170.5 OPCo 392.7 398.8 PSO 114.5 85.0 SWEPCo 153.0 158.6
Fees Paid to AEP Credit for Customer Accounts Receivable Sold	Years Ended December 31, Company 2021 (a) 2020 2019 (in millions) APCo $ 4.9 $ 5.2 $ 7.4 I&M 7.0 7.9 11.1 OPCo 8.3 24.1 27.1 PSO 3.4 4.8 7.8 SWEPCo 5.4 6.7 10.2
Proceeds on Sale of Receivables to AEP Credit	Years Ended December 31, Company 2021 2020 2019 (in millions) APCo $ 1,324.1 $ 1,272.9 $ 1,310.3 I&M 1,927.0 1,891.8 1,824.2 OPCo 2,458.5 2,366.2 2,293.6 PSO 1,406.4 1,221.0 1,442.5 SWEPCo 1,636.1 1,593.8 1,618.5

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	12 Months Ended
Stock-Based Compensation (Tables)	Dec. 31, 2021
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance Units and Reinvested Dividends on Outstanding Performance Units	Years Ended December 31, Performance Shares 2021 2020 2019 Awarded Shares (in thousands) 565.0 424.8 535.0 Weighted-Average Share Fair Value at Grant Date $ 81.02 $ 116.56 $ 83.21 Vesting Period (in years) 3 3 3 Performance Shares and AEP Career Shares Years Ended December 31, 2021 2020 2019 Awarded Shares (in thousands) 74.5 73.4 66.4 Weighted-Average Fair Value at Grant Date $ 84.48 $ 84.87 $ 88.73 Vesting Period (in years) (a) (a) (a)
Summary of Performance Scores and Performance Units Earned	Years Ended December 31, Performance Shares 2021 2020 2019 Certified Performance Score 102.9 % 128.2 % 132.7 % Performance Shares Earned 537,166 757,858 792,897 Performance Shares Mandatorily Deferred as AEP Career Shares 14,613 13,614 10,063 Performance Shares Voluntarily Deferred into the Incentive Compensation Deferral Program 22,915 26,936 49,392 Performance Shares to be Settled (a) 499,638 717,308 733,442 (a) Performance shares settled in AEP common stock in the quarter following the end of the year shown.
Summary of Cash Payouts for Performance Units and Career Shares	Years Ended December 31, Performance Shares and AEP Career Shares 2021 2020 2019 (in millions) Cash Settlements for Performance Units $ — $ — $ 58.3 AEP Common Stock Settlements for Performance Shares 54.7 75.4 — AEP Common Stock Settlements for Career Share Distributions 4.0 1.9 6.6
Status of Nonvested Performance Units	Nonvested Performance Shares Shares Weighted (in thousands) Nonvested as of January 1, 2021 938.6 $ 98.05 Awarded 565.0 81.02 Dividends 53.4 84.45 Vested (a) (529.0) 83.87 Forfeited (104.2) 87.65 Nonvested as of December 31, 2021 923.8 96.15 (a) The vested Performance Shares will be converted to 500 thousand shares based on the closing share price on the day before settlement.
Monte Carlo Valuation Assumptions	Years Ended December 31, Assumptions 2021 2020 2019 Valuation Period (in years) (a) 2.88 2.87 2.87 Expected Volatility Minimum 25.87 % 13.67 % 14.83 % Expected Volatility Maximum 39.90 % 28.15 % 25.57 % Expected Volatility Average 31.01 % 16.39 % 17.39 % Dividend Rate (b) — % — % — % Risk Free Rate 0.19 % 1.40 % 2.49 % (a) Period from award date to vesting date. (b) Equivalent to reinvesting dividends.
Summary of Units Awarded and Fair Value of Restricted Stock Units	Years Ended December 31, Restricted Stock Units 2021 2020 2019 Awarded Units (in thousands) 280.0 268.7 304.8 Weighted-Average Grant Date Fair Value $ 80.39 $ 94.38 $ 81.57
Total Fair Value and Total Intrinsic Value of Restricted Shares and Restricted Stock Units Vested	Years Ended December 31, Restricted Stock Units 2021 2020 2019 (in millions) Fair Value of Restricted Stock Units Vested $ 20.5 $ 22.9 $ 16.3 Intrinsic Value of Restricted Stock Units Vested (a) 22.0 25.2 21.6 (a) Intrinsic value is calculated as market price at the vesting date.
Status of Nonvested Restricted Shares and Restricted Stock Units	Nonvested Restricted Stock Units Shares/Units Weighted (in thousands) Nonvested as of January 1, 2021 448.0 $ 86.56 Awarded 280.0 80.39 Vested (250.5) 81.92 Forfeited (53.2) 85.80 Nonvested as of December 31, 2021 424.3 84.86
Stock Unit Accumulation Plan for Non-employee Directors	Years Ended December 31, Stock Unit Accumulation Plan for Non-Employee Directors 2021 2020 2019 Awarded Units (in thousands) 12.6 12.1 10.0 Weighted-Average Grant Date Fair Value $ 84.54 $ 83.80 $ 89.13
Compensation Cost and Actual Tax Benefit Realized for Tax Deductions from Compensation Cost for Share-based Payment Arrangements	Years Ended December 31, Share-based Compensation Plans 2021 2020 2019 (in millions) Compensation Cost for Share-based Payment Arrangements (a) $ 61.1 $ 53.8 $ 57.9 Actual Tax Benefit 8.7 7.2 8.4 Total Compensation Cost Capitalized 16.9 20.4 20.0 (a) Compensation cost for share-based payment arrangements is included in Other Operation and Maintenance expenses on the statements of income.

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
Related Party Transactions (Tables)	Dec. 31, 2021
Affiliated Revenues	Related Party Revenues AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Year Ended December 31, 2021 Direct Sales to East Affiliates $ — $ — $ 128.6 $ — $ — $ — $ — Transmission Revenues — 1,136.1 60.3 (2.5) (1.1) — 39.6 Other Revenues 3.9 17.8 9.0 6.3 25.9 4.2 1.4 Total Affiliated Revenues $ 3.9 $ 1,153.9 $ 197.9 $ 3.8 $ 24.8 $ 4.2 $ 41.0 Related Party Revenues AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Year Ended December 31, 2020 Direct Sales to East Affiliates $ — $ — $ 112.5 $ — $ — $ — $ — Auction Sales to OPCo (a) — — 5.3 3.1 — — — Direct Sales to AEPEP 87.5 — — — — — — Transmission Revenues — 885.0 49.1 2.9 16.6 — 37.4 Other Revenues 3.3 11.3 7.8 4.5 24.9 5.2 1.6 Total Affiliated Revenues $ 90.8 $ 896.3 $ 174.7 $ 10.5 $ 41.5 $ 5.2 $ 39.0 Related Party Revenues AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Year Ended December 31, 2019 Direct Sales to East Affiliates $ — $ — $ 128.6 $ — $ — $ — $ — Auction Sales to OPCo (a) — — 11.4 6.7 — — — Direct Sales to AEPEP 157.2 — — — — — (0.1) Transmission Revenues — 795.5 58.5 0.7 7.7 1.3 3.6 Other Revenues 3.3 11.2 6.8 3.1 19.6 4.8 1.4 Total Affiliated Revenues $ 160.5 $ 806.7 $ 205.3 $ 10.5 $ 27.3 $ 6.1 $ 4.9 (a) Refer to the Ohio Auctions section below for further information regarding these amounts.
Affiliated Purchases	Related Party Purchases I&M OPCo (in millions) Year Ended December 31, 2021 Auction Purchases from AEPEP (a) $ — $ 26.6 Auction Purchases from AEP Energy (a) — 25.3 Direct Purchases from AEGCo 217.9 — Total Affiliated Purchases $ 217.9 $ 51.9 Related Party Purchases I&M OPCo (in millions) Year Ended December 31, 2020 Auction Purchases from AEPEP (a) $ — $ 51.0 Auction Purchases from AEP Energy (a) — 58.7 Auction Purchases from AEPSC (a) — 10.0 Direct Purchases from AEGCo 172.8 — Total Affiliated Purchases $ 172.8 $ 119.7 Related Party Purchases I&M OPCo (in millions) Year Ended December 31, 2019 Auction Purchases from AEPEP (a) $ — $ 64.6 Auction Purchases from AEP Energy (a) — 69.9 Auction Purchases from AEPSC (a) — 21.5 Direct Purchases from AEGCo 214.9 — Total Affiliated Purchases $ 214.9 $ 156.0 (a) Refer to the Ohio Auctions section below for further information regarding this amount.
PJM Transmission Service Charges	Years Ended December 31, Company 2021 2020 2019 (in millions) APCo $ 302.0 $ 243.2 $ 222.3 I&M 186.7 145.9 143.5 OPCo 508.9 417.4 373.4
SPP Transmission Service Charges	Years Ended December 31, Company 2021 2020 2019 (in millions) PSO $ 94.7 $ 69.7 $ 46.9 SWEPCo 56.2 31.3 20.1
Joint License Agreement	Years Ended December 31, Billing Company 2021 2020 2019 (in millions) APCo $ 2.4 $ 0.9 $ 0.2 I&M 4.8 3.0 1.5 KPCo 0.5 0.4 0.3 OPCo 4.6 4.5 2.2 PSO 0.4 0.4 0.3 WPCo 0.2 0.2 0.1
Railcar Maintenance	Years Ended December 31, Company 2021 2020 2019 (in millions) I&M $ 0.3 $ 0.9 $ 1.3 PSO 0.4 0.7 0.8 SWEPCo 2.8 3.0 4.0
Barging, Urea Transloading and Other Services	Years Ended December 31, Company 2021 2020 2019 (in millions) AEGCo $ 7.6 $ 10.6 $ 14.9 APCo 40.1 43.7 38.9 KPCo 3.1 3.2 4.8 WPCo 3.2 3.3 4.8
Central Machine Shop	Years Ended December 31, Company 2021 2020 2019 (in millions) AGR $ 0.4 $ 2.9 $ 0.8 I&M 2.4 3.2 2.3 KPCo 1.0 0.9 1.4 OPCo 0.4 — — PSO 0.7 0.9 1.1 SWEPCo 2.7 0.5 1.1
Related Party Sales of Property	Sales Years Ended December 31, Company 2021 2020 2019 (in millions) AEP Texas $ 0.4 $ 0.9 $ 0.9 AEPTCo 1.4 0.2 — APCo 6.2 5.7 5.5 I&M 7.0 1.5 7.5 OPCo 9.2 7.0 7.0 PSO 0.5 1.1 0.8 SWEPCo 0.4 0.8 0.2
Related Party Purchases of Property	Purchases Years Ended December 31, Company 2021 2020 2019 (in millions) AEP Texas $ 0.4 $ 1.5 $ 0.3 AEPTCo 16.7 6.0 10.2 APCo 1.0 1.3 6.0 I&M 0.6 3.4 0.9 OPCo 1.4 1.2 3.0 PSO 0.3 0.4 0.5 SWEPCo 0.3 2.8 0.7
Charitable Contribution to AEP Foundation [Table Text Block]	Year Ended Company December 31, 2019 (in millions) AEP $ 50.0 AEP Texas 6.2 AEPTCo 6.5 APCo 8.9 I&M 9.0 OPCo 5.4 PSO 3.4 SWEPCo 5.5

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	12 Months Ended
Variable Interest Entities (Tables)	Dec. 31, 2021
Consolidated Assets And Liabilities Of Variable Interest Entities	American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities December 31, 2021 Registrant Subsidiaries SWEPCo I&M AEP Texas Transition Funding AEP Texas Restoration Funding APCo (in millions) ASSETS Current Assets $ 77.2 $ 65.2 $ 24.9 $ 24.3 $ 16.0 Net Property, Plant and Equipment 51.8 118.6 — — — Other Noncurrent Assets 104.1 57.2 208.3 (a) 192.6 (b) 187.8 (c) Total Assets $ 233.1 $ 241.0 $ 233.2 $ 216.9 $ 203.8 LIABILITIES AND EQUITY Current Liabilities $ 18.9 $ 65.1 $ 71.2 $ 36.1 $ 29.0 Noncurrent Liabilities 214.3 175.9 157.8 179.6 172.9 Equity (0.1) — 4.2 1.2 1.9 Total Liabilities and Equity $ 233.1 $ 241.0 $ 233.2 $ 216.9 $ 203.8 (a) Includes an intercompany item eliminated in consolidation of $24 million. (b) Includes an intercompany item eliminated in consolidation of $8 million. (c) Includes an intercompany item eliminated in consolidation of $2 million. American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities December 31, 2021 Other Consolidated VIEs AEP Credit Protected Transource Energy Apple Blossom and Black Oak Santa Rita East Dry Lake (in millions) ASSETS Current Assets $ 996.6 $ 217.3 $ 38.8 $ 9.9 $ 7.6 $ 4.0 Net Property, Plant and Equipment — — 475.4 217.3 437.6 146.1 Other Noncurrent Assets 10.4 — 3.0 11.3 — 0.3 Total Assets $ 1,007.0 $ 217.3 $ 517.2 $ 238.5 $ 445.2 $ 150.4 LIABILITIES AND EQUITY Current Liabilities $ 953.1 $ 37.5 $ 12.5 $ 6.6 $ 5.8 $ 0.9 Noncurrent Liabilities 0.9 82.3 216.9 5.2 7.0 0.6 Equity 53.0 97.5 287.8 226.7 432.4 148.9 Total Liabilities and Equity $ 1,007.0 $ 217.3 $ 517.2 $ 238.5 $ 445.2 $ 150.4 American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities December 31, 2020 Registrant Subsidiaries SWEPCo I&M AEP Texas Transition Funding AEP Texas Restoration Funding APCo (in millions) ASSETS Current Assets $ 88.0 $ 76.1 $ 61.2 $ 23.3 $ 16.8 Net Property, Plant and Equipment 97.3 138.9 — — — Other Noncurrent Assets 99.3 70.9 273.9 (a) 214.9 (b) 212.7 (c) Total Assets $ 284.6 $ 285.9 $ 335.1 $ 238.2 $ 229.5 LIABILITIES AND EQUITY Current Liabilities $ 57.7 $ 76.0 $ 69.8 $ 33.9 $ 28.7 Noncurrent Liabilities 225.3 209.9 246.5 203.1 198.9 Equity 1.6 — 18.8 1.2 1.9 Total Liabilities and Equity $ 284.6 $ 285.9 $ 335.1 $ 238.2 $ 229.5 (a) Includes an intercompany item eliminated in consolidation of $32 million. (b) Includes an intercompany item eliminated in consolidation of $9 million. (c) Includes an intercompany item eliminated in consolidation of $3 million. American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities December 31, 2020 Other Consolidated VIEs AEP Credit Protected Transource Energy Apple Blossom and Black Oak Santa Rita East (in millions) ASSETS Current Assets $ 960.4 $ 198.1 $ 22.2 $ 9.6 $ 6.0 Net Property, Plant and Equipment — — 458.7 223.1 453.1 Other Noncurrent Assets 12.9 — 3.7 12.1 — Total Assets $ 973.3 $ 198.1 $ 484.6 $ 244.8 $ 459.1 LIABILITIES AND EQUITY Current Liabilities $ 827.2 $ 43.1 $ 32.6 $ 5.3 $ 3.5 Noncurrent Liabilities 0.8 62.5 185.0 4.9 6.7 Equity 145.3 92.5 267.0 234.6 448.9 Total Liabilities and Equity $ 973.3 $ 198.1 $ 484.6 $ 244.8 $ 459.1
SWEPCo's Investment In DHLC	December 31, 2021 2020 As Reported on Maximum As Reported on Maximum (in millions) Capital Contribution from SWEPCo $ 7.6 $ 7.6 $ 7.6 $ 7.6 Retained Earnings 23.8 23.8 20.4 20.4 SWEPCo’s Share of Obligations — 50.3 — 98.5 Total Investment in DHLC $ 31.4 $ 81.7 $ 28.0 $ 126.5
AEP's Investment In OVEC	December 31, 2021 2020 As Reported on Maximum As Reported on Maximum Exposure (in millions) Capital Contribution from AEP $ 4.4 $ 4.4 $ 4.4 $ 4.4 AEP’s Ratio of OVEC Debt (a) — 492.0 — 555.0 Total Investment in OVEC $ 4.4 $ 496.4 $ 4.4 $ 559.4
Purchased Power from OVEC	Years Ended December 31, Company 2021 2020 2019 (in millions) APCo $ 104.3 $ 94.4 $ 104.5 I&M 52.2 47.2 52.3 OPCo 133.0 120.8 132.7
Billings from Significant Variable Interest	Years Ended December 31, Company 2021 2020 2019 (in millions) AEP Texas $ 206.9 $ 199.4 $ 206.6 AEPTCo 267.1 270.3 242.3 APCo 313.3 294.9 308.3 I&M 200.9 210.2 184.8 OPCo 234.9 232.8 230.4 PSO 123.7 113.2 125.7 SWEPCo 168.6 161.8 169.5
Carrying Amount and Classification of Variable Interest in Accounts Payable	December 31, 2021 2020 Company As Reported on Maximum As Reported on Maximum (in millions) AEP Texas $ 22.2 $ 22.2 $ 30.5 $ 30.5 AEPTCo 23.3 23.3 45.9 45.9 APCo 44.1 44.1 42.8 42.8 I&M 21.8 21.8 27.1 27.1 OPCo 25.5 25.5 33.9 33.9 PSO 13.7 13.7 15.7 15.7 SWEPCo 20.5 20.5 22.0 22.0

Property, Plant and Equipment_2

Property, Plant and Equipment (Tables)	12 Months Ended
Property, Plant and Equipment (Tables)	Dec. 31, 2021
Property, Plant and Equipment	December 31, 2021 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Regulated Property, Plant and Equipment Generation $ 21,196.8 (a) $ — $ — $ 6,683.9 $ 5,531.8 $ — $ 1,802.4 $ 4,734.5 (a) Transmission 29,866.0 5,849.9 10,886.3 4,322.4 1,783.1 2,992.8 1,107.7 2,316.9 Distribution 24,440.0 4,917.2 — 4,683.3 2,800.1 6,070.6 3,004.9 2,514.3 Other 5,249.8 958.7 427.2 668.9 755.1 982.2 433.5 542.0 CWIP 3,632.4 (a) 551.3 1,394.8 469.9 302.8 365.0 156.0 240.7 (a) Less: Accumulated Depreciation 20,375.5 1,642.9 772.9 5,047.4 3,885.3 2,457.4 1,707.0 3,002.2 Total Regulated Property, Plant and Equipment - Net 64,009.5 10,634.2 11,935.4 11,781.0 7,287.6 7,953.2 4,797.5 7,346.2 Nonregulated Property, Plant and Equipment - Net 1,991.8 1.2 0.3 23.3 23.3 9.8 5.3 53.9 Total Property, Plant and Equipment - Net $ 66,001.3 (b) $ 10,635.4 $ 11,935.7 (b) $ 11,804.3 $ 7,310.9 $ 7,963.0 $ 4,802.8 $ 7,400.1 December 31, 2020 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Regulated Property, Plant and Equipment Generation $ 21,587.8 (a) $ — $ — $ 6,633.7 $ 5,264.7 $ — $ 1,480.7 $ 4,681.4 (a) Transmission 27,841.5 5,279.6 9,593.5 3,900.5 1,696.4 2,831.9 1,069.9 2,165.7 Distribution 23,972.1 4,580.8 — 4,464.3 2,594.6 5,708.3 2,853.0 2,382.5 Other 4,852.4 866.0 328.8 598.0 644.6 888.5 388.1 564.5 CWIP 3,815.0 (a) 614.1 1,422.6 484.6 362.4 362.3 128.7 228.3 (a) Less: Accumulated Depreciation 20,094.2 1,528.1 572.8 4,711.0 3,538.6 2,348.8 1,607.3 3,032.0 Total Regulated Property, Plant and Equipment - Net 61,974.6 9,812.4 10,772.1 11,370.1 7,024.1 7,442.2 4,313.1 6,990.4 Nonregulated Property, Plant and Equipment - Net 1,927.0 1.2 0.7 24.0 28.2 9.9 6.9 97.8 Total Property, Plant and Equipment - Net $ 63,901.6 $ 9,813.6 $ 10,772.8 $ 11,394.1 $ 7,052.3 $ 7,452.1 $ 4,320.0 $ 7,088.2 (a) AEP and SWEPCo’s regulated generation and regulated CWIP include amounts related to SWEPCo’s Arkansas jurisdictional share of the Turk Plant. (b) Amount excludes $2.3 billion and $165 million for AEP and AEPTCo, respectively, of Property, Plant and Equipment - Net classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
Depreciation, Depletion and Amortization - Regulated	AEP 2021 2020 2019 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 2.7% - 7.8% 20 - 132 2.7% - 6.3% 20 - 132 2.5% - 5.5% 20 - 132 Transmission 2.0% - 2.6% 15 - 75 2.0% - 2.6% 15 - 75 1.8% - 2.6% 15 - 81 Distribution 2.8% - 3.6% 7 - 80 2.7% - 3.7% 7 - 78 2.7% - 3.7% 7 - 78 Other 3.0% - 12.5% 5 - 75 2.8% - 11.3% 5 - 75 2.6% - 9.5% 5 - 75 AEP Texas 2021 2020 2019 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Transmission 2.2% 50 - 75 2.0% 50 - 75 1.8% 45 - 81 Distribution 2.9% 7 - 70 3.1% 7 - 70 3.5% 7 - 70 Other 5.8% 5 - 50 6.1% 5 - 50 6.3% 5 - 50 AEPTCo 2021 2020 2019 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Transmission 2.5% 24 - 75 2.4% 24 - 75 2.0% 24 - 75 Other 6.7% 5 - 56 6.3% 5 - 64 5.8% 5 - 64 APCo 2021 2020 2019 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 3.6% 35 - 118 3.3% 35 - 118 3.2% 35 - 118 Transmission 2.1% 15 - 75 2.2% 15 - 75 1.8% 15 - 71 Distribution 3.5% 12 - 57 3.7% 12 - 57 3.7% 12 - 57 Other 8.5% 5 - 55 7.8% 5 - 55 7.2% 5 - 55 I&M 2021 2020 2019 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 4.7% 20 - 132 4.6% 20 - 132 4.0% 20 - 132 Transmission 2.4% 45 - 70 2.3% 45 - 70 1.9% 50 - 73 Distribution 3.4% 14 - 71 3.4% 14 - 71 3.4% 9 - 75 Other 9.0% 5 - 51 10.2% 5 - 51 9.4% 5 - 50 OPCo 2021 2020 2019 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Transmission 2.3% 39 - 60 2.3% 39 - 60 2.3% 39 - 60 Distribution 2.9% 11 - 70 3.1% 14 - 65 3.1% 14 - 65 Other 6.1% 5 - 50 5.0% 5 - 50 4.9% 5 - 50 PSO 2021 2020 2019 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 2.8% 30 - 75 3.1% 35 - 75 2.9% 35 - 75 Transmission 2.4% 42 - 75 2.2% 45 - 75 2.4% 45 - 75 Distribution 2.9% 15 - 78 2.9% 15 - 78 2.9% 15 - 78 Other 6.1% 5 - 56 5.7% 5 - 64 5.6% 5 - 64 SWEPCo 2021 2020 2019 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 2.7% 30 - 65 2.7% 35 - 65 2.5% 40 - 70 Transmission 2.4% 49 - 74 2.3% 47 - 73 2.4% 50 - 73 Distribution 2.8% 15 - 80 2.7% 15 - 67 2.7% 25 - 70 Other 8.6% 5 - 58 8.5% 5 - 52 7.6% 5 - 55
Depreciation, Depletion and Amortization - Unregulated	2021 2020 2019 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 3.8% - 10.4% 10 - 59 3.6% - 4.0% 15 - 59 3.2% - 21.2% 15 - 59 Transmission 2.6% 30 - 40 2.5% 30 - 40 2.5% 30 - 40 Distribution NA NA NA NA 2.3% 40 Other 16.5% 5 - 35 (a) 16.1% 5 - 50 17.6% 5 - 50 (a) In 2020 management announced plans to retire the Pirkey Plant in 2023 and the related depreciable lives have been adjusted accordingly. See Note 5 - Effects of Regulation for additional information. NA Not applicable.
Asset Retirement Obligation (ARO)	Company ARO as of December 31, 2020 Accretion Liabilities Liabilities Revisions in ARO as of December 31, 2021 (in millions) AEP (b)(c)(d)(e)(f) $ 2,516.7 $ 105.0 $ 22.8 $ (41.4) $ 138.6 $ 2,741.7 AEP Texas (b)(e) 4.6 0.2 — (0.4) — 4.4 APCo (b)(e) 313.1 13.7 — (6.9) 84.7 404.6 I&M (b)(c)(e) 1,813.8 72.9 0.3 (0.1) 59.4 1,946.3 OPCo (e) 1.9 0.1 — (0.1) — 1.9 PSO (b)(e) 47.4 3.3 7.6 (0.7) — 57.6 SWEPCo (b)(d)(e) 222.1 9.8 9.2 (20.9) 2.5 222.7 Company ARO as of December 31, 2019 Accretion Liabilities Liabilities Revisions in ARO as of December 31, 2020 (in millions) AEP (b)(c)(d)(e) $ 2,418.9 $ 102.4 $ 0.3 $ (188.0) $ 183.1 $ 2,516.7 AEP Texas (b)(e) 29.1 0.8 — (8.5) (16.8) 4.6 APCo (b)(e) 111.1 8.9 — (7.8) 200.9 313.1 I&M (b)(c)(e) 1,748.6 70.2 0.1 (0.2) (4.9) 1,813.8 OPCo (e) 1.8 0.1 — — — 1.9 PSO (b)(e) 52.2 3.1 — (3.1) (4.8) 47.4 SWEPCo (b)(d)(e) 212.2 10.7 — (10.9) 10.1 222.1 (a) Unless discussed above, primarily related to ash ponds, landfills and mine reclamation, generally due to changes in estimated closure area, volumes and/or unit costs. (b) Includes ARO related to ash disposal facilities. (c) Includes ARO related to nuclear decommissioning costs for the Cook Plant of $1.93 billion and $1.80 billion as of December 31, 2021 and 2020, respectively. (d) Includes ARO related to Sabine and DHLC. (e) Includes ARO related to asbestos removal. (f) Includes $18 million of ARO classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
Allowance For Equity Funds Used During Construction	Years Ended December 31, Company 2021 2020 2019 (in millions) AEP $ 139.7 $ 148.1 $ 168.4 AEP Texas 21.5 19.4 15.2 AEPTCo 67.2 74.0 84.3 APCo 15.6 14.6 16.6 I&M 12.8 11.5 19.4 OPCo 10.8 12.5 18.2 PSO 2.4 4.0 2.7 SWEPCo 7.0 7.7 6.8
Allowance For Borrowed Funds Used During Construction	Years Ended December 31, Company 2021 2020 2019 (in millions) AEP $ 53.8 $ 66.0 $ 88.7 AEP Texas 10.5 12.5 20.0 AEPTCo 21.0 25.5 32.2 APCo 7.5 7.9 9.3 I&M 5.1 5.7 8.9 OPCo 4.7 6.2 6.7 PSO 0.7 2.0 1.9 SWEPCo 3.0 3.9 4.0
Jointly-owned Electric Facilities	Registrant’s Share as of December 31, 2021 Fuel Percent of Utility Plant Construction Accumulated (in millions) AEP Dolet Hills Power Station, Unit 1 (a) Lignite 40.2 % $ — $ — $ — Flint Creek Generating Station, Unit 1 (b) Coal 50.0 % 377.6 6.3 133.5 Pirkey Power Plant, Unit 1 (b) Lignite 85.9 % 613.8 — 528.3 Turk Generating Plant (b) Coal 73.3 % 1,598.0 10.2 285.6 Total $ 2,589.4 $ 16.5 $ 947.4 I&M Rockport Generating Plant (c)(d)(e) Coal 50.0 % $ 1,247.2 $ 13.9 $ 794.5 PSO North Central Wind Energy Facilities (f)(g) Wind 45.5 % $ 313.7 $ — $ 4.2 SWEPCo Dolet Hills Power Station, Unit 1 (a) Lignite 40.2 % $ — $ — $ — Flint Creek Generating Station, Unit 1 (b) Coal 50.0 % 377.6 6.3 133.5 Pirkey Power Plant, Unit 1 (b) Lignite 85.9 % 613.8 — 528.3 Turk Generating Plant (b) Coal 73.3 % 1,598.0 10.2 285.6 North Central Wind Energy Facilities (f)(g) Wind 54.5 % 376.2 — 5.4 Total $ 2,965.6 $ 16.5 $ 952.8 Registrant’s Share as of December 31, 2020 Fuel Percent of Utility Plant Construction Accumulated (in millions) AEP Dolet Hills Power Station, Unit 1 (a) Lignite 40.2 % $ 342.4 $ 4.6 $ 295.4 Flint Creek Generating Station, Unit 1 (b) Coal 50.0 % 377.2 3.0 116.0 Pirkey Power Plant, Unit 1 (b) Lignite 85.9 % 602.8 3.7 441.0 Turk Generating Plant (b) Coal 73.3 % 1,594.3 2.8 257.3 Total $ 2,916.7 $ 14.1 $ 1,109.7 I&M Rockport Generating Plant (c)(d)(e) Coal 50.0 % $ 1,228.5 $ 19.6 $ 677.3 SWEPCo Dolet Hills Power Station, Unit 1 (a) Lignite 40.2 % $ 342.4 $ 4.6 $ 295.4 Flint Creek Generating Station, Unit 1 (b) Coal 50.0 % 377.2 3.0 116.0 Pirkey Power Plant, Unit 1 (b) Lignite 85.9 % 602.8 3.7 441.0 Turk Generating Plant (b) Coal 73.3 % 1,594.3 2.8 257.3 Total $ 2,916.7 $ 14.1 $ 1,109.7 (a) Operated by CLECO, a nonaffiliated company. The Dolet Hills Power Station was retired in December 2021. (b) Operated by SWEPCo. (c) Operated by I&M. (d) Amounts include I&M’s 50% ownership of both Unit 1 and capital additions for Unit 2. Unit 2 is subject to a finance lease with a nonaffiliated company. See the “Rockport Lease” section of Note 13 for additional information. (e) AEGCo owns 50% of Unit 1 with I&M and 50% of capital additions for Unit 2. (f) PSO and SWEPCo own undivided interests of 45.5% and 54.5% of the NCWF, respectively. Sundance was placed into service in April 2021. Maverick was placed into service in September 2021. See the “Acquisitions” section of Note 7 for additional information. (g) Operated by PSO.

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	12 Months Ended
Revenue from Contracts with Customers (Tables)	Dec. 31, 2021
Disaggregated Revenues from Contracts with Customers	Year Ended December 31, 2021 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation & Marketing Corporate and Other Reconciling Adjustments AEP Consolidated (in millions) Retail Revenues: Residential Revenues $ 3,952.6 $ 2,138.2 $ — $ — $ — $ — $ 6,090.8 Commercial Revenues 2,208.5 1,081.2 — — — — 3,289.7 Industrial Revenues 2,168.2 395.2 — — — (0.8) 2,562.6 Other Retail Revenues 170.6 43.9 — — — — 214.5 Total Retail Revenues 8,499.9 3,658.5 — — — (0.8) 12,157.6 Wholesale and Competitive Retail Revenues: Generation Revenues 942.6 — — 137.9 — — 1,080.5 Transmission Revenues (a) 355.5 572.4 1,456.4 — — (1,206.0) 1,178.3 Renewable Generation Revenues (b) — — — 86.9 — (3.6) 83.3 Retail, Trading and Marketing Revenues (c) — — — 1,722.6 1.4 (51.6) 1,672.4 Total Wholesale and Competitive Retail Revenues 1,298.1 572.4 1,456.4 1,947.4 1.4 (1,261.2) 4,014.5 Other Revenues from Contracts with Customers (b) 187.5 194.2 17.1 7.2 60.1 (115.2) 350.9 Total Revenues from Contracts with Customers 9,985.5 4,425.1 1,473.5 1,954.6 61.5 (1,377.2) 16,523.0 Other Revenues: Alternative Revenues (b) 13.5 48.8 52.7 — — (73.6) 41.4 Other Revenues (b) (d) (0.5) 19.0 — 209.1 10.7 (10.7) 227.6 Total Other Revenues 13.0 67.8 52.7 209.1 10.7 (84.3) 269.0 Total Revenues $ 9,998.5 $ 4,492.9 $ 1,526.2 $ 2,163.7 $ 72.2 $ (1,461.5) $ 16,792.0 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $1.1 billion. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $52 million. The remaining affiliated amounts were immaterial. (d) Generation & Marketing includes economic hedge activity. Year Ended December 31, 2020 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation & Marketing Corporate and Other Reconciling Adjustments AEP Consolidated (in millions) Retail Revenues: Residential Revenues $ 3,606.8 $ 2,086.9 $ — $ — $ — $ — $ 5,693.7 Commercial Revenues 2,016.2 1,048.6 — — — — 3,064.8 Industrial Revenues 2,018.0 390.1 — — — (0.7) 2,407.4 Other Retail Revenues 155.6 42.5 — — — — 198.1 Total Retail Revenues 7,796.6 3,568.1 — — — (0.7) 11,364.0 Wholesale and Competitive Retail Revenues: Generation Revenues 588.3 — — 131.9 — — 720.2 Transmission Revenues (a) 334.5 467.0 1,257.0 — — (1,006.7) 1,051.8 Renewable Generation Revenues (b) — — — 60.9 — (1.6) 59.3 Retail, Trading and Marketing Revenues (c) — — — 1,486.9 (5.5) (103.0) 1,378.4 Total Wholesale and Competitive Retail Revenues 922.8 467.0 1,257.0 1,679.7 (5.5) (1,111.3) 3,209.7 Other Revenues from Contracts with Customers (b) 163.2 157.8 22.4 2.3 92.5 (148.6) 289.6 Total Revenues from Contracts with Customers 8,882.6 4,192.9 1,279.4 1,682.0 87.0 (1,260.6) 14,863.3 Other Revenues: Alternative Revenues (b) (3.2) 70.0 (80.6) — — 7.5 (6.3) Other Revenues (b) (d) — 83.0 — 43.6 9.8 (74.9) 61.5 Total Other Revenues (3.2) 153.0 (80.6) 43.6 9.8 (67.4) 55.2 Total Revenues $ 8,879.4 $ 4,345.9 $ 1,198.8 $ 1,725.6 $ 96.8 $ (1,328.0) $ 14,918.5 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $965 million. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $103 million. The remaining affiliated amounts were immaterial. (d) Generation & Marketing includes economic hedge activity. Year Ended December 31, 2019 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation & Marketing Corporate and Other Reconciling Adjustments AEP Consolidated (in millions) Retail Revenues: Residential Revenues $ 3,643.7 $ 2,069.9 $ — $ — $ — $ — $ 5,713.6 Commercial Revenues 2,155.3 1,152.9 — — — — 3,308.2 Industrial Revenues 2,179.0 429.1 — — — (0.9) 2,607.2 Other Retail Revenues 179.1 43.8 — — — — 222.9 Total Retail Revenues 8,157.1 3,695.7 — — — (0.9) 11,851.9 Wholesale and Competitive Retail Revenues: Generation Revenues 807.6 — — 254.8 — — 1,062.4 Transmission Revenues (a) 292.1 435.1 1,077.2 — — (825.0) 979.4 Renewable Generation Revenues (b) — — — 57.3 — — 57.3 Retail, Trading and Marketing Revenues (c) — — — 1,480.7 — (135.6) 1,345.1 Total Wholesale and Competitive Retail Revenues 1,099.7 435.1 1,077.2 1,792.8 — (960.6) 3,444.2 Other Revenues from Contracts with Customers (b) 168.2 169.4 16.6 4.9 104.7 (147.1) 316.7 Total Revenues from Contracts with Customers 9,425.0 4,300.2 1,093.8 1,797.7 104.7 (1,108.6) 15,612.8 Other Revenues: Alternative Revenues (b) (57.9) 32.3 (20.6) — — (66.9) (113.1) Other Revenues (b) (d) — 150.0 — 59.9 (8.9) (139.3) 61.7 Total Other Revenues (57.9) 182.3 (20.6) 59.9 (8.9) (206.2) (51.4) Total Revenues $ 9,367.1 $ 4,482.5 $ 1,073.2 $ 1,857.6 $ 95.8 $ (1,314.8) $ 15,561.4 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $794 million. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $136 million. The remaining affiliated amounts were immaterial. (d) Generation & Marketing includes economic hedge activity. Year Ended December 31, 2021 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 550.3 $ — $ 1,379.6 $ 805.4 $ 1,587.9 $ 651.9 $ 709.5 Commercial Revenues 358.5 — 556.3 507.2 722.7 378.9 529.3 Industrial Revenues 108.9 — 584.3 557.0 286.3 274.1 344.4 Other Retail Revenues 31.3 — 70.8 5.2 12.6 77.7 10.0 Total Retail Revenues 1,049.0 — 2,591.0 1,874.8 2,609.5 1,382.6 1,593.2 Wholesale Revenues: Generation Revenues (a) — — 302.7 318.1 — 22.9 386.6 Transmission Revenues (b) 497.5 1,393.9 128.8 33.7 74.9 37.5 122.7 Total Wholesale Revenues 497.5 1,393.9 431.5 351.8 74.9 60.4 509.3 Other Revenues from Contracts with Customers (c) 41.2 17.0 70.4 104.1 153.1 31.3 23.5 Total Revenues from Contracts with Customers 1,587.7 1,410.9 3,092.9 2,330.7 2,837.5 1,474.3 2,126.0 Other Revenues: Alternative Revenues (d) 6.1 58.4 12.3 (4.0) 42.6 0.1 5.8 Other Revenues (d) — — — — 19.0 — — Total Other Revenues 6.1 58.4 12.3 (4.0) 61.6 0.1 5.8 Total Revenues $ 1,593.8 $ 1,469.3 $ 3,105.2 $ 2,326.7 $ 2,899.1 $ 1,474.4 $ 2,131.8 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $129 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $1.1 billion. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $60 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. Year Ended December 31, 2020 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 563.6 $ — $ 1,250.6 $ 794.1 $ 1,523.4 $ 579.4 $ 630.8 Commercial Revenues 366.7 — 517.0 499.3 682.0 320.1 466.7 Industrial Revenues 120.1 — 553.5 547.4 270.0 221.1 328.8 Other Retail Revenues 29.5 — 67.6 6.6 13.1 66.0 9.1 Total Retail Revenues 1,079.9 — 2,388.7 1,847.4 2,488.5 1,186.6 1,435.4 Wholesale Revenues: Generation Revenues (a) — — 230.2 274.6 — 15.1 162.0 Transmission Revenues (b) 399.9 1,210.3 130.8 29.0 67.0 27.5 111.2 Total Wholesale Revenues 399.9 1,210.3 361.0 303.6 67.0 42.6 273.2 Other Revenues from Contracts with Customers (c) 48.2 22.4 59.5 85.0 109.5 34.7 26.7 Total Revenues from Contracts with Customers 1,528.0 1,232.7 2,809.2 2,236.0 2,665.0 1,263.9 1,735.3 Other Revenues: Alternative Revenues (d) 3.4 (87.0) (13.0) 5.8 66.6 2.2 3.2 Other Revenues (d) 87.5 — — — 17.5 — — Total Other Revenues 90.9 (87.0) (13.0) 5.8 84.1 2.2 3.2 Total Revenues $ 1,618.9 $ 1,145.7 $ 2,796.2 $ 2,241.8 $ 2,749.1 $ 1,266.1 $ 1,738.5 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $112 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $952 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $69 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. Year Ended December 31, 2019 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 571.5 $ — $ 1,266.9 $ 730.0 $ 1,502.0 $ 650.2 $ 638.6 Commercial Revenues 411.5 — 559.9 494.2 738.5 388.5 485.4 Industrial Revenues 129.4 — 592.2 550.7 299.9 303.5 338.7 Other Retail Revenues 29.9 — 75.2 7.3 13.1 81.6 9.0 Total Retail Revenues 1,142.3 — 2,494.2 1,782.2 2,553.5 1,423.8 1,471.7 Wholesale Revenues: Generation Revenues (a) — — 251.5 402.4 — 39.5 194.7 Transmission Revenues (b) 379.2 1,025.5 103.6 25.1 56.0 27.5 106.7 Total Wholesale Revenues 379.2 1,025.5 355.1 427.5 56.0 67.0 301.4 Other Revenues from Contracts with Customers (c) 30.1 16.6 61.8 98.4 139.3 22.0 26.1 Total Revenues from Contracts with Customers 1,551.6 1,042.1 2,911.1 2,308.1 2,748.8 1,512.8 1,799.2 Other Revenues: Alternative Revenues (d) 0.6 (20.7) 13.6 (1.4) 31.7 (31.0) (48.3) Other Revenues (d) 157.1 — — — 17.1 — — Total Other Revenues 157.7 (20.7) 13.6 (1.4) 48.8 (31.0) (48.3) Total Revenues $ 1,709.3 $ 1,021.4 $ 2,924.7 $ 2,306.7 $ 2,797.6 $ 1,481.8 $ 1,750.9 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $129 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $782 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $73 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues.
Fixed Performance Obligations	Company 2022 2023-2024 2025-2026 After 2026 Total (in millions) AEP $ 1,231.9 $ 160.8 $ 157.9 $ 97.0 $ 1,647.6 AEP Texas 531.0 — — — 531.0 AEPTCo 1,510.3 — — — 1,510.3 APCo 201.5 32.2 23.2 11.6 268.5 I&M 37.7 8.8 8.8 4.5 59.8 OPCo 78.3 — — — 78.3 PSO 13.1 — — — 13.1 SWEPCo 43.0 — — — 43.0
Affiliated Accounts Receivable Contracts with Customers	Years Ended December 31, Company 2021 2020 (in millions) AEP Texas $ 0.4 $ 0.2 AEPTCo 95.5 81.0 APCo 117.8 52.7 I&M 61.2 34.8 OPCo 51.7 45.9 PSO 18.8 7.8 SWEPCo 24.7 11.2

Goodwill (Tables)

Goodwill (Tables)	12 Months Ended
Goodwill (Tables)	Dec. 31, 2021
Changes in Carrying Amount of Goodwill	Corporate and Other Generation AEP Consolidated (in millions) Balance as of December 31, 2019 $ 37.1 $ 15.4 $ 52.5 Impairment Losses — — — Balance as of December 31, 2020 37.1 15.4 52.5 Impairment Losses — — — Balance as of December 31, 2021 $ 37.1 $ 15.4 $ 52.5

Organization and Summary of S_4

Organization and Summary of Significant Accounting Policies (Details) - USD ($) $ / shares in Units, $ in Millions		12 Months Ended
		Dec. 31, 2021		Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Materials and Supplies		$ 681.3		$ 680.6
Supplementary Information
Depreciation and Amortization of Property, Plant and Equipment		2,717.1		2,487.5	$ 2,203.7
Amortization of Certain Securitized Assets		64.2		171.3	280.7
Amortization of Regulatory Assets and Liabilities		44.4		24	30.1
Total Depreciation and Amortization		2,825.7		2,682.8	2,514.5
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents at Beginning of Period		392.7
Restricted Cash		48		45.6
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents		451.4		438.3	432.6	$ 444.1
Amounts Attributable to AEP Common Shareholders
Net Income (Loss) Attributable to Noncontrolling Interests		0		(3.4)	(1.3)
Net Income (Loss)		$ 2,488.1		$ 2,200.1	$ 1,921.1
Weighted Average Number of Basic AEP Common Shares Outstanding		500,522,177		495,718,223	493,694,345
Earnings Per Share, Basic		$ 4.97		$ 4.44	$ 3.89
Weighted Average Dilutive Effect of:
Weighted Average Number of Diluted AEP Common Shares Outstanding		501,784,032		497,226,867	495,306,238
Earnings Per Share, Diluted		$ 4.96		$ 4.42	$ 3.88
Revenues
TOTAL REVENUES		$ 16,792		$ 14,918.5	$ 15,561.4
Expenses
Depreciation and Amortization		2,825.7		2,682.8	2,514.5
TOTAL EXPENSES		13,380.7		11,930.8	12,969.1
OPERATING INCOME (LOSS)		3,411.3		2,987.7	2,592.3
Other Income (Expense)
Allowance for Equity Funds Used During Construction		139.7		148.1	168.4
Interest Expense		(1,199.1)		(1,165.7)	(1,072.5)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)		2,511.9		2,146.1	1,834.8
Income Tax Expense (Benefit)		115.5		40.5	(12.9)
Net Income (Loss)		2,488.1		2,196.7	1,919.8
Accounts Receivable:
Customers		720.9		613.6
Total Accounts Receivable		1,941.6		1,842.7
Accrued Tax Benefits		121.5		185.3
TOTAL CURRENT ASSETS		7,809.2		4,351.5
Property, Plant and Equipment
Transmission		29,911.1		27,886.7
Other Property, Plant and Equipment		5,682.9		5,294.6
Construction Work in Progress		3,684.3		4,025.7
Total Property, Plant and Equipment		86,806.4		84,313
Accumulated Depreciation and Amortization		20,805.1		20,411.4
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		66,001.3	[1]	63,901.6
Other Noncurrent Assets
TOTAL OTHER NONCURRENT ASSETS		13,858.2		12,504.1
TOTAL ASSETS		87,668.7	[2]	80,757.2	75,892.3
Current Liabilities
Accounts Payable		2,054.6		1,709.7
Accrued Taxes		1,586.4		1,476.4
TOTAL CURRENT LIABILITIES		12,426.7		9,926.7
Liabilities, Noncurrent
Deferred Income Taxes		8,202.5		8,240.9
Regulatory Liabilities and Deferred Investment Tax Credits		8,686.3	[3]	8,378.7
TOTAL NONCURRENT LIABILITIES		52,518.5		50,010.8
TOTAL LIABILITIES		64,945.2		59,937.5
Equity [Abstract]
Retained Earnings		11,667.1		10,687.8
TOTAL LIABILITIES AND EQUITY		87,668.7		80,757.2
Operating Activites
Net Income (Loss)		2,488.1		2,196.7	1,919.8
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization		2,825.7		2,682.8	2,514.5
Deferred Income Taxes		107.6		196.1	(17.8)
Allowance for Equity Funds Used During Construction		(139.7)		(148.1)	(168.4)
Amortization of Deferred Property Taxes		(68)		(43.3)	(73.8)
Change in Other Noncurrent Assets		(132.7)		(142.5)	(112.8)
Increase (Decrease) in Other Noncurrent Liabilities		206.4		(54.5)	(116.1)
Accounts Receivable, Net		(119.7)		(129.3)	247.8
Accounts Payable		200.6		(35.3)	5.8
Accrued Taxes, Net		218.7		20.1	138.9
Net Cash Flows from Operating Activities		3,839.9		3,832.9	4,270.1
Investing Activities
Net Cash Flows Used for Investing Activities		(6,433.9)		(6,233.9)	(7,144.5)
Net Cash Provided by (Used in) Financing Activities
Net Cash Flows from Financing Activities		2,607.1		2,406.7	2,862.9
Cash and Cash Equivalents at Beginning of Period		392.7
Cash and Cash Equivalents at End of Period		403.4		392.7
Cash Paid (Received) for:
Cash Paid for Interest, Net of Capitalized Amounts		1,137.2		1,029.1	1,022.5
Income Taxes		13.2		(49.1)	6.1
Noncash Investing and Financing Activities:
Noncash Acquisition Under Finance Leases		287.6		44.2	87.5
Construction in Progress Expenditures Incurred but Not yet Paid		1,180.4		975.4	1,341.1
Construction Expenditures Included in Current Liabilities as of December 31,		1,180.4		975.4	1,341.1
Construction Expenditures Included in Noncurrent Liabilities as of December 31,		0		5.5	0
Acquisition of Nuclear Fuel Included in Current Liabilities as of December 31,		0		33.4	0.1
Expected Reimbursement For Spent Nuclear Fuel Dry Cask Storage		1.7		2.6	0.3
Forward Equity Purchase Contracts Included in Current and Noncurrent Liabilities as of December 31,		47.8		(86.2)	(7.6)
Organization and Summary of Significant Accounting Policies (Textuals)
Issuance of Long-term Debt		6,486.3		5,626.1	4,536.6
Repayments of Long-term Debt		2,989.3		1,339.8	1,220.8
Equity Method Investment		1,447.5		1,406.3	1,356.6
Income (Loss) from Equity Method Investment		$ 91.7		$ 91.1	$ 72.1
Antidilutive Shares Outstanding		0		128,000	0
Net Income (Loss)		$ 2,488.1		$ 2,196.7	$ 1,919.8
Retained Earnings		11,667.1		10,687.8
2020 Equity Units [Member]
Noncash Investing and Financing Activities:
Forward Equity Purchase Contracts Included in Current and Noncurrent Liabilities as of December 31,		0		110.6
2019 Equity Units [Member]
Noncash Investing and Financing Activities:
Forward Equity Purchase Contracts Included in Current and Noncurrent Liabilities as of December 31,					47.3
Cedar Creek Project
Noncash Investing and Financing Activities:
Noncash Contribution of Assets to Cedar Creek Project		(9.3)		0	0
Sempra Renewable LLC and Santa Rita
Noncash Investing and Financing Activities:
Liabilities Assumed with Sempra Renewable LLC and Santa Rita East Acquisition		0		0	32.4
Retained Earnings [Member]
Amounts Attributable to AEP Common Shareholders
Net Income (Loss)		2,488.1		2,200.1	1,921.1
Noncash Investing and Financing Activities:
Forward Equity Purchase Contracts Included in Current and Noncurrent Liabilities as of December 31,		$ (1.1)
Berkshire Hathaway [Member]
Organization and Summary of Significant Accounting Policies (Textuals)
Equity Method Investment, Ownership Percentage		50.00%
AEP Transmission Holdco [Member]
Organization and Summary of Significant Accounting Policies (Textuals)
Equity Method Investment, Ownership Percentage		50.00%
Pension Plans [Member] \| Equity [Member]
Target Asset Allocations
Target Asset Allocation		25.00%
Pension Plans [Member] \| Fixed Income [Member]
Target Asset Allocations
Target Asset Allocation		59.00%
Pension Plans [Member] \| Other Investments [Member]
Target Asset Allocations
Target Asset Allocation		15.00%
Pension Plans [Member] \| Cash and Cash Equivalents [Member]
Target Asset Allocations
Target Asset Allocation		1.00%
Other Postretirement Benefit Plans [Member] \| Equity [Member]
Target Asset Allocations
Target Asset Allocation		59.00%
Other Postretirement Benefit Plans [Member] \| Fixed Income [Member]
Target Asset Allocations
Target Asset Allocation		40.00%
Other Postretirement Benefit Plans [Member] \| Cash and Cash Equivalents [Member]
Target Asset Allocations
Target Asset Allocation		1.00%
Pension and Other Postretirement Benefit Plans [Member]
Supplementary Information
Securities Loaned		$ 137		177
AEP Texas Inc. [Member]
Materials and Supplies		73.9		70
Supplementary Information
Depreciation and Amortization of Property, Plant and Equipment		327.2		364.2	365.9
Amortization of Certain Securitized Assets		64.2		171.3	258.7
Amortization of Regulatory Assets and Liabilities		(4.4)		(5.7)	(2.3)
Total Depreciation and Amortization		387		529.8	622.3
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents at Beginning of Period		0.1
Restricted Cash		30.4		28.7
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents		30.5		28.8	157.8	159.8
Revenues
TOTAL REVENUES		1,593.8		1,618.9	1,709.3
Expenses
Depreciation and Amortization		387		529.8	622.3
TOTAL EXPENSES		1,117.8		1,249.3	1,477.3
OPERATING INCOME (LOSS)		476		369.6	232
Other Income (Expense)
Allowance for Equity Funds Used During Construction		21.5		19.4	15.2
Interest Expense		(176.5)		(171.8)	(137.2)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)		332.9		229.8	124.7
Income Tax Expense (Benefit)		43.1		(11.2)	(53.6)
Net Income (Loss)		289.8		241	178.3
Accounts Receivable:
Customers		123.4		112.8
Total Accounts Receivable		205.2		183.6
Accrued Tax Benefits		24.8		16.8
TOTAL CURRENT ASSETS		347.2		310.9
Property, Plant and Equipment
Transmission		5,849.9		5,279.6
Other Property, Plant and Equipment		961.1		868.4
Construction Work in Progress		551.3		614.1
Total Property, Plant and Equipment		12,279.5		11,342.9
Accumulated Depreciation and Amortization		1,644.1		1,529.3
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		10,635.4		9,813.6
Other Noncurrent Assets
TOTAL OTHER NONCURRENT ASSETS		854.1		905.7
TOTAL ASSETS		11,836.7		11,030.2
Current Liabilities
Accounts Payable		306.3		231.7
Affiliated Companies		32.5		44
Accrued Taxes		93.3		78.3
TOTAL CURRENT LIABILITIES		1,311.7		676.8
Liabilities, Noncurrent
Deferred Income Taxes		1,088.9		1,016.7
Regulatory Liabilities and Deferred Investment Tax Credits		1,242		1,270.8
TOTAL NONCURRENT LIABILITIES		6,930.8		7,147.4
TOTAL LIABILITIES		8,242.5		7,824.2
Equity [Abstract]
Retained Earnings		2,046.8		1,757
TOTAL LIABILITIES AND EQUITY		11,836.7		11,030.2
Operating Activites
Net Income (Loss)		289.8		241	178.3
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization		387		529.8	622.3
Deferred Income Taxes		43		(15.2)	(23.5)
Allowance for Equity Funds Used During Construction		(21.5)		(19.4)	(15.2)
Change in Other Noncurrent Assets		(78.2)		(74)	9.3
Increase (Decrease) in Other Noncurrent Liabilities		26.4		(24.7)	11.3
Accounts Receivable, Net		(21.6)		9.8	3.5
Accounts Payable		8.9		30.2	7.5
Accrued Taxes, Net		7		42.7	(11.8)
Net Cash Flows from Operating Activities		596.6		614.2	823.4
Investing Activities
Net Cash Flows Used for Investing Activities		(1,000.8)		(1,065.4)	(1,472.2)
Net Cash Provided by (Used in) Financing Activities
Net Cash Flows from Financing Activities		405.9		322.2	646.8
Cash and Cash Equivalents at Beginning of Period		0.1
Cash and Cash Equivalents at End of Period		0.1		0.1
Cash Paid (Received) for:
Cash Paid for Interest, Net of Capitalized Amounts		168.9		153.2	148.6
Income Taxes		5.7		(42.9)	(11)
Noncash Investing and Financing Activities:
Construction in Progress Expenditures Incurred but Not yet Paid		230		177.8	225.5
Construction Expenditures Included in Current Liabilities as of December 31,		230		177.8	225.5
Organization and Summary of Significant Accounting Policies (Textuals)
Issuance of Long-term Debt		444.2		652.7	1,070.4
Repayments of Long-term Debt		88.7		392.1	401.8
Net Income (Loss)		289.8		241	178.3
Retained Earnings		2,046.8		1,757
AEP Texas Inc. [Member] \| Retained Earnings [Member]
Other Income (Expense)
Net Income (Loss)		289.8		241	178.3
Operating Activites
Net Income (Loss)		289.8		241	178.3
Organization and Summary of Significant Accounting Policies (Textuals)
Net Income (Loss)		$ 289.8		241	178.3
AEP Texas Inc. [Member] \| Pension Plans [Member] \| Equity [Member]
Target Asset Allocations
Target Asset Allocation		25.00%
AEP Texas Inc. [Member] \| Pension Plans [Member] \| Fixed Income [Member]
Target Asset Allocations
Target Asset Allocation		59.00%
AEP Texas Inc. [Member] \| Pension Plans [Member] \| Other Investments [Member]
Target Asset Allocations
Target Asset Allocation		15.00%
AEP Texas Inc. [Member] \| Pension Plans [Member] \| Cash and Cash Equivalents [Member]
Target Asset Allocations
Target Asset Allocation		1.00%
AEP Texas Inc. [Member] \| Other Postretirement Benefit Plans [Member] \| Equity [Member]
Target Asset Allocations
Target Asset Allocation		59.00%
AEP Texas Inc. [Member] \| Other Postretirement Benefit Plans [Member] \| Fixed Income [Member]
Target Asset Allocations
Target Asset Allocation		40.00%
AEP Texas Inc. [Member] \| Other Postretirement Benefit Plans [Member] \| Cash and Cash Equivalents [Member]
Target Asset Allocations
Target Asset Allocation		1.00%
AEP Texas Inc. [Member] \| Pension and Other Postretirement Benefit Plans [Member]
Supplementary Information
Securities Loaned		$ 137		177
AEP Transmission Co [Member]
Materials and Supplies		9.3		8.5
Supplementary Information
Depreciation and Amortization of Property, Plant and Equipment		297.3		249	176
Amortization of Certain Securitized Assets		0		0	0
Amortization of Regulatory Assets and Liabilities		0		0	0
Total Depreciation and Amortization		297.3		249	176
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents at Beginning of Period		0		0	0
Revenues
TOTAL REVENUES		1,469.3		1,145.7	1,021.4
Expenses
Depreciation and Amortization		297.3		249	176
TOTAL EXPENSES		660		564.2	454.2
OPERATING INCOME (LOSS)		809.3		581.5	567.2
Other Income (Expense)
Allowance for Equity Funds Used During Construction		67.2		74	84.3
Interest Expense		(141.2)		(127.8)	(97.4)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)		735.8		530.1	557.1
Income Tax Expense (Benefit)		144.1		106.7	117.4
Net Income (Loss)		591.7		423.4	439.7
Accounts Receivable:
Customers		22.5		22.9
Total Accounts Receivable		118.6		104.1
Accrued Tax Benefits		5.6		9.9
TOTAL CURRENT ASSETS		331.3		235.8
Property, Plant and Equipment
Transmission		10,886.3		9,593.5
Other Property, Plant and Equipment		427.4		329.5
Construction Work in Progress		1,394.8		1,422.6
Total Property, Plant and Equipment		12,708.5		11,345.6
Accumulated Depreciation and Amortization		772.8		572.8
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		11,935.7	[1]	10,772.8
Other Noncurrent Assets
Deferred Property Taxes		245.7		220.1
TOTAL OTHER NONCURRENT ASSETS		257.4		237.4
TOTAL ASSETS		12,524.4	[4]	11,246	9,890.8
Current Liabilities
Accounts Payable		460.1		380.4
Affiliated Companies		69.9		97.3
Accrued Taxes		479		418.1
TOTAL CURRENT LIABILITIES		1,296.9		1,137.5
Liabilities, Noncurrent
Deferred Income Taxes		962.9		906.9
Regulatory Liabilities and Deferred Investment Tax Credits		644.1	[5]	581.8
TOTAL NONCURRENT LIABILITIES		5,851.4		5,395.6
TOTAL LIABILITIES		7,148.3		6,533.1
Equity [Abstract]
Retained Earnings		2,426.5		1,947.3
TOTAL MEMBER'S EQUITY		5,376.1		4,712.9	4,009.5	3,569.8
TOTAL LIABILITIES AND EQUITY		12,524.4		11,246
Operating Activites
Net Income (Loss)		591.7		423.4	439.7
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization		297.3		249	176
Deferred Income Taxes		68.5		81.6	91.3
Allowance for Equity Funds Used During Construction		(67.2)		(74)	(84.3)
Amortization of Deferred Property Taxes		(25.6)		(26.6)	(35.6)
Change in Other Noncurrent Assets		7.5		(8.2)	9.6
Increase (Decrease) in Other Noncurrent Liabilities		3.7		8.3	(8.1)
Accounts Receivable, Net		(16)		(19)	(5.4)
Accounts Payable		(2.2)		77.8	37.6
Accrued Taxes, Net		67.2		62.7	90.8
Net Cash Flows from Operating Activities		925.7		771.2	708.6
Investing Activities
Net Cash Flows Used for Investing Activities		(1,359)		(1,640.4)	(1,403.2)
Net Cash Provided by (Used in) Financing Activities
Net Cash Flows from Financing Activities		433.3		869.2	694.6
Net Increase (Decrease) in Cash and Cash Equivalents		0		0	0
Cash and Cash Equivalents at Beginning of Period		0		0	0
Cash and Cash Equivalents at End of Period		0		0	0
Cash Paid (Received) for:
Cash Paid for Interest, Net of Capitalized Amounts		132.9		119.7	90.6
Income Taxes		65.7		22.9	1.5
Noncash Investing and Financing Activities:
Construction in Progress Expenditures Incurred but Not yet Paid		358.7		311.9	472.7
Construction Expenditures Included in Current Liabilities as of December 31,		358.7		311.9	472.7
Organization and Summary of Significant Accounting Policies (Textuals)
Issuance of Long-term Debt		443.7		519.5	688
Repayments of Long-term Debt		50		0	85
Net Income (Loss)		591.7		423.4	439.7
Retained Earnings		2,426.5		1,947.3
AEP Transmission Co [Member] \| Retained Earnings [Member]
Other Income (Expense)
Net Income (Loss)		591.7		423.4	439.7
Equity [Abstract]
TOTAL MEMBER'S EQUITY		2,426.5		1,947.3	1,528.9	1,089.2
Operating Activites
Net Income (Loss)		591.7		423.4	439.7
Organization and Summary of Significant Accounting Policies (Textuals)
Net Income (Loss)		591.7		423.4	439.7
Appalachian Power Co [Member]
Materials and Supplies		109.8		99.6
Supplementary Information
Depreciation and Amortization of Property, Plant and Equipment		547		507.8	466.5
Amortization of Certain Securitized Assets		0		0	0
Amortization of Regulatory Assets and Liabilities		(0.8)		(0.3)	0.3
Total Depreciation and Amortization		546.2		507.5	466.8
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents at Beginning of Period		5.8
Restricted Cash		17.6		16.9
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents		20.1		22.7	26.8	29.8
Revenues
TOTAL REVENUES		3,105.2		2,796.2	2,924.7
Expenses
Depreciation and Amortization		546.2		507.5	466.8
TOTAL EXPENSES		2,555.8		2,239.6	2,527.4
OPERATING INCOME (LOSS)		549.4		556.6	397.3
Other Income (Expense)
Allowance for Equity Funds Used During Construction		15.6		14.6	16.6
Interest Expense		(214)		(217.6)	(205)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)		371		374	228.3
Income Tax Expense (Benefit)		22.1		4.3	(78)
Net Income (Loss)		348.9		369.7	306.3
Accounts Receivable:
Customers		158.5		142.8
Total Accounts Receivable		341		284.4
TOTAL CURRENT ASSETS		925.3		674.1
Property, Plant and Equipment
Transmission		4,322.4		3,900.5
Other Property, Plant and Equipment		696.6		627.2
Construction Work in Progress		469.9		484.6
Total Property, Plant and Equipment		16,856.1		16,110.3
Accumulated Depreciation and Amortization		5,051.8		4,716.2
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		11,804.3		11,394.1
Other Noncurrent Assets
TOTAL OTHER NONCURRENT ASSETS		1,359.3		1,247
TOTAL ASSETS		14,088.9		13,315.2
Current Liabilities
Accounts Payable		262.2		212
Affiliated Companies		118.6		97.1
Accrued Taxes		119.7		109.9
TOTAL CURRENT LIABILITIES		1,415.9		1,217.7
Liabilities, Noncurrent
Deferred Income Taxes		1,804.7		1,749.9
Regulatory Liabilities and Deferred Investment Tax Credits		1,238.8		1,224.7
TOTAL NONCURRENT LIABILITIES		8,025.1		7,753.2
TOTAL LIABILITIES		9,441		8,970.9
Equity [Abstract]
Retained Earnings		2,534.4		2,248
TOTAL LIABILITIES AND EQUITY		14,088.9		13,315.2
Operating Activites
Net Income (Loss)		348.9		369.7	306.3
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization		546.2		507.5	466.8
Deferred Income Taxes		15		(26.2)	(126.2)
Allowance for Equity Funds Used During Construction		(15.6)		(14.6)	(16.6)
Change in Other Noncurrent Assets		(68.8)		(40.4)	(38.2)
Increase (Decrease) in Other Noncurrent Liabilities		35.6		11.2	(40.3)
Accounts Receivable, Net		(53.3)		(30.2)	35.7
Accounts Payable		36.8		(48.1)	37.7
Accrued Taxes, Net		(16.2)		31.3	(10.2)
Net Cash Flows from Operating Activities		611.7		712	661.4
Investing Activities
Net Cash Flows Used for Investing Activities		(826.5)		(757.9)	(837.4)
Net Cash Provided by (Used in) Financing Activities
Net Cash Flows from Financing Activities		212.2		41.8	173
Cash and Cash Equivalents at Beginning of Period		5.8
Cash and Cash Equivalents at End of Period		2.5		5.8
Cash Paid (Received) for:
Cash Paid for Interest, Net of Capitalized Amounts		207.5		207.1	190.7
Income Taxes		32.8		0	63
Noncash Investing and Financing Activities:
Construction in Progress Expenditures Incurred but Not yet Paid		139.1		105.6	149.7
Construction Expenditures Included in Current Liabilities as of December 31,		139.1		105.6	149.7
Organization and Summary of Significant Accounting Policies (Textuals)
Issuance of Long-term Debt		494		606.9	478.2
Repayments of Long-term Debt		393		140.3	180.5
Net Income (Loss)		348.9		369.7	306.3
Retained Earnings		2,534.4		2,248
Appalachian Power Co [Member] \| Retained Earnings [Member]
Other Income (Expense)
Net Income (Loss)		348.9		369.7	306.3
Operating Activites
Net Income (Loss)		348.9		369.7	306.3
Organization and Summary of Significant Accounting Policies (Textuals)
Net Income (Loss)		$ 348.9		369.7	306.3
Appalachian Power Co [Member] \| Pension Plans [Member] \| Equity [Member]
Target Asset Allocations
Target Asset Allocation		25.00%
Appalachian Power Co [Member] \| Pension Plans [Member] \| Fixed Income [Member]
Target Asset Allocations
Target Asset Allocation		59.00%
Appalachian Power Co [Member] \| Pension Plans [Member] \| Other Investments [Member]
Target Asset Allocations
Target Asset Allocation		15.00%
Appalachian Power Co [Member] \| Pension Plans [Member] \| Cash and Cash Equivalents [Member]
Target Asset Allocations
Target Asset Allocation		1.00%
Appalachian Power Co [Member] \| Other Postretirement Benefit Plans [Member] \| Equity [Member]
Target Asset Allocations
Target Asset Allocation		59.00%
Appalachian Power Co [Member] \| Other Postretirement Benefit Plans [Member] \| Fixed Income [Member]
Target Asset Allocations
Target Asset Allocation		40.00%
Appalachian Power Co [Member] \| Other Postretirement Benefit Plans [Member] \| Cash and Cash Equivalents [Member]
Target Asset Allocations
Target Asset Allocation		1.00%
Appalachian Power Co [Member] \| Pension and Other Postretirement Benefit Plans [Member]
Supplementary Information
Securities Loaned		$ 137		177
Indiana Michigan Power Co [Member]
Materials and Supplies		175.2		175.8
Supplementary Information
Depreciation and Amortization of Property, Plant and Equipment		424.9		393.3	330.6
Amortization of Certain Securitized Assets		0		0	0
Amortization of Regulatory Assets and Liabilities		21.1		18.3	20
Total Depreciation and Amortization		446		411.6	350.6
Ohio Valley Electric Corporation - Barging and Other Transportation Services (43.47% Owned)		54		60.8	63.4
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents at Beginning of Period		3.3		2	2.4
Revenues
TOTAL REVENUES		2,326.7		2,241.8	2,306.7
Expenses
Depreciation and Amortization		446		411.6	350.6
TOTAL EXPENSES		1,968.8		1,878.9	1,965.9
OPERATING INCOME (LOSS)		357.9		362.9	340.8
Other Income (Expense)
Allowance for Equity Funds Used During Construction		12.8		11.5	19.4
Interest Expense		(116.8)		(112.3)	(117.9)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)		269.2		277.3	258.8
Income Tax Expense (Benefit)		(10.6)		(7.5)	(10.6)
Net Income (Loss)		279.8		284.8	269.4
Accounts Receivable:
Customers		40.6		44
Total Accounts Receivable		121.2		97
Accrued Tax Benefits		12.7		10.3
TOTAL CURRENT ASSETS		439.4		418.8
Property, Plant and Equipment
Transmission		1,783.1		1,696.4
Other Property, Plant and Equipment		792.9		686.7
Construction Work in Progress		302.8		362.4
Total Property, Plant and Equipment		11,210.7		10,604.8
Accumulated Depreciation and Amortization		3,899.8		3,552.5
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		7,310.9		7,052.3
Other Noncurrent Assets
TOTAL OTHER NONCURRENT ASSETS		4,657.9		4,167.2
TOTAL ASSETS		12,408.2		11,638.3
Current Liabilities
Accounts Payable		174.4		153.2
Affiliated Companies		94.9		80.5
Accrued Taxes		106.5		102.5
TOTAL CURRENT LIABILITIES		894		1,104.5
Liabilities, Noncurrent
Deferred Income Taxes		1,100.2		1,064.4
Regulatory Liabilities and Deferred Investment Tax Credits		2,447.9		2,041.9
TOTAL NONCURRENT LIABILITIES		8,729.5		7,784.6
TOTAL LIABILITIES		9,623.5		8,889.1
Equity [Abstract]
Retained Earnings		1,748.5		1,718.7
TOTAL LIABILITIES AND EQUITY		12,408.2		11,638.3
Operating Activites
Net Income (Loss)		279.8		284.8	269.4
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization		446		411.6	350.6
Deferred Income Taxes		(38)		(16.2)	(52.7)
Allowance for Equity Funds Used During Construction		(12.8)		(11.5)	(19.4)
Change in Other Noncurrent Assets		(54.1)		6.1	8.3
Increase (Decrease) in Other Noncurrent Liabilities		7.5		45	33.7
Accounts Receivable, Net		(22.3)		14.5	35.4
Accounts Payable		42.3		(10.8)	3.6
Accrued Taxes, Net		1.6		(20.2)	48.3
Net Cash Flows from Operating Activities		733.7		776.3	685.2
Investing Activities
Net Cash Flows Used for Investing Activities		(633.1)		(648.9)	(720.1)
Net Cash Provided by (Used in) Financing Activities
Net Cash Flows from Financing Activities		(102.6)		(126.1)	34.5
Net Increase (Decrease) in Cash and Cash Equivalents		(2)		1.3	(0.4)
Cash and Cash Equivalents at Beginning of Period		3.3		2	2.4
Cash and Cash Equivalents at End of Period		1.3		3.3	2
Cash Paid (Received) for:
Cash Paid for Interest, Net of Capitalized Amounts		110.9		107.6	111.9
Income Taxes		29.3		42.1	3.4
Noncash Investing and Financing Activities:
Construction in Progress Expenditures Incurred but Not yet Paid		87.8		62.8	86
Construction Expenditures Included in Current Liabilities as of December 31,		87.8		62.8	86
Acquisition of Nuclear Fuel Included in Current Liabilities as of December 31,		0		33.4	0.1
Expected Reimbursement For Spent Nuclear Fuel Dry Cask Storage		1.7		2.6	0.3
Organization and Summary of Significant Accounting Policies (Textuals)
Issuance of Long-term Debt		546.7		69.5	123.3
Repayments of Long-term Debt		383.5		93.2	117.1
Net Income (Loss)		279.8		284.8	269.4
Retained Earnings		1,748.5		1,718.7
Indiana Michigan Power Co [Member] \| Retained Earnings [Member]
Other Income (Expense)
Net Income (Loss)		279.8		284.8	269.4
Operating Activites
Net Income (Loss)		279.8		284.8	269.4
Organization and Summary of Significant Accounting Policies (Textuals)
Net Income (Loss)		$ 279.8		284.8	269.4
Indiana Michigan Power Co [Member] \| Pension Plans [Member] \| Equity [Member]
Target Asset Allocations
Target Asset Allocation		25.00%
Indiana Michigan Power Co [Member] \| Pension Plans [Member] \| Fixed Income [Member]
Target Asset Allocations
Target Asset Allocation		59.00%
Indiana Michigan Power Co [Member] \| Pension Plans [Member] \| Other Investments [Member]
Target Asset Allocations
Target Asset Allocation		15.00%
Indiana Michigan Power Co [Member] \| Pension Plans [Member] \| Cash and Cash Equivalents [Member]
Target Asset Allocations
Target Asset Allocation		1.00%
Indiana Michigan Power Co [Member] \| Other Postretirement Benefit Plans [Member] \| Equity [Member]
Target Asset Allocations
Target Asset Allocation		59.00%
Indiana Michigan Power Co [Member] \| Other Postretirement Benefit Plans [Member] \| Fixed Income [Member]
Target Asset Allocations
Target Asset Allocation		40.00%
Indiana Michigan Power Co [Member] \| Other Postretirement Benefit Plans [Member] \| Cash and Cash Equivalents [Member]
Target Asset Allocations
Target Asset Allocation		1.00%
Indiana Michigan Power Co [Member] \| Pension and Other Postretirement Benefit Plans [Member]
Supplementary Information
Securities Loaned		$ 137		177
Ohio Power Co [Member]
Materials and Supplies		74.1		66.9
Supplementary Information
Depreciation and Amortization of Property, Plant and Equipment		301.1		275	229.4
Amortization of Certain Securitized Assets		0		0	22
Amortization of Regulatory Assets and Liabilities		2.2		1.6	(10.5)
Total Depreciation and Amortization		303.3		276.6	240.9
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents at Beginning of Period		7.4
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents		3		7.4	3.7	$ 32.5
Revenues
TOTAL REVENUES		2,899.1		2,749.1	2,797.6
Expenses
Depreciation and Amortization		303.3		276.6	240.9
TOTAL EXPENSES		2,513.9		2,345.4	2,396.4
OPERATING INCOME (LOSS)		385.2		403.7	401.2
Other Income (Expense)
Allowance for Equity Funds Used During Construction		10.8		12.5	18.2
Interest Expense		(124.4)		(117.2)	(106.2)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)		288		316.6	332
Income Tax Expense (Benefit)		34.4		45.2	34.9
Net Income (Loss)		253.6		271.4	297.1
Accounts Receivable:
Customers		71.6		50
Total Accounts Receivable		150		133.2
TOTAL CURRENT ASSETS		327.5		256.3
Property, Plant and Equipment
Transmission		2,992.8		2,831.9
Other Property, Plant and Equipment		992.9		899.6
Construction Work in Progress		365		362.3
Total Property, Plant and Equipment		10,421.3		9,802.1
Accumulated Depreciation and Amortization		2,458.3		2,350
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		7,963		7,452.1
Other Noncurrent Assets
TOTAL OTHER NONCURRENT ASSETS		975.3		1,002
TOTAL ASSETS		9,265.8		8,710.4
Current Liabilities
Accounts Payable		213.5		181
Affiliated Companies		125.4		118.4
Accrued Taxes		702.4		631
TOTAL CURRENT LIABILITIES		1,245.7		1,906.2
Liabilities, Noncurrent
Deferred Income Taxes		1,000.9		955.1
Regulatory Liabilities and Deferred Investment Tax Credits		1,020.9		1,005.2
TOTAL NONCURRENT LIABILITIES		5,173.8		4,111.5
TOTAL LIABILITIES		6,419.5		6,017.7
Equity [Abstract]
Retained Earnings		1,686.3		1,532.7
TOTAL LIABILITIES AND EQUITY		9,265.8		8,710.4
Operating Activites
Net Income (Loss)		253.6		271.4	297.1
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization		303.3		276.6	240.9
Deferred Income Taxes		30.7		77.2	43.8
Allowance for Equity Funds Used During Construction		(10.8)		(12.5)	(18.2)
Amortization of Deferred Property Taxes		(35.3)		(16.6)	(33.7)
Change in Other Noncurrent Assets		(40.7)		(49.4)	(35.3)
Increase (Decrease) in Other Noncurrent Liabilities		6.9		(66.4)	(93.2)
Accounts Receivable, Net		(11.8)		4.2	75
Accounts Payable		19.1		10.3	0.4
Accrued Taxes, Net		78.2		43.3	38.7
Net Cash Flows from Operating Activities		575.6		410.9	421.2
Investing Activities
Net Cash Flows Used for Investing Activities		(753.3)		(791)	(744.1)
Net Cash Provided by (Used in) Financing Activities
Net Cash Flows from Financing Activities		173.3		383.8	294.1
Cash and Cash Equivalents at Beginning of Period		7.4
Cash and Cash Equivalents at End of Period		3		7.4
Cash Paid (Received) for:
Cash Paid for Interest, Net of Capitalized Amounts		119.5		111.2	100.6
Income Taxes		(7.9)		(26.9)	7.3
Noncash Investing and Financing Activities:
Construction in Progress Expenditures Incurred but Not yet Paid		97.1		76.7	125.9
Construction Expenditures Included in Current Liabilities as of December 31,		97.1		76.7	125.9
Organization and Summary of Significant Accounting Policies (Textuals)
Issuance of Long-term Debt		1,037.1		347	444.3
Repayments of Long-term Debt		500.1		0.1	80.3
Net Income (Loss)		253.6		271.4	297.1
Retained Earnings		1,686.3		1,532.7
Ohio Power Co [Member] \| Retained Earnings [Member]
Other Income (Expense)
Net Income (Loss)		253.6		271.4	297.1
Operating Activites
Net Income (Loss)		253.6		271.4	297.1
Organization and Summary of Significant Accounting Policies (Textuals)
Net Income (Loss)		$ 253.6		271.4	297.1
Ohio Power Co [Member] \| Pension Plans [Member] \| Equity [Member]
Target Asset Allocations
Target Asset Allocation		25.00%
Ohio Power Co [Member] \| Pension Plans [Member] \| Fixed Income [Member]
Target Asset Allocations
Target Asset Allocation		59.00%
Ohio Power Co [Member] \| Pension Plans [Member] \| Other Investments [Member]
Target Asset Allocations
Target Asset Allocation		15.00%
Ohio Power Co [Member] \| Pension Plans [Member] \| Cash and Cash Equivalents [Member]
Target Asset Allocations
Target Asset Allocation		1.00%
Ohio Power Co [Member] \| Other Postretirement Benefit Plans [Member] \| Equity [Member]
Target Asset Allocations
Target Asset Allocation		59.00%
Ohio Power Co [Member] \| Other Postretirement Benefit Plans [Member] \| Fixed Income [Member]
Target Asset Allocations
Target Asset Allocation		40.00%
Ohio Power Co [Member] \| Other Postretirement Benefit Plans [Member] \| Cash and Cash Equivalents [Member]
Target Asset Allocations
Target Asset Allocation		1.00%
Ohio Power Co [Member] \| Pension and Other Postretirement Benefit Plans [Member]
Supplementary Information
Securities Loaned		$ 137		177
Public Service Co Of Oklahoma [Member]
Materials and Supplies		56.2		54
Supplementary Information
Depreciation and Amortization of Property, Plant and Equipment		185.9		171.9	162.5
Amortization of Certain Securitized Assets		0		0	0
Amortization of Regulatory Assets and Liabilities		10.7		1.6	7
Total Depreciation and Amortization		196.6		173.5	169.5
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents at Beginning of Period		2.6		1.5	2
Revenues
TOTAL REVENUES		1,474.4		1,266.1	1,481.8
Expenses
Depreciation and Amortization		196.6		173.5	169.5
TOTAL EXPENSES		1,281.5		1,090.2	1,282.5
OPERATING INCOME (LOSS)		192.9		175.9	199.3
Other Income (Expense)
Allowance for Equity Funds Used During Construction		2.4		4	2.7
Interest Expense		(62.9)		(60.3)	(66.5)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)		145.2		128.2	145.1
Income Tax Expense (Benefit)		4.1		5.2	7.5
Net Income (Loss)		141.1		123	137.6
Accounts Receivable:
Customers		41.5		30.8
Total Accounts Receivable		77.1		48.4
Accrued Tax Benefits		17.6		10.9
TOTAL CURRENT ASSETS		386.8		181.3
Property, Plant and Equipment
Transmission		1,107.7		1,069.9
Other Property, Plant and Equipment		437		393.3
Construction Work in Progress		156		128.7
Total Property, Plant and Equipment		6,508		5,925.6
Accumulated Depreciation and Amortization		1,705.2		1,605.6
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		4,802.8		4,320
Other Noncurrent Assets
TOTAL OTHER NONCURRENT ASSETS		1,209.4		489.4
TOTAL ASSETS		6,399		4,990.7
Current Liabilities
Accounts Payable		157.4		107
Affiliated Companies		51		43.4
Accrued Taxes		27		26.8
TOTAL CURRENT LIABILITIES		562.7		478.6
Liabilities, Noncurrent
Deferred Income Taxes		782.3		688.5
Regulatory Liabilities and Deferred Investment Tax Credits		835.3		802.2
TOTAL NONCURRENT LIABILITIES		3,544.7		2,966.5
TOTAL LIABILITIES		4,107.4		3,445.1
Equity [Abstract]
Retained Earnings		1,095.4		974.3
TOTAL LIABILITIES AND EQUITY		6,399		4,990.7
Operating Activites
Net Income (Loss)		141.1		123	137.6
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization		196.6		173.5	169.5
Deferred Income Taxes		113.9		17	(18.2)
Allowance for Equity Funds Used During Construction		(2.4)		(4)	(2.7)
Change in Other Noncurrent Assets		(18.3)		(17.9)	5.7
Increase (Decrease) in Other Noncurrent Liabilities		4.4		1.6	(7.3)
Accounts Receivable, Net		(28.7)		1.4	15.4
Accounts Payable		34.2		(29.5)	7
Accrued Taxes, Net		(6.5)		3.6	3.9
Net Cash Flows from Operating Activities		(433.3)		157	350.3
Investing Activities
Net Cash Flows Used for Investing Activities		(626.7)		(295.1)	(328.1)
Net Cash Provided by (Used in) Financing Activities
Net Cash Flows from Financing Activities		1,058.7		139.2	(22.7)
Net Increase (Decrease) in Cash and Cash Equivalents		(1.3)		1.1	(0.5)
Cash and Cash Equivalents at Beginning of Period		2.6		1.5	2
Cash and Cash Equivalents at End of Period		1.3		2.6	1.5
Cash Paid (Received) for:
Cash Paid for Interest, Net of Capitalized Amounts		57		59.1	61.1
Income Taxes		(102.9)		(11.8)	22.4
Noncash Investing and Financing Activities:
Construction in Progress Expenditures Incurred but Not yet Paid		56.8		35.5	46
Construction Expenditures Included in Current Liabilities as of December 31,		56.8		35.5	46
Organization and Summary of Significant Accounting Policies (Textuals)
Issuance of Long-term Debt		1,290		0	349.5
Repayments of Long-term Debt		750.5		13.2	250.5
Net Income (Loss)		141.1		123	137.6
Retained Earnings		1,095.4		974.3
Public Service Co Of Oklahoma [Member] \| Retained Earnings [Member]
Other Income (Expense)
Net Income (Loss)		141.1		123	137.6
Operating Activites
Net Income (Loss)		141.1		123	137.6
Organization and Summary of Significant Accounting Policies (Textuals)
Net Income (Loss)		$ 141.1		123	137.6
Public Service Co Of Oklahoma [Member] \| Pension Plans [Member] \| Equity [Member]
Target Asset Allocations
Target Asset Allocation		25.00%
Public Service Co Of Oklahoma [Member] \| Pension Plans [Member] \| Fixed Income [Member]
Target Asset Allocations
Target Asset Allocation		59.00%
Public Service Co Of Oklahoma [Member] \| Pension Plans [Member] \| Other Investments [Member]
Target Asset Allocations
Target Asset Allocation		15.00%
Public Service Co Of Oklahoma [Member] \| Pension Plans [Member] \| Cash and Cash Equivalents [Member]
Target Asset Allocations
Target Asset Allocation		1.00%
Public Service Co Of Oklahoma [Member] \| Other Postretirement Benefit Plans [Member] \| Equity [Member]
Target Asset Allocations
Target Asset Allocation		59.00%
Public Service Co Of Oklahoma [Member] \| Other Postretirement Benefit Plans [Member] \| Fixed Income [Member]
Target Asset Allocations
Target Asset Allocation		40.00%
Public Service Co Of Oklahoma [Member] \| Other Postretirement Benefit Plans [Member] \| Cash and Cash Equivalents [Member]
Target Asset Allocations
Target Asset Allocation		1.00%
Public Service Co Of Oklahoma [Member] \| Pension and Other Postretirement Benefit Plans [Member]
Supplementary Information
Securities Loaned		$ 137		177
Southwestern Electric Power Co [Member]
Materials and Supplies		81.9		95.8
Supplementary Information
Depreciation and Amortization of Property, Plant and Equipment		292.9		271.2	247.9
Amortization of Certain Securitized Assets		0		0	0
Amortization of Regulatory Assets and Liabilities		2.1		1.5	1.2
Total Depreciation and Amortization		295		272.7	249.1
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents at Beginning of Period		13.2		1.6	24.5
Amounts Attributable to AEP Common Shareholders
Net Income (Loss) Attributable to Noncontrolling Interests		3.1		2.9	3.6
Net Income (Loss)		239		180.8	158.6
Revenues
TOTAL REVENUES		2,131.8		1,738.5	1,750.9
Expenses
Depreciation and Amortization		295		272.7	249.1
TOTAL EXPENSES		1,792.3		1,448	1,495.2
OPERATING INCOME (LOSS)		339.5		290.5	255.7
Other Income (Expense)
Allowance for Equity Funds Used During Construction		7		7.7	6.8
Interest Expense		(125.9)		(118.5)	(119.1)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)		238.1		190.2	154.5
Income Tax Expense (Benefit)		(0.6)		9.4	(4.7)
Net Income (Loss)		242.1		183.7	162.2
Accounts Receivable:
Customers		35.8		27.1
Total Accounts Receivable		86.4		64.9
Accrued Tax Benefits		17.8		29.9
TOTAL CURRENT ASSETS		668.5		428
Property, Plant and Equipment
Transmission		2,316.9		2,165.7
Other Property, Plant and Equipment		764		788.8
Construction Work in Progress		240.7		228.3
Total Property, Plant and Equipment		10,570.4		10,246.7
Accumulated Depreciation and Amortization		3,170.3		3,158.5
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		7,400.1		7,088.2
Other Noncurrent Assets
TOTAL OTHER NONCURRENT ASSETS		1,257.1		637.9
TOTAL ASSETS		9,325.7		8,154.1
Current Liabilities
Accounts Payable		163.6		135.9
Affiliated Companies		61.4		43
Accrued Taxes		44.3		41
TOTAL CURRENT LIABILITIES		538.7		763.6
Liabilities, Noncurrent
Deferred Income Taxes		1,087.6		1,017.6
Regulatory Liabilities and Deferred Investment Tax Credits		806.9		863.4
TOTAL NONCURRENT LIABILITIES		5,637.2		4,762.8
TOTAL LIABILITIES		6,175.9		5,526.4
Equity [Abstract]
Retained Earnings		2,050.9		1,811.9
TOTAL LIABILITIES AND EQUITY		9,325.7		8,154.1
Operating Activites
Net Income (Loss)		242.1		183.7	162.2
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization		295		272.7	249.1
Deferred Income Taxes		16.6		32.4	(11)
Allowance for Equity Funds Used During Construction		(7)		(7.7)	(6.8)
Change in Other Noncurrent Assets		41.9		16.1	2.7
Increase (Decrease) in Other Noncurrent Liabilities		(1.1)		25.2	2.7
Accounts Receivable, Net		(21.5)		7.3	0
Accounts Payable		22		11.1	(28.4)
Accrued Taxes, Net		15.4		(23.1)	(3.2)
Net Cash Flows from Operating Activities		96.8		356.3	339.8
Investing Activities
Net Cash Flows Used for Investing Activities		(920.7)		(392.6)	(330.2)
Net Cash Provided by (Used in) Financing Activities
Net Cash Flows from Financing Activities		861.9		47.9	(32.5)
Net Increase (Decrease) in Cash and Cash Equivalents		38		11.6	(22.9)
Cash and Cash Equivalents at Beginning of Period		13.2		1.6	24.5
Cash and Cash Equivalents at End of Period		51.2		13.2	1.6
Cash Paid (Received) for:
Cash Paid for Interest, Net of Capitalized Amounts		116.5		110.7	111.1
Income Taxes		(28.8)		4.3	8.6
Noncash Investing and Financing Activities:
Construction in Progress Expenditures Incurred but Not yet Paid		69		46	69.1
Construction Expenditures Included in Current Liabilities as of December 31,		69		46	69.1
Organization and Summary of Significant Accounting Policies (Textuals)
Issuance of Long-term Debt		1,137.6		0	0
Repayments of Long-term Debt		381.2		21.2	59.7
Income (Loss) from Equity Method Investment		3.4		2.9	3
Net Income (Loss)		242.1		183.7	162.2
Retained Earnings		2,050.9		1,811.9
Southwestern Electric Power Co [Member] \| Retained Earnings [Member]
Amounts Attributable to AEP Common Shareholders
Net Income (Loss)		$ 239		180.8	$ 158.6
Southwestern Electric Power Co [Member] \| Pension Plans [Member] \| Equity [Member]
Target Asset Allocations
Target Asset Allocation		25.00%
Southwestern Electric Power Co [Member] \| Pension Plans [Member] \| Fixed Income [Member]
Target Asset Allocations
Target Asset Allocation		59.00%
Southwestern Electric Power Co [Member] \| Pension Plans [Member] \| Other Investments [Member]
Target Asset Allocations
Target Asset Allocation		15.00%
Southwestern Electric Power Co [Member] \| Pension Plans [Member] \| Cash and Cash Equivalents [Member]
Target Asset Allocations
Target Asset Allocation		1.00%
Southwestern Electric Power Co [Member] \| Other Postretirement Benefit Plans [Member] \| Equity [Member]
Target Asset Allocations
Target Asset Allocation		59.00%
Southwestern Electric Power Co [Member] \| Other Postretirement Benefit Plans [Member] \| Fixed Income [Member]
Target Asset Allocations
Target Asset Allocation		40.00%
Southwestern Electric Power Co [Member] \| Other Postretirement Benefit Plans [Member] \| Cash and Cash Equivalents [Member]
Target Asset Allocations
Target Asset Allocation		1.00%
Southwestern Electric Power Co [Member] \| Pension and Other Postretirement Benefit Plans [Member]
Supplementary Information
Securities Loaned		$ 137		$ 177
Restricted Stock Units and Performance Share Units [Member]
Weighted Average Dilutive Effect of:
Weighted Average Dilutive Effect of Shares		1,300,000		1,500,000	1,600,000
Dilutive Securities, Effect on Basic Earnings Per Share		$ (0.01)		$ (0.02)	$ (0.01)
Revenues [Member] \| AEP Texas Inc. [Member] \| Credit Concentration Risk
Risks and Uncertainties
Percentage of Significant Customers Concentration Risk	[6]	43.00%		46.00%	48.00%
Revenues [Member] \| AEP Transmission Co [Member] \| Credit Concentration Risk
Risks and Uncertainties
Percentage of Significant Customers Concentration Risk		79.00%		78.00%	79.00%
Revenues [Member] \| Appalachian Power Co [Member] \| Credit Concentration Risk
Risks and Uncertainties
Percentage of Significant Customers Concentration Risk		10.00%		10.00%	10.00%
Revenues [Member] \| Indiana Michigan Power Co [Member] \| Credit Concentration Risk
Risks and Uncertainties
Percentage of Significant Customers Concentration Risk		10.00%		10.00%	10.00%
Revenues [Member] \| Ohio Power Co [Member] \| Credit Concentration Risk
Risks and Uncertainties
Percentage of Significant Customers Concentration Risk		10.00%		10.00%	10.00%
Revenues [Member] \| Public Service Co Of Oklahoma [Member] \| Credit Concentration Risk
Risks and Uncertainties
Percentage of Significant Customers Concentration Risk		10.00%		10.00%	10.00%
Revenues [Member] \| Southwestern Electric Power Co [Member] \| Credit Concentration Risk
Risks and Uncertainties
Percentage of Significant Customers Concentration Risk		10.00%		10.00%	10.00%
Accounts Receivable [Member] \| AEP Texas Inc. [Member] \| Credit Concentration Risk
Risks and Uncertainties
Percentage of Significant Customers Concentration Risk	[6]	41.00%		40.00%	43.00%
Accounts Receivable [Member] \| AEP Transmission Co [Member] \| Credit Concentration Risk
Risks and Uncertainties
Percentage of Significant Customers Concentration Risk		81.00%		78.00%	78.00%
Noncontrolling Interest [Member] \| Dry Lake Solar Project [Member]
Noncash Investing and Financing Activities:
Noncash Contribution of Assets by Noncontrolling Interest		$ 35.3		$ 0	$ 0
Noncontrolling Interest [Member] \| Sempra Renewables LLC and Santa Rita East Acquisition [Member]
Noncash Investing and Financing Activities:
Noncash Contribution of Assets by Noncontrolling Interest		0		0	$ 253.4
Sabine Mining Co [Member] \| Southwestern Electric Power Co [Member]
Materials and Supplies		12		23.3
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents at Beginning of Period		10.1
Property, Plant and Equipment
Other Property, Plant and Equipment		219.9		223.7
Accumulated Depreciation and Amortization		168.1		126.5
Net Cash Provided by (Used in) Financing Activities
Cash and Cash Equivalents at Beginning of Period		10.1
Cash and Cash Equivalents at End of Period		$ 49.9		$ 10.1

[1]	Amount excludes $2.3 billion and $165 million for AEP and AEPTCo, respectively, of Property, Plant and Equipment - Net classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[2]	Amount includes Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[3]	2021 amounts exclude $148 million of regulatory liabilities classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[4]	Amount includes Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[5]	2021 amounts exclude $8 million of regulatory liabilities classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[6]	In January 2021, NRG Energy, parent company of Reliant Energy, completed a deal to purchase Direct Energy from Centrica.

Comprehensive Income (Details)

Comprehensive Income (Details) - USD ($) $ in Millions		12 Months Ended
Comprehensive Income (Details) - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		$ (85.1)	$ (147.7)	$ (120.4)
Change in Fair Value Recognized in AOCI		536.8	(66.4)	(69.7)
Commodity
Generation and Marketing Revenues		16,792	14,918.5	15,561.4
Interest Rate
Interest Expense		1,199.1	1,165.7	1,072.5
Pension and OPEB
Reclassifications from AOCI, before Income Tax (Expense) Benefit		(337.9)	163.2	53.7
Income Tax (Expense) Benefit		115.5	40.5	(12.9)
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit		(266.9)	129	42.4
Net Current Period Other Comprehensive Income (Loss)		269.9	62.6	(27.3)
Ending Balance in AOCI		184.8	(85.1)	(147.7)
Pension and OPEB [Member] \| Amortization of Deferred Costs [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		123.7	130.7	136.3
Change in Fair Value Recognized in AOCI		0	0	0
Pension and OPEB
Reclassifications from AOCI, before Income Tax (Expense) Benefit		(10.3)	(8.9)	(7.1)
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit		(8.1)	(7)	(5.6)
Net Current Period Other Comprehensive Income (Loss)		(8.1)	(7)	(5.6)
Ending Balance in AOCI		115.6	123.7	130.7
Pension and OPEB [Member] \| Changes in Funded Status [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(100.7)	(163.4)	(221.1)
Change in Fair Value Recognized in AOCI		27.5	62.7	57.7
Pension and OPEB
Reclassifications from AOCI, before Income Tax (Expense) Benefit		0	0	0
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit		0	0	0
Net Current Period Other Comprehensive Income (Loss)		27.5	62.7	57.7
Ending Balance in AOCI		(73.2)	(100.7)	(163.4)
Accumulated Other Comprehensive Income [Member]
Pension and OPEB
Net Current Period Other Comprehensive Income (Loss)		269.9	62.6	(27.3)
Commodity [Member] \| Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(60.6)	(103.5)	(23)
Change in Fair Value Recognized in AOCI		488.2	(89.2)	(127.2)
Pension and OPEB
Reclassifications from AOCI, before Income Tax (Expense) Benefit		(334.1)	167.2	59.3
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit		(263.9)	132.1	46.7
Net Current Period Other Comprehensive Income (Loss)		224.3	42.9	(80.5)
Ending Balance in AOCI		163.7	(60.6)	(103.5)
Interest Rate [Member] \| Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(47.5)	(11.5)	(12.6)
Change in Fair Value Recognized in AOCI	[1]	21.1	(39.9)	(0.2)
Pension and OPEB
Reclassifications from AOCI, before Income Tax (Expense) Benefit		6.5	4.9	1.5
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit		5.1	3.9	1.3
Net Current Period Other Comprehensive Income (Loss)		26.2	(36)	1.1
Ending Balance in AOCI		(21.3)	(47.5)	(11.5)
Generation and Marketing Revenues [Member]
Commodity
Generation and Marketing Revenues		2,108.3	1,621	1,721.8
Apple Blossom and Black Oak [Member] \| Interest Rate [Member] \| Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Change in Fair Value Recognized in AOCI		(7)	6	4
AEP Texas Inc. [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(8.9)	(12.8)	(15.1)
Change in Fair Value Recognized in AOCI		1.3	2.7	1.1
Commodity
Generation and Marketing Revenues		1,587.7	1,528	1,551.6
Interest Rate
Interest Expense		176.5	171.8	137.2
Pension and OPEB
Reclassifications from AOCI, before Income Tax (Expense) Benefit		1.4	1.5	1.5
Income Tax (Expense) Benefit		43.1	(11.2)	(53.6)
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit		1.1	1.2	1.2
Net Current Period Other Comprehensive Income (Loss)		2.4	3.9	2.3
Ending Balance in AOCI		(6.5)	(8.9)	(12.8)
AEP Texas Inc. [Member] \| Pension and OPEB [Member] \| Amortization of Deferred Costs [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		5.1	4.9	4.7
Change in Fair Value Recognized in AOCI		0	0	0
Pension and OPEB
Reclassifications from AOCI, before Income Tax (Expense) Benefit		0.2	0.2	0.2
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit		0.2	0.2	0.2
Net Current Period Other Comprehensive Income (Loss)		0.2	0.2	0.2
Ending Balance in AOCI		5.3	5.1	4.9
AEP Texas Inc. [Member] \| Pension and OPEB [Member] \| Changes in Funded Status [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(11.7)	(14.3)	(15.4)
Change in Fair Value Recognized in AOCI		1.2	2.6	1.1
Pension and OPEB
Reclassifications from AOCI, before Income Tax (Expense) Benefit		0	0	0
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit		0	0	0
Net Current Period Other Comprehensive Income (Loss)		1.2	2.6	1.1
Ending Balance in AOCI		(10.5)	(11.7)	(14.3)
AEP Texas Inc. [Member] \| Accumulated Other Comprehensive Income [Member]
Pension and OPEB
Net Current Period Other Comprehensive Income (Loss)		2.4	3.9	2.3
AEP Texas Inc. [Member] \| Interest Rate [Member] \| Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(2.3)	(3.4)	(4.4)
Change in Fair Value Recognized in AOCI		0.1	0.1	0
Pension and OPEB
Reclassifications from AOCI, before Income Tax (Expense) Benefit		1.2	1.3	1.3
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit		0.9	1	1
Net Current Period Other Comprehensive Income (Loss)		1	1.1	1
Ending Balance in AOCI		(1.3)	(2.3)	(3.4)
Appalachian Power Co [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		7.2	5	(5)
Change in Fair Value Recognized in AOCI		22.3	7	13.4
Commodity
Generation and Marketing Revenues		3,092.9	2,809.2	2,911.1
Interest Rate
Interest Expense		214	217.6	205
Pension and OPEB
Reclassifications from AOCI, before Income Tax (Expense) Benefit		(6.4)	(6.1)	(4.3)
Income Tax (Expense) Benefit		22.1	4.3	(78)
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit		(5.1)	(4.8)	(3.4)
Net Current Period Other Comprehensive Income (Loss)		17.2	2.2	10
Ending Balance in AOCI		24.4	7.2	5
Appalachian Power Co [Member] \| Pension and OPEB [Member] \| Amortization of Deferred Costs [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		5.4	9.2	11.7
Change in Fair Value Recognized in AOCI		0	0	0
Pension and OPEB
Reclassifications from AOCI, before Income Tax (Expense) Benefit		(5.3)	(4.8)	(3.2)
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit		(4.2)	(3.8)	(2.5)
Net Current Period Other Comprehensive Income (Loss)		(4.2)	(3.8)	(2.5)
Ending Balance in AOCI		1.2	5.4	9.2
Appalachian Power Co [Member] \| Pension and OPEB [Member] \| Changes in Funded Status [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		2.6	(5.1)	(18.5)
Change in Fair Value Recognized in AOCI		13.1	7.7	13.4
Pension and OPEB
Reclassifications from AOCI, before Income Tax (Expense) Benefit		0	0	0
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit		0	0	0
Net Current Period Other Comprehensive Income (Loss)		13.1	7.7	13.4
Ending Balance in AOCI		15.7	2.6	(5.1)
Appalachian Power Co [Member] \| Accumulated Other Comprehensive Income [Member]
Pension and OPEB
Net Current Period Other Comprehensive Income (Loss)		17.2	2.2	10
Appalachian Power Co [Member] \| Interest Rate [Member] \| Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(0.8)	0.9	1.8
Change in Fair Value Recognized in AOCI		9.2	(0.7)	0
Pension and OPEB
Reclassifications from AOCI, before Income Tax (Expense) Benefit		(1.1)	(1.3)	(1.1)
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit		(0.9)	(1)	(0.9)
Net Current Period Other Comprehensive Income (Loss)		8.3	(1.7)	(0.9)
Ending Balance in AOCI		7.5	(0.8)	0.9
Appalachian Power Co [Member] \| Purchased Electricity for Resale [Member]
Commodity
Purchased Electricity for Resale		539.6	360.3	391
Indiana Michigan Power Co [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(7)	(11.6)	(13.8)
Change in Fair Value Recognized in AOCI		4.2	3.1	0.8
Commodity
Generation and Marketing Revenues		2,330.7	2,236	2,308.1
Interest Rate
Interest Expense		116.8	112.3	117.9
Pension and OPEB
Reclassifications from AOCI, before Income Tax (Expense) Benefit		1.9	1.9	1.8
Income Tax (Expense) Benefit		(10.6)	(7.5)	(10.6)
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit		1.5	1.5	1.4
Net Current Period Other Comprehensive Income (Loss)		5.7	4.6	2.2
Ending Balance in AOCI		(1.3)	(7)	(11.6)
Indiana Michigan Power Co [Member] \| Pension and OPEB [Member] \| Amortization of Deferred Costs [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		4.8	4.9	5.1
Change in Fair Value Recognized in AOCI		0	0	0
Pension and OPEB
Reclassifications from AOCI, before Income Tax (Expense) Benefit		(0.1)	(0.1)	(0.2)
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit		(0.1)	(0.1)	(0.2)
Net Current Period Other Comprehensive Income (Loss)		(0.1)	(0.1)	(0.2)
Ending Balance in AOCI		4.7	4.8	4.9
Indiana Michigan Power Co [Member] \| Pension and OPEB [Member] \| Changes in Funded Status [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(3.5)	(6.6)	(7.4)
Change in Fair Value Recognized in AOCI		4.2	3.1	0.8
Pension and OPEB
Reclassifications from AOCI, before Income Tax (Expense) Benefit		0	0	0
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit		0	0	0
Net Current Period Other Comprehensive Income (Loss)		4.2	3.1	0.8
Ending Balance in AOCI		0.7	(3.5)	(6.6)
Indiana Michigan Power Co [Member] \| Accumulated Other Comprehensive Income [Member]
Pension and OPEB
Net Current Period Other Comprehensive Income (Loss)		5.7	4.6	2.2
Indiana Michigan Power Co [Member] \| Interest Rate [Member] \| Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(8.3)	(9.9)	(11.5)
Change in Fair Value Recognized in AOCI		0	0	0
Pension and OPEB
Reclassifications from AOCI, before Income Tax (Expense) Benefit		2	2	2
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit		1.6	1.6	1.6
Net Current Period Other Comprehensive Income (Loss)		1.6	1.6	1.6
Ending Balance in AOCI		(6.7)	(8.3)	(9.9)
Indiana Michigan Power Co [Member] \| Purchased Electricity for Resale [Member]
Commodity
Purchased Electricity for Resale		176.8	182.2	232.3
Ohio Power Co [Member]
Commodity
Generation and Marketing Revenues		2,837.5	2,665	2,748.8
Interest Rate
Interest Expense		124.4	117.2	106.2
Pension and OPEB
Income Tax (Expense) Benefit		34.4	45.2	34.9
Net Current Period Other Comprehensive Income (Loss)				(1)
Ohio Power Co [Member] \| Accumulated Other Comprehensive Income [Member]
Pension and OPEB
Net Current Period Other Comprehensive Income (Loss)				(1)
Ohio Power Co [Member] \| Interest Rate [Member] \| Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		0	0	1
Change in Fair Value Recognized in AOCI		0	0	0
Pension and OPEB
Reclassifications from AOCI, before Income Tax (Expense) Benefit		0	0	(1.3)
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit		0	0	(1)
Net Current Period Other Comprehensive Income (Loss)		0	0	(1)
Ending Balance in AOCI		0	0	0
Ohio Power Co [Member] \| Purchased Electricity for Resale [Member]
Commodity
Purchased Electricity for Resale		678	549.2	607.3
Public Service Co Of Oklahoma [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		0.1
Commodity
Generation and Marketing Revenues		1,474.3	1,263.9	1,512.8
Interest Rate
Interest Expense		62.9	60.3	66.5
Pension and OPEB
Income Tax (Expense) Benefit		4.1	5.2	7.5
Net Current Period Other Comprehensive Income (Loss)		(0.1)	(1)	(1)
Ending Balance in AOCI		0	0.1
Public Service Co Of Oklahoma [Member] \| Accumulated Other Comprehensive Income [Member]
Pension and OPEB
Net Current Period Other Comprehensive Income (Loss)		(0.1)	(1)	(1)
Public Service Co Of Oklahoma [Member] \| Interest Rate [Member] \| Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		0.1	1.1	2.1
Change in Fair Value Recognized in AOCI		0	0	0
Pension and OPEB
Reclassifications from AOCI, before Income Tax (Expense) Benefit		(0.1)	(1.3)	(1.3)
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit		(0.1)	(1)	(1)
Net Current Period Other Comprehensive Income (Loss)		(0.1)	(1)	(1)
Ending Balance in AOCI		0	0.1	1.1
Southwestern Electric Power Co [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		1.9	(1.3)	(5.4)
Change in Fair Value Recognized in AOCI		4.9	3.2	3.7
Commodity
Generation and Marketing Revenues		2,126	1,735.3	1,799.2
Interest Rate
Interest Expense		125.9	118.5	119.1
Pension and OPEB
Reclassifications from AOCI, before Income Tax (Expense) Benefit		(0.1)	0	0.5
Income Tax (Expense) Benefit		(0.6)	9.4	(4.7)
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit		(0.1)	0	0.4
Net Current Period Other Comprehensive Income (Loss)		4.8	3.2	4.1
Ending Balance in AOCI		6.7	1.9	(1.3)
Southwestern Electric Power Co [Member] \| Pension and OPEB [Member] \| Amortization of Deferred Costs [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(2.8)	(1.3)	(0.2)
Change in Fair Value Recognized in AOCI		0	0	0
Pension and OPEB
Reclassifications from AOCI, before Income Tax (Expense) Benefit		(2)	(1.9)	(1.4)
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit		(1.6)	(1.5)	(1.1)
Net Current Period Other Comprehensive Income (Loss)		(1.6)	(1.5)	(1.1)
Ending Balance in AOCI		(4.4)	(2.8)	(1.3)
Southwestern Electric Power Co [Member] \| Pension and OPEB [Member] \| Changes in Funded Status [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		5	1.8	(1.9)
Change in Fair Value Recognized in AOCI		4.9	3.2	3.7
Pension and OPEB
Reclassifications from AOCI, before Income Tax (Expense) Benefit		0	0	0
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit		0	0	0
Net Current Period Other Comprehensive Income (Loss)		4.9	3.2	3.7
Ending Balance in AOCI		9.9	5	1.8
Southwestern Electric Power Co [Member] \| Accumulated Other Comprehensive Income [Member]
Pension and OPEB
Net Current Period Other Comprehensive Income (Loss)		4.8	3.2	4.1
Southwestern Electric Power Co [Member] \| Interest Rate [Member] \| Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(0.3)	(1.8)	(3.3)
Change in Fair Value Recognized in AOCI		0	0	0
Pension and OPEB
Reclassifications from AOCI, before Income Tax (Expense) Benefit		1.9	1.9	1.9
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit		1.5	1.5	1.5
Net Current Period Other Comprehensive Income (Loss)		1.5	1.5	1.5
Ending Balance in AOCI		1.2	(0.3)	(1.8)
Reclassifications from Accumulated Other Comprehensive Income [Member]
Interest Rate
Interest Expense	[2]	6.5	4.9	1.5
Pension and OPEB
Amortization of Prior Service Cost (Credit)		(19.4)	(19.2)	(19.2)
Amortization of Actuarial (Gains) Losses		9.1	10.3	12.1
Income Tax (Expense) Benefit		(71)	34.2	11.3
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Pension and OPEB [Member] \| Amortization of Deferred Costs [Member]
Interest Rate
Interest Expense	[2]	0	0	0
Pension and OPEB
Amortization of Prior Service Cost (Credit)		(19.4)	(19.2)	(19.2)
Amortization of Actuarial (Gains) Losses		9.1	10.3	12.1
Income Tax (Expense) Benefit		(2.2)	(1.9)	(1.5)
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Pension and OPEB [Member] \| Changes in Funded Status [Member]
Interest Rate
Interest Expense	[2]	0	0	0
Pension and OPEB
Amortization of Prior Service Cost (Credit)		0	0	0
Amortization of Actuarial (Gains) Losses		0	0	0
Income Tax (Expense) Benefit		0	0	0
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Commodity [Member] \| Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Interest Rate
Interest Expense	[2]	0	0	0
Pension and OPEB
Amortization of Prior Service Cost (Credit)		0	0	0
Amortization of Actuarial (Gains) Losses		0	0	0
Income Tax (Expense) Benefit		(70.2)	35.1	12.6
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Interest Rate [Member] \| Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Interest Rate
Interest Expense	[2]	6.5	4.9	1.5
Pension and OPEB
Amortization of Prior Service Cost (Credit)		0	0	0
Amortization of Actuarial (Gains) Losses		0	0	0
Income Tax (Expense) Benefit		1.4	1	0.2
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Generation and Marketing Revenues [Member]
Commodity
Generation and Marketing Revenues	[2]	0.7	(0.4)	(0.2)
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Generation and Marketing Revenues [Member] \| Pension and OPEB [Member] \| Amortization of Deferred Costs [Member]
Commodity
Generation and Marketing Revenues	[2]	0	0	0
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Generation and Marketing Revenues [Member] \| Pension and OPEB [Member] \| Changes in Funded Status [Member]
Commodity
Generation and Marketing Revenues	[2]	0	0	0
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Generation and Marketing Revenues [Member] \| Commodity [Member] \| Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Commodity
Generation and Marketing Revenues	[2]	0.7	(0.4)	(0.2)
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Generation and Marketing Revenues [Member] \| Interest Rate [Member] \| Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Commodity
Generation and Marketing Revenues	[2]	0	0	0
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Purchased Electricity for Resale [Member]
Commodity
Purchased Electricity for Resale	[2]	(334.8)	167.6	59.5
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Purchased Electricity for Resale [Member] \| Pension and OPEB [Member] \| Amortization of Deferred Costs [Member]
Commodity
Purchased Electricity for Resale	[2]	0	0	0
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Purchased Electricity for Resale [Member] \| Pension and OPEB [Member] \| Changes in Funded Status [Member]
Commodity
Purchased Electricity for Resale	[2]	0	0	0
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Purchased Electricity for Resale [Member] \| Commodity [Member] \| Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Commodity
Purchased Electricity for Resale	[2]	(334.8)	167.6	59.5
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Purchased Electricity for Resale [Member] \| Interest Rate [Member] \| Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Commodity
Purchased Electricity for Resale	[2]	0	0	0
Reclassifications from Accumulated Other Comprehensive Income [Member] \| AEP Texas Inc. [Member]
Interest Rate
Interest Expense	[2]	1.2	1.3	1.3
Pension and OPEB
Amortization of Prior Service Cost (Credit)		(0.1)	(0.1)	(0.1)
Amortization of Actuarial (Gains) Losses		0.3	0.3	0.3
Income Tax (Expense) Benefit		0.3	0.3	0.3
Reclassifications from Accumulated Other Comprehensive Income [Member] \| AEP Texas Inc. [Member] \| Pension and OPEB [Member] \| Amortization of Deferred Costs [Member]
Interest Rate
Interest Expense	[2]	0	0	0
Pension and OPEB
Amortization of Prior Service Cost (Credit)		(0.1)	(0.1)	(0.1)
Amortization of Actuarial (Gains) Losses		0.3	0.3	0.3
Income Tax (Expense) Benefit		0	0	0
Reclassifications from Accumulated Other Comprehensive Income [Member] \| AEP Texas Inc. [Member] \| Pension and OPEB [Member] \| Changes in Funded Status [Member]
Interest Rate
Interest Expense	[2]	0	0	0
Pension and OPEB
Amortization of Prior Service Cost (Credit)		0	0	0
Amortization of Actuarial (Gains) Losses		0	0	0
Income Tax (Expense) Benefit		0	0	0
Reclassifications from Accumulated Other Comprehensive Income [Member] \| AEP Texas Inc. [Member] \| Interest Rate [Member] \| Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Interest Rate
Interest Expense	[2]	1.2	1.3	1.3
Pension and OPEB
Amortization of Prior Service Cost (Credit)		0	0	0
Amortization of Actuarial (Gains) Losses		0	0	0
Income Tax (Expense) Benefit		0.3	0.3	0.3
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Appalachian Power Co [Member]
Interest Rate
Interest Expense	[2]	(1.1)	(1.3)	(1.1)
Pension and OPEB
Amortization of Prior Service Cost (Credit)		(5.3)	(5.3)	(5.3)
Amortization of Actuarial (Gains) Losses			0.5	2.1
Income Tax (Expense) Benefit		(1.3)	(1.3)	(0.9)
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Appalachian Power Co [Member] \| Pension and OPEB [Member] \| Amortization of Deferred Costs [Member]
Interest Rate
Interest Expense	[2]	0	0	0
Pension and OPEB
Amortization of Prior Service Cost (Credit)		(5.3)	(5.3)	(5.3)
Amortization of Actuarial (Gains) Losses			0.5	2.1
Income Tax (Expense) Benefit		(1.1)	(1)	(0.7)
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Appalachian Power Co [Member] \| Pension and OPEB [Member] \| Changes in Funded Status [Member]
Interest Rate
Interest Expense	[2]	0	0	0
Pension and OPEB
Amortization of Prior Service Cost (Credit)		0	0	0
Amortization of Actuarial (Gains) Losses			0	0
Income Tax (Expense) Benefit		0	0	0
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Appalachian Power Co [Member] \| Interest Rate [Member] \| Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Interest Rate
Interest Expense	[2]	(1.1)	(1.3)	(1.1)
Pension and OPEB
Amortization of Prior Service Cost (Credit)		0	0	0
Amortization of Actuarial (Gains) Losses			0	0
Income Tax (Expense) Benefit		(0.2)	(0.3)	(0.2)
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Indiana Michigan Power Co [Member]
Interest Rate
Interest Expense	[2]	2	2	2
Pension and OPEB
Amortization of Prior Service Cost (Credit)		(0.8)	(0.8)	(0.8)
Amortization of Actuarial (Gains) Losses		0.7	0.7	0.6
Income Tax (Expense) Benefit		0.4	0.4	0.4
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Indiana Michigan Power Co [Member] \| Pension and OPEB [Member] \| Amortization of Deferred Costs [Member]
Interest Rate
Interest Expense	[2]	0	0	0
Pension and OPEB
Amortization of Prior Service Cost (Credit)		(0.8)	(0.8)	(0.8)
Amortization of Actuarial (Gains) Losses		0.7	0.7	0.6
Income Tax (Expense) Benefit		0	0	0
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Indiana Michigan Power Co [Member] \| Pension and OPEB [Member] \| Changes in Funded Status [Member]
Interest Rate
Interest Expense	[2]	0	0	0
Pension and OPEB
Amortization of Prior Service Cost (Credit)		0	0	0
Amortization of Actuarial (Gains) Losses		0	0	0
Income Tax (Expense) Benefit		0	0	0
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Indiana Michigan Power Co [Member] \| Interest Rate [Member] \| Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Interest Rate
Interest Expense	[2]	2	2	2
Pension and OPEB
Amortization of Prior Service Cost (Credit)		0	0	0
Amortization of Actuarial (Gains) Losses		0	0	0
Income Tax (Expense) Benefit		0.4	0.4	0.4
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Ohio Power Co [Member] \| Interest Rate [Member] \| Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Interest Rate
Interest Expense	[2]	0	0	(1.3)
Pension and OPEB
Income Tax (Expense) Benefit		0	0	(0.3)
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Public Service Co Of Oklahoma [Member] \| Interest Rate [Member] \| Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Interest Rate
Interest Expense	[2]	(0.1)	(1.3)	(1.3)
Pension and OPEB
Income Tax (Expense) Benefit		0	(0.3)	(0.3)
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Southwestern Electric Power Co [Member]
Interest Rate
Interest Expense	[2]	1.9	1.9	1.9
Pension and OPEB
Amortization of Prior Service Cost (Credit)		(2)	(2)	(2)
Amortization of Actuarial (Gains) Losses		0	0.1	0.6
Income Tax (Expense) Benefit		0	0	0.1
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Southwestern Electric Power Co [Member] \| Pension and OPEB [Member] \| Amortization of Deferred Costs [Member]
Interest Rate
Interest Expense	[2]	0	0	0
Pension and OPEB
Amortization of Prior Service Cost (Credit)		(2)	(2)	(2)
Amortization of Actuarial (Gains) Losses		0	0.1	0.6
Income Tax (Expense) Benefit		(0.4)	(0.4)	(0.3)
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Southwestern Electric Power Co [Member] \| Pension and OPEB [Member] \| Changes in Funded Status [Member]
Interest Rate
Interest Expense	[2]	0	0	0
Pension and OPEB
Amortization of Prior Service Cost (Credit)		0	0	0
Amortization of Actuarial (Gains) Losses		0	0	0
Income Tax (Expense) Benefit		0	0	0
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Southwestern Electric Power Co [Member] \| Interest Rate [Member] \| Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Interest Rate
Interest Expense	[2]	1.9	1.9	1.9
Pension and OPEB
Amortization of Prior Service Cost (Credit)		0	0	0
Amortization of Actuarial (Gains) Losses		0	0	0
Income Tax (Expense) Benefit		$ 0.4	$ 0.4	$ 0.4

[1]	The change in fair value includes $(7) million, $6 million and $4 million related to AEP's investment in joint venture wind farms acquired as part of the purchase of Sempra Renewables LLC for the years ended December 31, 2021, 2020 and 2019, respectively. See “Sempra Renewables LLC” section of Note 17 for additional information.
[2]	Amounts reclassified to the referenced line item on the statements of income.

Rate Matters East Companies (De

Rate Matters East Companies (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021		Dec. 31, 2020
Public Utilities, General Disclosures [Line Items]
Total Property, Plant and Equipment, Net	$ 66,001.3	[1]	$ 63,901.6
Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Total Property, Plant and Equipment, Net	11,804.3		11,394.1
Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Total Property, Plant and Equipment, Net	7,310.9		7,052.3
Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Total Property, Plant and Equipment, Net	$ 7,963		$ 7,452.1
Wheeling Power Company \| Mitchell Power Plant
Public Utilities, General Disclosures [Line Items]
Ownership Interest in Mitchell Power Plant	50.00%
Kentucky Power Co [Member] \| Mitchell Power Plant
Public Utilities, General Disclosures [Line Items]
Ownership Interest in Mitchell Power Plant	50.00%
2017-2019 Virginia Triennial Review [Member] \| Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Total Basis Point Band for Authorized Return on Equity	140.00%
Approved Return on Common Equity	9.20%
2020 Ohio Base Rate Case [Member] \| Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Annual Increase	$ 42
Requested Return on Equity	10.15%
Approved Return on Common Equity	9.70%
Approved Annual Revenue Cap for the DIR in 2021	$ 57
Approved Annual Revenue Cap for the DIR in 2022	91
Approved Annual Revenue Cap for the DIR in 2023	116
Approved Annual Revenue Cap for the DIR for the first five months of 2024	51
Approved Annual Revenue Decrease	68
CCR/ELG Filings \| Mitchell Power Plant
Public Utilities, General Disclosures [Line Items]
Estimated CCR/ELG Costs	132
Estimated alternative CCR Investment	25
CCR/ELG Filings \| Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Estimated ELG Costs	197
Net Book Value of Amos and Mountaineer Plants - Virginia	1,500
Estimated ELG Investment	26
CCR/ELG Filings \| Kentucky Power Co [Member] \| Mitchell Power Plant
Public Utilities, General Disclosures [Line Items]
Estimated ELG Investment	3
Property, Plant and Equipment, Net	586
2021 Indiana Base Rate Case \| Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Annual Increase	$ 104
Requested Return on Equity	10.00%
Phased In Annual Increase 2022	$ 73
Phased in Annual Increase 2023	31
Amount of Increase Related to Annual Depreciation Expense	7
Proposed Settlement Annual Rate Increase	$ 61
Proposed Settlement Agreement ROE	9.70%
Approved Annual Increase in 2022	$ 3
Approved Annual Increase in 2023	$ 58
Minimum [Member] \| 2017-2019 Virginia Triennial Review [Member] \| Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Approved Return on Common Equity	8.50%
Maximum [Member] \| 2017-2019 Virginia Triennial Review [Member] \| Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Approved Return on Common Equity	9.90%

[1]	Amount excludes $2.3 billion and $165 million for AEP and AEPTCo, respectively, of Property, Plant and Equipment - Net classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.

Rate Matters West Companies (De

Rate Matters West Companies (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021		Dec. 31, 2020	Dec. 31, 2019
Public Utilities, General Disclosures [Line Items]
Other Asset Impairment Charges	$ 11.6		$ 0	$ 156.4
Total Property, Plant and Equipment, Net	66,001.3	[1]	63,901.6
AEP Share of Independence Energy Connection Capital Costs	81
Noncurrent Regulatory Assets	4,142.3	[2]	3,527
AEP Texas Inc. [Member]
Public Utilities, General Disclosures [Line Items]
Other Asset Impairment Charges	0		0	32.5
Total Property, Plant and Equipment, Net	10,635.4		9,813.6
Noncurrent Regulatory Assets	275.2		266.8
Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Total Property, Plant and Equipment, Net	4,802.8		4,320
Noncurrent Regulatory Assets	1,037.4		375
Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Other Asset Impairment Charges	11.6		0	0
Provision for Refund	(0.4)		(2)	$ (32)
Total Property, Plant and Equipment, Net	7,400.1		7,088.2
Noncurrent Regulatory Assets	1,005.3		$ 403.1
AEP Texas Interim Transmission and Distribution Rates [Member] \| AEP Texas Inc. [Member]
Public Utilities, General Disclosures [Line Items]
AEP Texas Cumulative Revenues Subject to Review	$ 298
ETT Interim Transmission Rates [Member]
Public Utilities, General Disclosures [Line Items]
Parent Ownership Interest In ETT	50.00%
AEP Share Of ETT Cumulative Revenues Subject To Review	$ 1,400
2012 Texas Base Rate Case [Member] \| Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
2013 Reversal Of Previously Recorded Regulatory Disallowances	114
Estimated Reduced Annual Revenues	$ 15
2016 Texas Base Rate Case [Member] \| Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Return on Equity	10.00%
Approved Return on Common Equity	9.60%
Requested Net Increase in Texas Annual Revenues	$ 69
Approved Net Increase in Texas Annual Revenues	50
Approved Additional Vegetation Management Expenses	2
Impairment Charge Total	19
Impairment Charge Welsh Plant, Unit 2	7
Impairment Charge Disallowed Plant Investments	12
Additional Revenues Recognized to be Surcharged to Customers	32
Additional Recognized Expenses Consisting Primarily of Depreciation and Vegetation Management	7
2020 Texas Base Rate Case [Member] \| Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Annual Increase	$ 105
Approved Return on Common Equity	9.25%
Impairment Charge Total	$ 12
Requested Return on Equity	10.35%
Requested Net Annual Increase	$ 90
Amount of Increase Related to Annual Depreciation Expense	10
Amount of Increase Related to Storm Catastrophe Reserve	2
Requested Recovery of Dolet Hills Power Station	45
Revised Requested Annual Increase	100
Revised Requested Net Annual Increase	85
Approved Annual Revenue Increase	39
Amount of Approved Increase Related to Vegetation Management	5
Amount of Approved Increase Related to Storm Catastrophe Reserve	2
Amount of Increase Related to Vegetation Management	5
2020 Louisiana Base Rate Case [Member] \| Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Annual Increase	134
Staff Recommended Annual Rate Increase	$ 6
Requested Return on Equity	10.35%
Amount of Increase Related to Annual Depreciation Expense	$ 32
Revised Requested Annual Increase	$ 114
Staff Recommended Return on Common Equity	9.10%
Requested Annual Increase in Rebuttal	$ 95
2021 Oklahoma Base Rate Case \| Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Requested Annual Increase	$ 172
Approved Return on Common Equity	9.40%
Requested Return on Equity	10.00%
Amount of Increase Related to Annual Depreciation Expense	$ 57
Amount of Increase Related to SPP Expenses	31
Proposed Grid Transformation Plan	100
Revised Requested Annual Increase	128
Proposed Settlement Annual Rate Increase	$ 51
Proposed Settlement Agreement ROE	9.40%
Approved Annual Revenue Increase	$ 51
2021 Oklahoma Base Rate Case \| Oklaunion Power Station Accelerated Depreciation [Member] \| Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Amount of Increase Related to Annual Depreciation Expense	45
2021 Arkansas Rate Case \| Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Annual Increase	85
Staff Recommended Annual Rate Increase	$ 47
Requested Return on Equity	10.35%
Amount of Increase Related to Annual Depreciation Expense	$ 14
Amount of Increase Related to SPP Expenses	$ 6
Staff Recommended Return on Common Equity	9.30%
Requested Annual Increase in Rebuttal	$ 81
Amount of Increase Related to North Central Wind Facilities	$ 41
Staff Recommended Debt Capital Structure	55.50%
Staff Recommended Equity Capital Structure	44.50%
Requested Debt Capital Structure	48.70%
Requested Equity Capital Structure	51.30%
February 2021 Severe Storm Fuel Costs \| Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Interim WACC	0.75%
Approved Carrying Charge	0.75%
February 2021 Severe Storm Fuel Costs \| Public Service Co Of Oklahoma [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Noncurrent Regulatory Assets	$ 679
February 2021 Severe Storm Fuel Costs \| Southwestern Electric Power Co [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Noncurrent Regulatory Assets	$ 430
February 2021 Severe Storm Fuel Costs \| Southwestern Electric Power Co [Member] \| Louisiana Jurisdiction [Member]
Public Utilities, General Disclosures [Line Items]
Interim WACC	3.25%
February 2021 Severe Storm Fuel Costs \| Southwestern Electric Power Co [Member] \| Louisiana Jurisdiction [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Noncurrent Regulatory Assets	$ 148
February 2021 Severe Storm Fuel Costs \| Southwestern Electric Power Co [Member] \| Arkansas
Public Utilities, General Disclosures [Line Items]
Interim WACC	0.30%
Requested Weighted Average Cost of Capital	6.05%
Intervenor Recommended WACC	1.65%
February 2021 Severe Storm Fuel Costs \| Southwestern Electric Power Co [Member] \| Arkansas \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Noncurrent Regulatory Assets	$ 103
February 2021 Severe Storm Fuel Costs \| Southwestern Electric Power Co [Member] \| Texas
Public Utilities, General Disclosures [Line Items]
Requested Weighted Average Cost of Capital	7.18%
February 2021 Severe Storm Fuel Costs \| Southwestern Electric Power Co [Member] \| Texas \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Noncurrent Regulatory Assets	$ 179
2021 Louisiana Storm Cost Filing \| Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Deferred Storm Costs	145
Minimum [Member] \| 2012 Texas Base Rate Case [Member] \| Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Estimated Turk AFUDC Disallowance	80
Estimated Turk AFUDC Refunds	$ 0
Minimum [Member] \| 2020 Louisiana Base Rate Case [Member] \| Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Intervenor Recommended Return on Common Equity	9.35%
Minimum [Member] \| 2021 Arkansas Rate Case \| Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Intervenor Recommended Return on Common Equity	8.75%
Minimum [Member] \| February 2021 Severe Storm Fuel Costs \| Southwestern Electric Power Co [Member] \| Texas
Public Utilities, General Disclosures [Line Items]
Intervenor Recommended WACC	0.82%
Maximum [Member] \| 2012 Texas Base Rate Case [Member] \| Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Estimated Turk AFUDC Disallowance	$ 100
Estimated Turk AFUDC Refunds	$ 160
Maximum [Member] \| 2020 Louisiana Base Rate Case [Member] \| Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Intervenor Recommended Return on Common Equity	9.80%
Maximum [Member] \| 2021 Arkansas Rate Case \| Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Intervenor Recommended Return on Common Equity	9.25%
Maximum [Member] \| February 2021 Severe Storm Fuel Costs \| Southwestern Electric Power Co [Member] \| Texas
Public Utilities, General Disclosures [Line Items]
Intervenor Recommended WACC	1.625%

[1]	Amount excludes $2.3 billion and $165 million for AEP and AEPTCo, respectively, of Property, Plant and Equipment - Net classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[2]	2021 amounts exclude $485 million of regulatory assets classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.

Effects of Regulation (Details)

Effects of Regulation (Details) - USD ($) $ in Millions		12 Months Ended
Effects of Regulation (Details) - USD ($) $ in Millions		Dec. 31, 2021		Dec. 31, 2020		Dec. 31, 2019
Regulated Generating Unit to be Retired
Net Investment		$ 66,001.3	[1]	$ 63,901.6
Materials and Supplies		681.3		680.6
Annual Depreciation		2,717.1		2,487.5		$ 2,203.7
Regulatory Assets
Current Regulatory Assets		647.8	[2]	90.7
Noncurrent Regulatory Assets		4,142.3	[2]	3,527
Regulatory Liabilities
Current Regulatory Liabilities		1.5	[3]	52.6
Noncurrent Regulatory Liabilities		8,686.3	[3]	8,378.7
Effects of Regulation Textuals [Abstract]
Revisions in Cash Flow Estimates	[5],[6],[7],[8],[9]	138.6	[4]	183.1
Secured Debt		603.5		716.4
Accumulated Depreciation and Amortization		20,805.1		20,411.4
Asset Impairments and Other Related Charges		11.6		0		156.4
Assets Held for Sale		2,919.7		0
Liabilities Held for Sale		1,880.9		0
AEP Texas Inc. [Member]
Regulated Generating Unit to be Retired
Net Investment		10,635.4		9,813.6
Materials and Supplies		73.9		70
Annual Depreciation		327.2		364.2		365.9
Regulatory Assets
Noncurrent Regulatory Assets		275.2		266.8
Regulatory Liabilities
Noncurrent Regulatory Liabilities		1,242		1,270.8
Effects of Regulation Textuals [Abstract]
Revisions in Cash Flow Estimates	[6],[7],[9]	0		(16.8)
Secured Debt		404.7		492.6
Accumulated Depreciation and Amortization		1,644.1		1,529.3
Asset Impairments and Other Related Charges		0		0		32.5
AEP Transmission Co [Member]
Regulated Generating Unit to be Retired
Net Investment		11,935.7	[1]	10,772.8
Materials and Supplies		9.3		8.5
Annual Depreciation		297.3		249		176
Regulatory Assets
Noncurrent Regulatory Assets		8.5		15.1
Regulatory Liabilities
Noncurrent Regulatory Liabilities		644.1	[10]	581.8
Effects of Regulation Textuals [Abstract]
Accumulated Depreciation and Amortization		772.8		572.8
Assets Held for Sale		167.9		0
Liabilities Held for Sale		27.6		0
Appalachian Power Co [Member]
Regulated Generating Unit to be Retired
Net Investment		11,804.3		11,394.1
Materials and Supplies		109.8		99.6
Annual Depreciation		547		507.8		466.5
Regulatory Assets
Current Regulatory Assets		201.3		5.3
Noncurrent Regulatory Assets		757.6		686.3
Regulatory Liabilities
Noncurrent Regulatory Liabilities		1,238.8		1,224.7
Effects of Regulation Textuals [Abstract]
Revisions in Cash Flow Estimates	[6],[7],[9]	84.7		200.9
Secured Debt		198.8		223.8
Accumulated Depreciation and Amortization		5,051.8		4,716.2
Asset Impairments and Other Related Charges		0		0		92.9
Indiana Michigan Power Co [Member]
Regulated Generating Unit to be Retired
Net Investment		7,310.9		7,052.3
Materials and Supplies		175.2		175.8
Annual Depreciation		424.9		393.3		330.6
Regulatory Assets
Current Regulatory Assets		6.4		5.4
Noncurrent Regulatory Assets		410.9		404.8
Regulatory Liabilities
Current Regulatory Liabilities		1.5		20.8
Noncurrent Regulatory Liabilities		2,447.9		2,041.9
Effects of Regulation Textuals [Abstract]
Revisions in Cash Flow Estimates	[6],[7],[8],[9]	59.4		(4.9)
Accumulated Depreciation and Amortization		3,899.8		3,552.5
Pending Reg Assets Approved in Rate Case		3
Ohio Power Co [Member]
Regulated Generating Unit to be Retired
Net Investment		7,963		7,452.1
Materials and Supplies		74.1		66.9
Annual Depreciation		301.1		275		229.4
Regulatory Assets
Noncurrent Regulatory Assets		293		385.8
Regulatory Liabilities
Current Regulatory Liabilities		0		3.9
Noncurrent Regulatory Liabilities		1,020.9		1,005.2
Effects of Regulation Textuals [Abstract]
Revisions in Cash Flow Estimates	[6],[9]	0		0
Accumulated Depreciation and Amortization		2,458.3		2,350
Public Service Co Of Oklahoma [Member]
Regulated Generating Unit to be Retired
Net Investment		4,802.8		4,320
Materials and Supplies		56.2		54
Annual Depreciation		185.9		171.9		162.5
Regulatory Assets
Current Regulatory Assets		194.6		30.1
Noncurrent Regulatory Assets		1,037.4		375
Regulatory Liabilities
Noncurrent Regulatory Liabilities		835.3		802.2
Effects of Regulation Textuals [Abstract]
Revisions in Cash Flow Estimates	[6],[7],[9]	0		(4.8)
Accumulated Depreciation and Amortization		1,705.2		1,605.6
Southwestern Electric Power Co [Member]
Regulated Generating Unit to be Retired
Net Investment		7,400.1		7,088.2
Materials and Supplies		81.9		95.8
Annual Depreciation		292.9		271.2		247.9
Regulatory Assets
Current Regulatory Assets		143.9		2.6
Noncurrent Regulatory Assets		1,005.3		403.1
Regulatory Liabilities
Current Regulatory Liabilities		0		37.6
Noncurrent Regulatory Liabilities		806.9		863.4
Effects of Regulation Textuals [Abstract]
Revisions in Cash Flow Estimates	[5],[6],[7],[9]	2.5		10.1
Accumulated Depreciation and Amortization		3,170.3		3,158.5
Asset Impairments and Other Related Charges		11.6		0		$ 0
Net Under-Recovered Fuel Costs		144
Regulatory Liabilities Approved for Payment [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		8,423.9		7,889.8
Regulatory Liabilities Approved for Payment [Member] \| AEP Texas Inc. [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		1,229		1,276.5
Regulatory Liabilities Approved for Payment [Member] \| AEP Transmission Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		635.4		581.8
Regulatory Liabilities Approved for Payment [Member] \| Appalachian Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		1,234.3		1,224.7
Regulatory Liabilities Approved for Payment [Member] \| Indiana Michigan Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		2,447.9		2,041.9
Regulatory Liabilities Approved for Payment [Member] \| Ohio Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		1,020.7		1,005
Regulatory Liabilities Approved for Payment [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		779.1		802.2
Regulatory Liabilities Approved for Payment [Member] \| Southwestern Electric Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		806.9		550
Regulatory Liabilities Pending Final Regulatory Determination [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		262.4		488.9
Regulatory Liabilities Pending Final Regulatory Determination [Member] \| AEP Texas Inc. [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		13		(5.7)
Regulatory Liabilities Pending Final Regulatory Determination [Member] \| AEP Transmission Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[11]	8.7		0
Regulatory Liabilities Pending Final Regulatory Determination [Member] \| Appalachian Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[12]	4.5		0
Regulatory Liabilities Pending Final Regulatory Determination [Member] \| Ohio Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		0.2		0.2
Regulatory Liabilities Pending Final Regulatory Determination [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[13]	56.2		0
Regulatory Liabilities Pending Final Regulatory Determination [Member] \| Southwestern Electric Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[14]	0		313.4
Kentucky Power Co [Member]
Effects of Regulation Textuals [Abstract]
Liabilities Held for Sale		148
Kentucky Transmission Company \| AEP Transmission Co [Member]
Effects of Regulation Textuals [Abstract]
Liabilities Held for Sale		8
Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Approved for Payment [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		3,207.3		3,091.2
Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| AEP Texas Inc. [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		749.5		723.6
Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| AEP Transmission Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		271.4		198.6
Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Appalachian Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		703.6		679.2
Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Indiana Michigan Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		201.6		185.6
Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Ohio Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		467.6		458.4
Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		300.2		289.9
Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Southwestern Electric Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		463.7		473.3
Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Pending Final Regulatory Determination [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		0		2.5
Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Pending Final Regulatory Determination [Member] \| AEP Texas Inc. [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		0		2.5
Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		2,505.2		2,005.9
Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| AEP Texas Inc. [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		34.2		57.9
Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Appalachian Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		97.8		72.8
Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Indiana Michigan Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		2,063.7		1,601.5
Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Ohio Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		72.5		50.8
Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		55.1		52.3
Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Southwestern Electric Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		13		8.2
Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Pending Final Regulatory Determination [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		0.2		1.5
Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[15]	2,711.4		2,792.7
Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| AEP Texas Inc. [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[16]	445.3		495
Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| AEP Transmission Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[11]	364		383.2
Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Appalachian Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[12]	432.9		472.7
Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Indiana Michigan Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[17]	182.6		254.8
Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Ohio Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[18]	480.6		495.8
Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[13]	423.8		460
Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Southwestern Electric Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[14]	330.2		68.5
Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Pending Final Regulatory Determination [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[15]	262.2		484.9
Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Pending Final Regulatory Determination [Member] \| AEP Texas Inc. [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[16]	13		(8.2)
Regulatory Assets Pending Final Regulatory Approval [Member]
Regulatory Assets
Noncurrent Regulatory Assets		985.9		442.2
Regulatory Assets Pending Final Regulatory Approval [Member] \| AEP Texas Inc. [Member]
Regulatory Assets
Noncurrent Regulatory Assets		41.2		32.9
Regulatory Assets Pending Final Regulatory Approval [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		105.1		43.8
Regulatory Assets Pending Final Regulatory Approval [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		3.7		4.3
Regulatory Assets Pending Final Regulatory Approval [Member] \| Ohio Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		3.8		8.4
Regulatory Assets Pending Final Regulatory Approval [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Assets
Noncurrent Regulatory Assets		14.2		50.5
Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		817.9		247.3
Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		3,156.4		3,084.8
Regulatory Assets Approved for Recovery [Member] \| AEP Texas Inc. [Member]
Regulatory Assets
Noncurrent Regulatory Assets		234		233.9
Regulatory Assets Approved for Recovery [Member] \| AEP Transmission Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		8.5		15.1
Regulatory Assets Approved for Recovery [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		652.5		642.5
Regulatory Assets Approved for Recovery [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		407.2		400.5
Regulatory Assets Approved for Recovery [Member] \| Ohio Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		289.2		377.4
Regulatory Assets Approved for Recovery [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Assets
Noncurrent Regulatory Assets		1,023.2		324.5
Regulatory Assets Approved for Recovery [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		187.4		155.8
Kentucky Power Co [Member]
Effects of Regulation Textuals [Abstract]
Assets Held for Sale		485
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Regulatory Assets
Noncurrent Regulatory Assets		648		220.7
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| AEP Texas Inc. [Member]
Regulatory Assets
Noncurrent Regulatory Assets		0		16.3
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		6.8		3.7
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		0.1		0.5
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Assets
Noncurrent Regulatory Assets		0		34.4
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		641.2		124.4
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		1,535.1		1,131.4
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| AEP Texas Inc. [Member]
Regulatory Assets
Noncurrent Regulatory Assets		35.4		29.3
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		110.4		123.4
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		303.3		298.4
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Ohio Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		56.9		60.2
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Assets
Noncurrent Regulatory Assets		981.5		253.7
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		29.9		33.6
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Regulatory Assets
Noncurrent Regulatory Assets		337.9		221.5
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| AEP Texas Inc. [Member]
Regulatory Assets
Noncurrent Regulatory Assets		41.2		16.6
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		98.3		40.1
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		3.6	[19]	3.8
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Assets
Noncurrent Regulatory Assets		14.2		16.1
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		176.7		122.9
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		1,621.3		1,953.4
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| AEP Texas Inc. [Member]
Regulatory Assets
Noncurrent Regulatory Assets		198.6		204.6
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		542.1		519.1
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		103.9		102.1
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Ohio Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		232.3		317.2
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Assets
Noncurrent Regulatory Assets		41.7		70.8
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		157.5		122.2
Northeastern Plant, Unit 3 [Member] \| Generating Units Probable of Abandonment [Member] \| Public Service Co Of Oklahoma [Member]
Regulated Generating Unit to be Retired
Net Investment		167.2
Accelerated Depreciation Regulatory Asset		128.1
Cost of Removal Regulatory Liability	[20]	$ 20
Expected Retirement Date	[21]	2026
Annual Depreciation	[22]	$ 14.9
Pirkey Power Plant [Member] \| Generating Units Probable of Abandonment [Member] \| Southwestern Electric Power Co [Member]
Regulated Generating Unit to be Retired
Net Investment		120
Accelerated Depreciation Regulatory Asset		87
Cost of Removal Regulatory Liability		$ 39.3
Expected Retirement Date	[23]	2023
Annual Depreciation	[22]	$ 13.5
Welsh Plant, Units 1 and 3 [Member] \| Generating Units Probable of Abandonment [Member] \| Southwestern Electric Power Co [Member]
Regulated Generating Unit to be Retired
Net Investment		475.2
Accelerated Depreciation Regulatory Asset		45.9
Cost of Removal Regulatory Liability	[24]	$ 58.4
Expected Retirement Date	[25]	2028
Annual Depreciation	[22]	$ 36.4
Deferred Fuel Costs [Member] \| Regulatory Liabilities Currently Paying a Return [Member]
Regulatory Liabilities
Current Regulatory Liabilities		0		27.6
Deferred Fuel Costs [Member] \| Regulatory Liabilities Currently Paying a Return [Member] \| Southwestern Electric Power Co [Member]
Regulatory Liabilities
Current Regulatory Liabilities		0		37.6	[26]
Deferred Fuel Costs [Member] \| Regulatory Liabilities Currently Not Paying Return [Member]
Regulatory Liabilities
Current Regulatory Liabilities		$ 1.5		25
Remaining Refund Period		1 year
Deferred Fuel Costs [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Indiana Michigan Power Co [Member]
Regulatory Liabilities
Current Regulatory Liabilities		$ 1.5		20.8
Remaining Refund Period		1 year
Deferred Fuel Costs [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Ohio Power Co [Member]
Regulatory Liabilities
Current Regulatory Liabilities		$ 0		3.9
Deferred Fuel Costs [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Ohio Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 15.2		0
Remaining Refund Period		11 years
Deferred Fuel Costs [Member] \| Regulatory Assets Currently Earning Return [Member]
Regulatory Assets
Current Regulatory Assets		$ 409.4		41.4
Remaining Recovery Period		1 year
Deferred Fuel Costs [Member] \| Regulatory Assets Currently Earning Return [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Current Regulatory Assets		$ 127.2		3.3
Remaining Recovery Period		1 year
Deferred Fuel Costs [Member] \| Regulatory Assets Currently Earning Return [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Current Regulatory Assets		$ 6.4		5.4
Remaining Recovery Period		1 year
Deferred Fuel Costs [Member] \| Regulatory Assets Currently Earning Return [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Assets
Current Regulatory Assets		$ 194.6		30.1
Remaining Recovery Period		1 year
Deferred Fuel Costs [Member] \| Regulatory Assets Currently Earning Return [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Current Regulatory Assets	[27]	$ 81.2		2.6
Remaining Recovery Period		1 year
Deferred Fuel Costs [Member] \| Regulatory Assets Currently Not Earning Return [Member]
Regulatory Assets
Current Regulatory Assets		$ 175.7		49.3
Remaining Recovery Period		1 year
Deferred Fuel Costs [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Current Regulatory Assets		$ 74.1		2
Remaining Recovery Period		1 year
Dolet Hills Power Station Accelerated Depreciation [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 72.3		71.2
Dolet Hills Power Station Accelerated Depreciation [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets	[28]	72.3		71.2
Kentucky Deferred Purchase Power Expenses [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Regulatory Assets
Noncurrent Regulatory Assets		0		41.3
Plant Retirement Costs - Unrecovered Plant, Louisiana [Member] \| Southwestern Electric Power Co [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Regulatory Assets
Noncurrent Regulatory Assets		35
Plant Retirement Costs - Unrecovered Plant, Louisiana [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Regulatory Assets
Noncurrent Regulatory Assets		35.2		35.2
Plant Retirement Costs - Unrecovered Plant, Louisiana [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		35.2		35.2
Pirkey Power Plant Accelerated Depreciation [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Regulatory Assets
Noncurrent Regulatory Assets		87		12.2
Pirkey Power Plant Accelerated Depreciation [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		87		12.2
Welsh Plant, Units 1 and 3 Accelerated Depreciation [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Regulatory Assets
Noncurrent Regulatory Assets		45.9		3.6
Welsh Plant, Units 1 and 3 Accelerated Depreciation [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		45.9		3.6
Oklaunion Power Station Accelerated Depreciation [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Regulatory Assets
Noncurrent Regulatory Assets		0		34.4
Oklaunion Power Station Accelerated Depreciation [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Assets
Noncurrent Regulatory Assets		0		34.4
COVID-19 - Virginia [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		6.8		3.7
Other Regulatory Assets Pending Final Regulatory Approval [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Regulatory Assets
Noncurrent Regulatory Assets		9.2		22.8
Other Regulatory Assets Pending Final Regulatory Approval [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		0.1		0.5
Other Regulatory Assets Pending Final Regulatory Approval [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		2.4		2.2
Other Regulatory Assets Pending Final Regulatory Approval [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Regulatory Assets
Noncurrent Regulatory Assets		43.9		36.5
Other Regulatory Assets Pending Final Regulatory Approval [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| AEP Texas Inc. [Member]
Regulatory Assets
Noncurrent Regulatory Assets		7.4		1.5
Other Regulatory Assets Pending Final Regulatory Approval [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		3.6		1.5
Other Regulatory Assets Pending Final Regulatory Approval [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		1.9		0
Other Regulatory Assets Pending Final Regulatory Approval [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		18.4		14.5
Storm Related Costs [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 17.4		11.5
Remaining Recovery Period		3 years
Storm Related Costs [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 17.4		11.5
Remaining Recovery Period		3 years
Storm Related Costs [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 256.9		134.2
Storm Related Costs [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| AEP Texas Inc. [Member]
Regulatory Assets
Noncurrent Regulatory Assets		22.4		0.8
Storm Related Costs [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		68.8		3.4
Storm Related Costs [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Ohio Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		3.8		4
Storm Related Costs [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Assets
Noncurrent Regulatory Assets		13.9		15.8
Storm Related Costs [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		148		99.3
Storm Related Costs [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| AEP Texas Inc. [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 12.8		17.1
Remaining Recovery Period		3 years
Storm Related Costs [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 12.6		0.3
Remaining Recovery Period		2 years
Plant Retirement Costs - Asset Retirement Obligation Costs [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 0		107.1
Plant Retirement Costs - Asset Retirement Obligation Costs [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Regulatory Assets
Noncurrent Regulatory Assets		25.9		25.9
Plant Retirement Costs - Asset Retirement Obligation Costs [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		25.9		25.9
Plant Retirement Costs - Asset Retirement Obligation Costs [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 293.2		212.7
Remaining Recovery Period		21 years
Plant Retirement Costs - Asset Retirement Obligation Costs [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 293.1		202.7
Remaining Recovery Period		15 years
Environmental Expense Deferral - Virginia [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 0		9.3
COVID-19 [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Regulatory Assets
Noncurrent Regulatory Assets		11.2		24.9
COVID-19 [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| AEP Texas Inc. [Member]
Regulatory Assets
Noncurrent Regulatory Assets		2.1		10.5
COVID-19 [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		1.7		3.8
COVID-19 [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Ohio Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		0		4.4
COVID-19 [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Assets
Noncurrent Regulatory Assets		0.3		0.3
Vegetation Management Program [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| AEP Texas Inc. [Member]
Regulatory Assets
Noncurrent Regulatory Assets		5.2		3.8
Vegetation Management Program [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| AEP Texas Inc. [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 17.4		22.4
Remaining Recovery Period		4 years
Plant Retirement Costs - Unrecovered Plant [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets	[29]	$ 522.2		713.1
Remaining Recovery Period		25 years
Plant Retirement Costs - Unrecovered Plant [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 110		122.4
Remaining Recovery Period		22 years
Plant Retirement Costs - Unrecovered Plant [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 170.8		191.5
Remaining Recovery Period		7 years
Plant Retirement Costs - Unrecovered Plant [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Assets
Noncurrent Regulatory Assets	[30]	$ 227.6		180.8
Remaining Recovery Period		25 years
Plant Retirement Costs - Unrecovered Plant, Arkansas [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 13.7		14.4
Remaining Recovery Period		21 years
Plant Retirement Costs - Unrecovered Plant, Texas [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 51.9		16.1
Remaining Recovery Period		25 years
Plant Retirement Costs - Unrecovered Plant, Texas [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 51.9		16.1
Remaining Recovery Period		25 years
Meter Replacement Costs [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 44.9		55.5
Remaining Recovery Period		6 years
Meter Replacement Costs [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| AEP Texas Inc. [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 22.7		29.3
Remaining Recovery Period		5 years
Meter Replacement Costs [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 22.2		26.2
Remaining Recovery Period		6 years
Ohio Distribution Decoupling [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 41.6		46.6
Remaining Recovery Period		2 years
Ohio Distribution Decoupling [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Ohio Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 41.6		46.6
Remaining Recovery Period		2 years
Ohio Basic Transmission Cost Rider [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Ohio Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 5.2		12.3
Remaining Recovery Period		2 years
Environmental Controls Projects [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 36.2		38.6
Remaining Recovery Period		19 years
Environmental Controls Projects [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 25.2		26.5
Remaining Recovery Period		19 years
Environmental Controls Projects [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 11		12.1
Remaining Recovery Period		11 years
Rockport Plant Dry Sorbent Injection System and Selective Catalytic Reduction [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 66.6		34.4
Remaining Recovery Period		7 years
Rockport Plant Dry Sorbent Injection System and Selective Catalytic Reduction [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 66.6		34.4
Remaining Recovery Period		7 years
Cook Plant Uprate Project [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 27.7		30.2
Remaining Recovery Period		12 years
Cook Plant Uprate Project [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 27.7		30.2
Remaining Recovery Period		12 years
Advanced Metering System [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| AEP Texas Inc. [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 0		16.3
Advanced Metering System [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| AEP Texas Inc. [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 10.6		0
Remaining Recovery Period		1 year
Other Regulatory Assets Approved for Recovery [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 99.2		94.4
Other Regulatory Assets Approved for Recovery [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| AEP Texas Inc. [Member]
Regulatory Assets
Noncurrent Regulatory Assets		2.1		0
Other Regulatory Assets Approved for Recovery [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		0.4		1
Other Regulatory Assets Approved for Recovery [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		6		7
Other Regulatory Assets Approved for Recovery [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Assets
Noncurrent Regulatory Assets		1.9		0.5
Other Regulatory Assets Approved for Recovery [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		5.2		7.1
Other Regulatory Assets Approved for Recovery [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		158.5		133.5
Other Regulatory Assets Approved for Recovery [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| AEP Texas Inc. [Member]
Regulatory Assets
Noncurrent Regulatory Assets		4.3		7.8
Other Regulatory Assets Approved for Recovery [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		10.7		12.7
Other Regulatory Assets Approved for Recovery [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		13.8		16
Other Regulatory Assets Approved for Recovery [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Ohio Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		12.3		15.8
Other Regulatory Assets Approved for Recovery [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Assets
Noncurrent Regulatory Assets		13.1		12.4
Other Regulatory Assets Approved for Recovery [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		18.8		17
Vegetation Management [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 29.3		67.8
Remaining Recovery Period		4 years
Asset Retirement Obligation - Louisiana [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 10.3		9.1
Deferred Cook Plant Life Cycle Management Project Costs [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 13.1		14.1
Remaining Recovery Period		13 years
Cook Plant Study Costs - Indiana [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 9.4		10.1
Remaining Recovery Period		14 years
Cook Plant Turbine [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 9.7		11.1
Remaining Recovery Period		17 years
Pension and OPEB Funded Status [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Indiana Michigan Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 27.6		0
Remaining Refund Period		12 years
Pension and OPEB Funded Status [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 677		1,088.6
Remaining Recovery Period		12 years
Pension and OPEB Funded Status [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| AEP Texas Inc. [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 119		145
Remaining Recovery Period		12 years
Pension and OPEB Funded Status [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 62.7		114.4
Remaining Recovery Period		12 years
Pension and OPEB Funded Status [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 0		25.7
Pension and OPEB Funded Status [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Ohio Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 83.3		130.7
Remaining Recovery Period		12 years
Pension and OPEB Funded Status [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 22.9		52.3
Remaining Recovery Period		12 years
Pension and OPEB Funded Status [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 73.8		89.1
Remaining Recovery Period		12 years
Unamortized Loss on Reacquired Debt [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 111.2		120
Remaining Recovery Period		27 years
Unamortized Loss on Reacquired Debt [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 78.2		82.1
Remaining Recovery Period		24 years
Unamortized Loss on Reacquired Debt [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 14.2		15.7
Remaining Recovery Period		27 years
Unamortized Loss on Reacquired Debt [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 5.7		6.1
Remaining Recovery Period		17 years
Peak Demand Reduction/Energy Efficiency [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| AEP Texas Inc. [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 14.5		7.7
Remaining Recovery Period		2 years
Peak Demand Reduction/Energy Efficiency [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 17.8		16.8
Remaining Recovery Period		5 years
Unrealized Loss on Forward Commitments [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 100.8		111.3
Remaining Recovery Period		11 years
Unrealized Loss on Forward Commitments [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 7.2		0
Remaining Recovery Period		3 years
Unrealized Loss on Forward Commitments [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Ohio Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 92.1		110
Remaining Recovery Period		11 years
Virginia Transmission Rate Adjustment Clause [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 37.2		18.8
Remaining Recovery Period		2 years
Virginia Transmission Rate Adjustment Clause [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 37.2		18.8
Remaining Recovery Period		2 years
Vegetation Management Program - West Virginia [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 11.9		45.4
Remaining Recovery Period		2 years
Cook Nuclear Plant Refueling Outage Levelization [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 32		39.5
Remaining Recovery Period		3 years
Cook Nuclear Plant Refueling Outage Levelization [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 32		39.5
Remaining Recovery Period		3 years
PJM/SPP Annual Formula Rate True Up [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 17.6		33
Remaining Recovery Period		2 years
PJM/SPP Annual Formula Rate True Up [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| AEP Transmission Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 8.5		15.1
Remaining Recovery Period		2 years
Postemployment Benefits [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 29.1		29.1
Remaining Recovery Period		3 years
Postemployment Benefits [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 13.3		13.5
Remaining Recovery Period		3 years
Postemployment Benefits [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 9		4.9
Remaining Recovery Period		3 years
Postemployment Benefits [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Ohio Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 6.2		6.7
Remaining Recovery Period		3 years
PJM Annual Formula Rate True-up [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 3.5		12.7
Remaining Recovery Period		2 years
OVEC Purchased Power [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Ohio Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 14.8		0
Remaining Refund Period		2 years
OVEC Purchased Power [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 0		27.4
OVEC Purchased Power [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Ohio Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		0		27.4
Fuel and Purchased Power Adjustment Rider [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 12.1		24
Remaining Recovery Period		2 years
PJM Costs and Off-system Sales Margin Sharing - Indiana [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Indiana Michigan Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 0		13.3
PJM Costs and Off-system Sales Margin Sharing - Indiana [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Indiana Michigan Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 15.1		0
Remaining Recovery Period		2 years
Other Regulatory Liabilities Pending Final Regulatory Determination [Member] \| Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Pending Final Regulatory Determination [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 0		2.5
Other Regulatory Liabilities Pending Final Regulatory Determination [Member] \| Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Pending Final Regulatory Determination [Member] \| AEP Texas Inc. [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		0		2.5
Other Regulatory Liabilities Pending Final Regulatory Determination [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Pending Final Regulatory Determination [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		0.2		1.5
Other Regulatory Liabilities Pending Final Regulatory Determination [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Pending Final Regulatory Determination [Member] \| Ohio Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		0.2		0.2
Excess ADIT Associated with Certain Depreciable Property [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[15],[31]	3,556.7		3,485.7
Excess ADIT Associated with Certain Depreciable Property [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| AEP Texas Inc. [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[16],[32]	498.8		506
Excess ADIT Associated with Certain Depreciable Property [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| AEP Transmission Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[11],[33]	522.6		531.5
Excess ADIT Associated with Certain Depreciable Property [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Appalachian Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[12],[34]	663.6		690
Excess ADIT Associated with Certain Depreciable Property [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Indiana Michigan Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[17],[35]	433.6		450.6
Excess ADIT Associated with Certain Depreciable Property [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Ohio Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[18],[36]	325		334.6
Excess ADIT Associated with Certain Depreciable Property [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[13],[37]	389.3		397
Excess ADIT Associated with Certain Depreciable Property [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Southwestern Electric Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[14],[38]	609		332.5
Excess ADIT Associated with Certain Depreciable Property [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Pending Final Regulatory Determination [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[15]	0		291.6
Excess ADIT Associated with Certain Depreciable Property [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Pending Final Regulatory Determination [Member] \| Southwestern Electric Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[14]	0		291.6
Excess ADIT that is Not Subject to Rate Normalization Requirements [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[15]	$ 386.5		714.9
Remaining Refund Period		7 years
Excess ADIT that is Not Subject to Rate Normalization Requirements [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| AEP Texas Inc. [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[16]	$ 0		41.7
Excess ADIT that is Not Subject to Rate Normalization Requirements [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| AEP Transmission Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[11]	$ (26.2)		(30.6)
Remaining Refund Period		7 years
Excess ADIT that is Not Subject to Rate Normalization Requirements [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Appalachian Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[12]	$ 83.6		139.1
Remaining Refund Period		7 years
Excess ADIT that is Not Subject to Rate Normalization Requirements [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Indiana Michigan Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[17]	$ 90.2		136.2
Remaining Refund Period		3 years
Excess ADIT that is Not Subject to Rate Normalization Requirements [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Ohio Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[18]	$ 190.8		223.9
Remaining Refund Period		7 years
Excess ADIT that is Not Subject to Rate Normalization Requirements [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[13]	$ 46.4		71.3
Remaining Refund Period		3 years
Excess ADIT that is Not Subject to Rate Normalization Requirements [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Southwestern Electric Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[14]	$ 7		11.5
Remaining Refund Period		1 year
Excess ADIT that is Not Subject to Rate Normalization Requirements [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Pending Final Regulatory Determination [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[15],[40]	$ 262.2	[39]	193.3
Excess ADIT that is Not Subject to Rate Normalization Requirements [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Pending Final Regulatory Determination [Member] \| AEP Texas Inc. [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[16]	13		(8.2)
Excess ADIT that is Not Subject to Rate Normalization Requirements [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Pending Final Regulatory Determination [Member] \| AEP Transmission Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[11]	8.7	[41]	0
Excess ADIT that is Not Subject to Rate Normalization Requirements [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Pending Final Regulatory Determination [Member] \| Appalachian Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[12]	4.5	[42]	0
Excess ADIT that is Not Subject to Rate Normalization Requirements [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Pending Final Regulatory Determination [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[13],[43]	56.2		0
Excess ADIT that is Not Subject to Rate Normalization Requirements [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Pending Final Regulatory Determination [Member] \| Southwestern Electric Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[14]	0		21.8
Excess ADIT that is Not Subject to Rate Normalization Requirements [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Pending Final Regulatory Determination [Member] \| AEPTHCo's investment in ETT and Transource Energy [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		173		173
Asset Removal Costs [Member] \| Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Approved for Payment [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[44]	3,172.1		3,061.9
Asset Removal Costs [Member] \| Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| AEP Texas Inc. [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[45]	744.7		718.3
Asset Removal Costs [Member] \| Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| AEP Transmission Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[46]	271.4		198.6
Asset Removal Costs [Member] \| Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Appalachian Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[47]	703.3		678.9
Asset Removal Costs [Member] \| Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Indiana Michigan Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[48]	179.7		168.2
Asset Removal Costs [Member] \| Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Ohio Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[49]	467.6		458.4
Asset Removal Costs [Member] \| Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[50]	300.2		289.9
Asset Removal Costs [Member] \| Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Southwestern Electric Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[51]	461.3		470.9
Deferred Investment Tax Credits [Member] \| Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Approved for Payment [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 2.1		4.1
Remaining Refund Period		32 years
Deferred Investment Tax Credits [Member] \| Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Appalachian Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 0.3		0.3
Remaining Refund Period		32 years
Deferred Investment Tax Credits [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 248.5		216.7
Remaining Refund Period		35 years
Deferred Investment Tax Credits [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| AEP Texas Inc. [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 6.8		8.5
Remaining Refund Period		12 years
Deferred Investment Tax Credits [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Indiana Michigan Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 22.4		21.3
Remaining Refund Period		29 years
Deferred Investment Tax Credits [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 50.8		51
Remaining Refund Period		23 years
Other Regulatory Liabilities Approved for Payment [Member] \| Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Approved for Payment [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 33.1		25.2
Other Regulatory Liabilities Approved for Payment [Member] \| Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| AEP Texas Inc. [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		4.8		5.3
Other Regulatory Liabilities Approved for Payment [Member] \| Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Indiana Michigan Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		21.9		17.4
Other Regulatory Liabilities Approved for Payment [Member] \| Regulatory Liabilities Currently Paying a Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Southwestern Electric Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		2.4		2.4
Other Regulatory Liabilities Approved for Payment [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		90.9		82.9
Other Regulatory Liabilities Approved for Payment [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| AEP Texas Inc. [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		1.1		1.2
Other Regulatory Liabilities Approved for Payment [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Appalachian Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		15		6.8
Other Regulatory Liabilities Approved for Payment [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Indiana Michigan Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		6		28.4
Other Regulatory Liabilities Approved for Payment [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Ohio Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		0.4		0.7
Other Regulatory Liabilities Approved for Payment [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		4.3		1.3
Other Regulatory Liabilities Approved for Payment [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Southwestern Electric Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		1.9		2.7
Excess Nuclear Decommissioning Funding [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[52]	1,939.7		1,476.6
Excess Nuclear Decommissioning Funding [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Indiana Michigan Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[53]	1,939.7		1,476.6
PJM Transmission Enhancement Refund [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 42.9		56.2
Remaining Refund Period		4 years
PJM Transmission Enhancement Refund [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Appalachian Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 13		16.3
Remaining Refund Period		4 years
PJM Transmission Enhancement Refund [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Indiana Michigan Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 7.9		9.9
Remaining Refund Period		4 years
PJM Transmission Enhancement Refund [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Ohio Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 19.6		24.5
Remaining Refund Period		4 years
Transition and Restoration Charges [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 26.3		48.2
Remaining Refund Period		8 years
Transition and Restoration Charges [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| AEP Texas Inc. [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 26.3		48.2
Remaining Refund Period		8 years
2017-2019 Virginia Triennial Revenue Provision [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 41.6		44.2
Remaining Refund Period		27 years
2017-2019 Virginia Triennial Revenue Provision [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Appalachian Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 41.6		44.2
Remaining Refund Period		27 years
Spent Nuclear Fuel [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[52]	$ 49.5		43.1
Spent Nuclear Fuel [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Indiana Michigan Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[53]	49.5		43.1
Peak Demand Reduction/Energy Efficiency [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 28.6		26.3
Remaining Refund Period		2 years
Peak Demand Reduction/Energy Efficiency [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Ohio Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 22.5		19.9
Remaining Refund Period		2 years
Peak Demand Reduction/Energy Efficiency [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Southwestern Electric Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 2.6		5.2
Remaining Refund Period		2 years
Peak Demand Reduction/Energy Efficiency [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 40.8		27
Remaining Recovery Period		5 years
Ohio Enhanced Service Reliability Plan [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Ohio Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 0		5.7
Ohio Enhanced Service Reliability Plan [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Ohio Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 9.5		0
Remaining Recovery Period		2 years
Income Taxes Subject to Flow Through [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[15]	$ (1,231.8)		(1,407.9)
Remaining Refund Period		52 years
Income Taxes Subject to Flow Through [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| AEP Texas Inc. [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[16]	$ (53.5)		(52.7)
Remaining Refund Period		35 years
Income Taxes Subject to Flow Through [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| AEP Transmission Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[11]	$ (132.4)		(117.7)
Remaining Refund Period		36 years
Income Taxes Subject to Flow Through [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Appalachian Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[12]	$ (314.3)		(356.4)
Remaining Refund Period		23 years
Income Taxes Subject to Flow Through [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Indiana Michigan Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[17]	$ (341.2)		(332)
Remaining Refund Period		20 years
Income Taxes Subject to Flow Through [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Ohio Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[18]	$ (35.2)		(62.7)
Remaining Refund Period		30 years
Income Taxes Subject to Flow Through [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[13]	$ (11.9)		(8.3)
Remaining Refund Period		28 years
Income Taxes Subject to Flow Through [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Southwestern Electric Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities	[14]	$ (285.8)		(275.5)
Remaining Refund Period		27 years
Smart Grid Costs [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Ohio Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 19.3		19.2
Remaining Recovery Period		2 years
Distribution Investment Rider [Member] \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Ohio Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 2.1		7.4
Remaining Recovery Period		2 years
Red Rock Generating Facility [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 7.9		8.2
Remaining Recovery Period		35 years
Dolet Hills Generating Station and Related Fuel Operations \| Southwestern Electric Power Co [Member]
Effects of Regulation Textuals [Abstract]
Share of Net Investment in Dolet Hills Power Station		$ 108
Amount of Dolet Hills Fuel Costs Approved to Recover		20
Approved Deferral of Dolet Hills Fuel Costs		30
Pirkey Power Plant and Related Fuel Operations \| Southwestern Electric Power Co [Member]
Effects of Regulation Textuals [Abstract]
Share of Net Investment in Pirkey Power Plant		207
Pirkey Power Plant and Sabine Unbilled Fixed Costs		91
Dolet Hills Power Station [Member] \| Southwestern Electric Power Co [Member]
Effects of Regulation Textuals [Abstract]
Revisions in Cash Flow Estimates		21
Asset Impairments and Other Related Charges		12
Dolet Hills Power Station [Member] \| Southwestern Electric Power Co [Member] \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Regulatory Assets
Noncurrent Regulatory Assets		72
Unrealized Gain on Forward Commitments [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 37.2		11.7
Remaining Refund Period		3 years
Unrealized Gain on Forward Commitments [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Appalachian Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 28.2		5.5
Remaining Refund Period		3 years
Unrealized Gain on Forward Commitments [Member] \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Southwestern Electric Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 3.7		0.2
Remaining Refund Period		2 years
Welsh Plant Unit 2 \| Southwestern Electric Power Co [Member]
Effects of Regulation Textuals [Abstract]
Impairment Charge Welsh Plant, Unit 2		$ 7
February 2021 Severe Storm Fuel Costs \| Regulatory Assets Currently Earning Return [Member]
Regulatory Assets
Current Regulatory Assets	[54]	$ 62.7		0
Remaining Recovery Period		1 year
February 2021 Severe Storm Fuel Costs \| Regulatory Assets Currently Earning Return [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Current Regulatory Assets	[55]	$ 62.7		0
Remaining Recovery Period		1 year
February 2021 Severe Storm Fuel Costs \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 367.5		0
February 2021 Severe Storm Fuel Costs \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		367.5		0
February 2021 Severe Storm Fuel Costs \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets	[56]	679.3		0
February 2021 Severe Storm Fuel Costs \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Public Service Co Of Oklahoma [Member]
Regulatory Assets
Noncurrent Regulatory Assets	[57]	679.3		0
Dolet Hills Power Station Fuel Costs - Louisiana \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Regulatory Assets
Noncurrent Regulatory Assets		30.9		0
Dolet Hills Power Station Fuel Costs - Louisiana \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		30.9		0
Texas Transmission Cost Recovery Factor \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 30.6		4.6
Remaining Recovery Period		2 years
Texas Transmission Cost Recovery Factor \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| AEP Texas Inc. [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 30.6		4.6
Remaining Recovery Period		2 years
Texas Retail Electric Provider Bad Debt Expense \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| AEP Texas Inc. [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 4.1		0
Environmental Compliance Costs \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Appalachian Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 13.7		0
Remaining Recovery Period		2 years
Rockport Plant Unit 2 Selective Catalytic Reduction \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Indiana Michigan Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 10.6		8.9
Remaining Refund Period		2 years
Ohio Economic Development Rider \| Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Ohio Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 10.1		1.3
Remaining Recovery Period		2 years
PJM Load Service Entity Formula Rate True-Up \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Ohio Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 7.5		0
Remaining Recovery Period		2 years
Dolet Hills Power Station Fuel Costs - Arkansas \| Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Approved for Recovery [Member] \| Southwestern Electric Power Co [Member]
Regulatory Assets
Noncurrent Regulatory Assets		$ 13		0
Remaining Recovery Period		5 years
Vegetation Management - Texas \| Regulatory Liabilities Currently Not Paying Return [Member] \| Regulatory Liabilities Approved for Payment [Member] \| Southwestern Electric Power Co [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 4.8		$ 0.1
Remaining Refund Period		2 years
2020 Texas Fuel Reconciliation \| Southwestern Electric Power Co [Member]
Effects of Regulation Textuals [Abstract]
Amount of Fuel Costs Under Review		$ 1,700
2020 Texas Fuel Reconciliation \| Southwestern Electric Power Co [Member] \| TEXAS
Effects of Regulation Textuals [Abstract]
Amount of Fuel Costs Under Review		616
Recommended Disallowance from Staff or Intervenors		125
Reduction in Recoverable Fuel Costs		10
State Income Tax Rate Changes \| Excess ADIT that is Not Subject to Rate Normalization Requirements [Member] \| Income Tax Related Regulatory Liabilities [Member] \| Regulatory Liabilities Pending Final Regulatory Determination [Member]
Regulatory Liabilities
Noncurrent Regulatory Liabilities		$ 70

[1]	Amount excludes $2.3 billion and $165 million for AEP and AEPTCo, respectively, of Property, Plant and Equipment - Net classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[2]	2021 amounts exclude $485 million of regulatory assets classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[3]	2021 amounts exclude $148 million of regulatory liabilities classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[4]	Includes $18 million of ARO classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[5]	Includes ARO related to Sabine and DHLC.
[6]	Includes ARO related to asbestos removal.
[7]	Includes ARO related to ash disposal facilities.
[8]	Includes ARO related to nuclear decommissioning costs for the Cook Plant of $1.93 billion and $1.80 billion as of December 31, 2021 and 2020, respectively.
[9]	Unless discussed above, primarily related to ash ponds, landfills and mine reclamation, generally due to changes in estimated closure area, volumes and/or unit costs.
[10]	2021 amounts exclude $8 million of regulatory liabilities classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[11]	Predominately pays a return due to the inclusion of Excess ADIT in rate base.
[12]	Predominately pays a return due to the inclusion of Excess ADIT in rate base.
[13]	Predominately pays a return due to the inclusion of Excess ADIT in rate base.
[14]	Predominately pays a return due to the inclusion of Excess ADIT in rate base.
[15]	Predominately pays a return due to the inclusion of Excess ADIT in rate base.
[16]	Predominately pays a return due to the inclusion of Excess ADIT in rate base.
[17]	Predominately pays a return due to the inclusion of Excess ADIT in rate base.
[18]	Predominately pays a return due to the inclusion of Excess ADIT in rate base.
[19]	In February 2022, the IURC issued an order approving Indiana jurisdictional COVID-19 costs and certain other regulatory assets totaling $3 million. See “2021 Indiana Base Rate Case” section of Note 4 for additional information.
[20]	Includes Northeastern Plant, Unit 4, which was retired in 2016. Removal of Northeastern Plant, Unit 4, will be performed with Northeastern Plant, Unit 3, after retirement.
[21]	Northeastern Plant, Unit 3 is currently being recovered through 2040.
[22]	Represents the amount of annual depreciation that has been collected from customers over the prior 12-month period.
[23]	Pirkey Power Plant is currently being recovered through 2025 in the Louisiana jurisdiction and through 2045 in the Arkansas and Texas jurisdictions.
[24]	Includes Welsh Plant, Unit 2, which was retired in 2016. Removal of Welsh Plant, Unit 2, will be performed with Welsh Plant, Units 1 and 3, after retirement.
[25]	Unit 1 is being recovered through 2027 in the Louisiana jurisdiction and through 2037 in the Arkansas and Texas jurisdictions. Unit 3 is being recovered through 2032 in the Louisiana jurisdiction and through 2042 in the Arkansas and Texas jurisdictions.
[26]	2020 amount includes Arkansas and Texas jurisdictions.
[27]	2021 amount includes Arkansas, Louisiana and Texas jurisdictions. 2020 amount includes Louisiana jurisdiction.
[28]	2021 amount includes Arkansas and Louisiana jurisdictions. 2020 amount includes Arkansas, Louisiana and Texas jurisdictions.
[29]	Northeastern Plant, Unit 3 is approved for recovery through 2040, but expected to retire in 2026. PSO records a regulatory asset for accelerated depreciation. See “Regulated Generating Units to be Retired” section above for additional information.
[30]	Northeastern Plant, Unit 3 is approved for recovery through 2040, but expected to retire in 2026. PSO records a regulatory asset for accelerated depreciation. See “Regulated Generating Units to be Retired” section above for additional information
[31]	Refunded using ARAM.
[32]	Refunded using ARAM.
[33]	Refunded using ARAM.
[34]	Refunded using ARAM.
[35]	Refunded using ARAM.
[36]	Refunded using ARAM.
[37]	Refunded using ARAM.
[38]	Refunded using ARAM.
[39]	2021 amount includes $70 million for Excess ADIT as a result of changes in various state income tax rates. See the “Federal and State Tax Legislation” section of Note 12 for additional information.
[40]	2021 and 2020 amounts include approximately $173 million and $173 million, respectively, related to AEP Transmission Holdco’s investment in ETT and Transource Energy. AEP Transmission Holdco expects to amortize the balance commensurate with the return of Excess ADIT to ETT and Transource Energy’s customers.
[41]	Amount represents regulatory liabilities for Excess ADIT as a result of changes in various state income tax rates. See the “Federal and State Tax Legislation” section of Note 12 for additional information.
[42]	Amount represents regulatory liabilities for Excess ADIT as a result of a change in the state income tax apportionment formula in West Virginia. See the “Federal and State Tax Legislation” section of Note 12 for additional information.
[43]	Amount represents regulatory liabilities for Excess ADIT as a result of a change in the state income tax rate. See the “Federal and State Tax Legislation” section of Note 12 for additional information.
[44]	Relieved as removal costs are incurred.
[45]	Relieved as removal costs are incurred.
[46]	Relieved as removal costs are incurred.
[47]	Relieved as removal costs are incurred.
[48]	Relieved as removal costs are incurred.
[49]	Relieved as removal costs are incurred.
[50]	Relieved as removal costs are incurred.
[51]	Relieved as removal costs are incurred.
[52]	Relieved when plant is decommissioned.
[53]	Relieved when plant is decommissioned.
[54]	Unrecovered Winter Storm Fuel Costs are pending final regulatory approval as of December 31, 2021. The current asset balance represents amounts expected to be recovered in the Arkansas and Louisiana jurisdictions over the next 12 months. See “February 2021 Severe Winter Weather Impacts in SPP” section of SWEPCo Rate Matters in Note 4 for additional information.
[55]	Unrecovered Winter Storm Fuel Costs are pending final regulatory approval as of December 31, 2021. The current asset balance represents amounts expected to be recovered in the Arkansas and Louisiana jurisdictions over the next 12 months. See “February 2021 Severe Winter Weather Impacts in SPP” section of SWEPCo Rate Matters in Note 4 for additional information.
[56]	In February 2022, the OCC approved PSO’s securitization of the Unrecovered Winter Storm Fuel Costs. The timing of securitization is to be determined. See ”February 2021 Severe Winter Weather Impacts in SPP” section of PSO Rate Matters in Note 4 for additional information.
[57]	In February 2022, the OCC approved PSO’s securitization of the Unrecovered Winter Storm Fuel Costs. The timing of securitization is to be determined. See ”February 2021 Severe Winter Weather Impacts in SPP” section of PSO Rate Matters in Note 4 for additional information.

Commitments, Guarantees and C_3

Commitments, Guarantees and Contingencies (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Contractual Commitments
Less than 1 year		$ 854.2
For 2-3 years		894.4
For 4-5 years		459.5
After 5 years		966.2
Total Contractual Commitments		3,174.3
Commitments, Guarantees and Contingencies (Textuals)
Revolving Credit Facilities		5,000
Disposal, Assessed Fees and Related Interest	[1]	281.3	$ 281.2
Rockport Plant, Unit 2 Acquisition Price		116
AEP Wind Holdings LLC [Member] \| Generation and Marketing [Member]
Commitments, Guarantees and Contingencies (Textuals)
Maximum Potential Amount of Future Payments Associated with Guarantee		142
Guarantor Obligations, Current Carrying Value		28
Guarantor Obligations, Current Carrying Value, Contingent Portion		2
Letters of Credit [Member]
Maximum Future Payments for Letters of Credit Under Uncommitted Facilities
Maximum Future Payments for Letters of Credit Issued Under the Uncommitted Facility		168.5
Commitments, Guarantees and Contingencies (Textuals)
Letters of Credit Limit		1,200
Uncommitted Facility		375
Letters of Credit [Member] \| Subsequent Event [Member]
Commitments, Guarantees and Contingencies (Textuals)
Uncommitted Facility		400
Fuel Purchase Contracts [Member]
Contractual Commitments
Less than 1 year	[2],[3],[4]	706.4
For 2-3 years	[2],[3],[4]	584.9
For 4-5 years	[2],[3],[4]	167.8
After 5 years	[2],[3],[4]	301.8
Total Contractual Commitments	[2],[3],[4]	1,760.9
Energy and Capacity Purchase Contracts [Member]
Contractual Commitments
Less than 1 year		147.8
For 2-3 years		309.5
For 4-5 years		291.7
After 5 years		664.4
Total Contractual Commitments		1,413.4
AEP Texas Inc. [Member] \| Letters of Credit [Member]
Maximum Future Payments for Letters of Credit Under Uncommitted Facilities
Maximum Future Payments for Letters of Credit Issued Under the Uncommitted Facility		2.2
Appalachian Power Co [Member]
Contractual Commitments
Less than 1 year		307.3
For 2-3 years		253.6
For 4-5 years		99.1
After 5 years		168.4
Total Contractual Commitments		828.4
Appalachian Power Co [Member] \| Fuel Purchase Contracts [Member]
Contractual Commitments
Less than 1 year	[2],[4]	266.9
For 2-3 years	[2],[4]	171.8
For 4-5 years	[2],[4]	18.7
After 5 years	[2],[4]	18.4
Total Contractual Commitments	[2],[4]	475.8
Appalachian Power Co [Member] \| Fuel Purchase Contracts [Member] \| Subsequent Event [Member]
Contractual Commitments
Less than 1 year		95
For 2-3 years		449
For 4-5 years		96
Appalachian Power Co [Member] \| Energy and Capacity Purchase Contracts [Member]
Contractual Commitments
Less than 1 year		40.4
For 2-3 years		81.8
For 4-5 years		80.4
After 5 years		150
Total Contractual Commitments		352.6
Indiana Michigan Power Co [Member]
Contractual Commitments
Less than 1 year		314.9
For 2-3 years		458.3
For 4-5 years		352.4
After 5 years		589.2
Total Contractual Commitments		1,714.8
Commitments, Guarantees and Contingencies (Textuals)
Disposal, Assessed Fees and Related Interest	[1]	281.3	281.2
Rockport Plant, Unit 2 Acquisition Price		116
Indiana Michigan Power Co [Member] \| Fuel Purchase Contracts [Member]
Contractual Commitments
Less than 1 year	[4]	147.7
For 2-3 years	[4]	245.7
For 4-5 years	[4]	149.1
After 5 years	[4]	283.3
Total Contractual Commitments	[4]	825.8
Indiana Michigan Power Co [Member] \| Energy and Capacity Purchase Contracts [Member]
Contractual Commitments
Less than 1 year		167.2
For 2-3 years		212.6
For 4-5 years		203.3
After 5 years		305.9
Total Contractual Commitments		889
Ohio Power Co [Member] \| Energy and Capacity Purchase Contracts [Member]
Contractual Commitments
Less than 1 year		34.6
For 2-3 years		69.1
For 4-5 years		65.4
After 5 years		180
Total Contractual Commitments		349.1
Public Service Co Of Oklahoma [Member]
Contractual Commitments
Less than 1 year		80.4
For 2-3 years		90.3
For 4-5 years		67.9
After 5 years		125.9
Total Contractual Commitments		364.5
Public Service Co Of Oklahoma [Member] \| Fuel Purchase Contracts [Member]
Contractual Commitments
Less than 1 year	[4]	48.2
For 2-3 years	[4]	23
For 4-5 years	[4]	0
After 5 years	[4]	0
Total Contractual Commitments	[4]	71.2
Public Service Co Of Oklahoma [Member] \| Energy and Capacity Purchase Contracts [Member]
Contractual Commitments
Less than 1 year		32.2
For 2-3 years		67.3
For 4-5 years		67.9
After 5 years		125.9
Total Contractual Commitments		293.3
Southwestern Electric Power Co [Member]
Contractual Commitments
Less than 1 year		163
For 2-3 years		99.7
For 4-5 years		8.4
After 5 years		0
Total Contractual Commitments		271.1
Southwestern Electric Power Co [Member] \| Fuel Purchase Contracts [Member]
Contractual Commitments
Less than 1 year	[4]	158.8
For 2-3 years	[4]	91.3
For 4-5 years	[4]	0
After 5 years	[4]	0
Total Contractual Commitments	[4]	250.1
Southwestern Electric Power Co [Member] \| Energy and Capacity Purchase Contracts [Member]
Contractual Commitments
Less than 1 year		4.2
For 2-3 years		8.4
For 4-5 years		8.4
After 5 years		0
Total Contractual Commitments		21
Kentucky Power Co [Member] \| Fuel Purchase Contracts [Member]
Contractual Commitments
Less than 1 year		22
Decommissioning and Low Level Waste Accumulation Disposal [Member]
Commitments, Guarantees and Contingencies (Textuals)
Cost of Decommissioning and Disposal of Radioactive Waste		2,200
Additional Ongoing Costs for Post Decommissioning Storage of SNF		7
Subsequent Decommissioning of the Spent Fuel Storage Facility		33
Amount Recovered in Rates for Decommissioning Costs		4	4	$ 7
Decommissioning Trust Assets Amount		3,500	3,000
Decommissioning and Low Level Waste Accumulation Disposal [Member] \| Indiana Michigan Power Co [Member]
Commitments, Guarantees and Contingencies (Textuals)
Cost of Decommissioning and Disposal of Radioactive Waste		2,200
Additional Ongoing Costs for Post Decommissioning Storage of SNF		7
Subsequent Decommissioning of the Spent Fuel Storage Facility		33
Amount Recovered in Rates for Decommissioning Costs		4	4	7
Decommissioning Trust Assets Amount		3,500	3,000
Spent Nuclear Fuel Disposal [Member]
Commitments, Guarantees and Contingencies (Textuals)
DOE SNF Disposal Fee		0
Disposal, Assessed Fees and Related Interest		281	281
Trust Fund Assets One Time Fee Obligation for Nuclear Fuel Disposition		329	324
Recovery of Spent Nuclear Fuel Storage Costs		14	24	8
Current Amount Recoverable from the Federal Government		3	14
Noncurrent Amount Recoverable from the Federal Government		21	1
Spent Nuclear Fuel Disposal [Member] \| Indiana Michigan Power Co [Member]
Commitments, Guarantees and Contingencies (Textuals)
DOE SNF Disposal Fee		0
Disposal, Assessed Fees and Related Interest		281	281
Trust Fund Assets One Time Fee Obligation for Nuclear Fuel Disposition		329	324
Recovery of Spent Nuclear Fuel Storage Costs		14	24	$ 8
Current Amount Recoverable from the Federal Government		3	14
Noncurrent Amount Recoverable from the Federal Government		21	$ 1
Nuclear Incident Liability [Member]
Commitments, Guarantees and Contingencies (Textuals)
Insurance Coverage for Property Damage, Decommissioning and Decontamination		2,700
Coverage for Property Damage, Decommissioning and Decontamination for a Nonnuclear Incident		500
Contingent Financial Obligation for Mutual Insurance		42
Insurance Protection for Public Liability Arising from a Nuclear Incident		13,500
Commercially Available Insurance		450
Assessed Amount per Nuclear Incident		275
Deferred Premium Assessment Annual Payment		41
Commercially Available Insurance for Catastrophic Nature		450
Liability Coverage Under the Price-Anderson Act		13,100
Nuclear Incident Liability [Member] \| Indiana Michigan Power Co [Member]
Commitments, Guarantees and Contingencies (Textuals)
Insurance Coverage for Property Damage, Decommissioning and Decontamination		2,700
Coverage for Property Damage, Decommissioning and Decontamination for a Nonnuclear Incident		500
Contingent Financial Obligation for Mutual Insurance		42
Insurance Protection for Public Liability Arising from a Nuclear Incident		13,500
Commercially Available Insurance		450
Assessed Amount per Nuclear Incident		275
Deferred Premium Assessment Annual Payment		41
Commercially Available Insurance for Catastrophic Nature		450
Liability Coverage Under the Price-Anderson Act		13,100
March 2026 [Member] \| Letters of Credit [Member]
Commitments, Guarantees and Contingencies (Textuals)
Revolving Credit Facilities		4,000
March 2023 [Member] \| Letters of Credit [Member]
Commitments, Guarantees and Contingencies (Textuals)
Revolving Credit Facilities		$ 1,000

[1]	Spent Nuclear Fuel Obligation consists of a liability along with accrued interest for disposal of SNF. See “Spent Nuclear Fuel Disposal” section of Note 6 for additional information.
[2]	In the first quarter of 2022, APCo entered into new fuel purchase contracts related to coal procurement. The new commitments were as follows: $95 million in less than 1 year, $449 million in 2-3 years and $96 million in 4-5 years. These commitments are not included in the tables above. All other new commitments in the first quarter of 2022 were immaterial.
[3]	Includes $22 million of purchase fuel contracts for KPCo commitments that are expected to occur prior to the anticipated closing of the sale transaction in the second quarter of 2022. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[4]	Represents contractual commitments to purchase coal, natural gas, uranium and other consumables as fuel for electric generation along with related transportation of the fuel.

Acquisitions, Assets and Liab_3

Acquisitions, Assets and Liabilities Held for Sale, Dispositions and Impairments (Details)		3 Months Ended		12 Months Ended
		Jun. 30, 2020USD ($)	Jun. 30, 2019MW	Dec. 31, 2021USD ($)RateMWGW		Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)MW
Disposal Group, Including Discontinued Operation, Income Statement Disclosures
Asset Impairments and Other Related Charges				$ 11,600,000		$ 0	$ 156,400,000
Asset Impairment Charges
Utilities Operating Expense, Operations				2,547,700,000		2,572,400,000	2,743,700,000
Additional Paid in Capital				7,172,600,000		6,588,900,000
Asset Retirement Obligation, Liabilities Settled	[2],[3],[4],[5]			41,400,000	[1]	188,000,000
Property, Plant and Equipment, Generation				23,088,100,000		23,133,900,000
Obligations Under Operating Leases				492,800,000		638,400,000
Customers				720,900,000		613,600,000
Materials and Supplies				681,300,000		680,600,000
Total Property, Plant and Equipment, Net				66,001,300,000	[6]	63,901,600,000
Noncurrent Regulatory Assets				4,142,300,000	[7]	3,527,000,000
Assets Held for Sale				2,919,700,000		0
Accounts Payable, Current				2,054,600,000		1,709,700,000
Long-term Debt, Current Maturities				2,153,800,000		2,086,100,000	1,598,700,000
Customer Deposits, Current				321,600,000		335,600,000
Deferred Tax Liabilities, Net, Noncurrent				8,202,500,000		8,240,900,000
Regulatory Liabilities and Deferred Investment Tax Credits				8,686,300,000	[8]	8,378,700,000
Long-term Debt, Excluding Current Maturities				31,300,700,000		28,986,400,000	25,126,800,000
Liabilities Held for Sale				1,880,900,000		0
Property, Plant and Equipment, Other				5,682,900,000		5,294,600,000
North Central Wind Energy Facilities
Asset Impairment Charges
Payments to Acquire Property, Plant, and Equipment				(652,800,000)		0	0
Dry Lake Solar Project [Member]
Asset Impairment Charges
Payments to Acquire Property, Plant, and Equipment				(114,400,000)		0	0
Vertically Integrated Utilities [Member]
Disposal Group, Including Discontinued Operation, Income Statement Disclosures
Asset Impairments and Other Related Charges				11,600,000			92,900,000
Asset Impairment Charges
Proceeds from Divestiture of Businesses				1,450,000,000
Total Property, Plant and Equipment, Net				32,897,300,000		33,437,100,000
Long-term Debt, Current Maturities				1,022,400,000		1,034,600,000	704,700,000
Long-term Debt, Excluding Current Maturities				12,964,400,000		12,375,600,000	12,162,000,000
Enterprise Value				$ 2,850,000,000
Vertically Integrated Utilities [Member] \| Sundance [Member]
WindGenerationMWs \| MW				199
Vertically Integrated Utilities [Member] \| Maverick [Member]
WindGenerationMWs \| MW				287
Vertically Integrated Utilities [Member] \| Traverse [Member]
WindGenerationMWs \| MW				998
Vertically Integrated Utilities [Member] \| Kentucky Power Company and Kentucky Transmission Company
Asset Impairment Charges
Customers				$ 33,200,000
Materials and Supplies				30,600,000
Total Property, Plant and Equipment, Net				2,302,700,000
Noncurrent Regulatory Assets				484,700,000
Disposal Group, Including Discontinued Operation, Other Assets				68,500,000
Assets Held for Sale				2,919,700,000
Accounts Payable, Current				53,400,000
Long-term Debt, Current Maturities				200,000,000
Customer Deposits, Current				32,400,000
Deferred Tax Liabilities, Net, Noncurrent				441,600,000
Regulatory Liabilities and Deferred Investment Tax Credits				148,100,000
Disposal Group, Including Discontinued Operation, Other Liabilities, Current				102,300,000
Long-term Debt, Excluding Current Maturities				903,100,000
Liabilities Held for Sale				1,880,900,000
Vertically Integrated Utilities [Member] \| North Central Wind Energy Facilities \| Sundance [Member]
Asset Impairment Charges
Payments to Acquire Property, Plant, and Equipment				270,000,000
Vertically Integrated Utilities [Member] \| North Central Wind Energy Facilities \| Maverick [Member]
Asset Impairment Charges
Payments to Acquire Property, Plant, and Equipment				383,000,000
Generation and Marketing [Member]
Disposal Group, Including Discontinued Operation, Income Statement Disclosures
Asset Impairments and Other Related Charges				0			31,000,000
Asset Impairment Charges
Total Property, Plant and Equipment, Net				1,864,400,000		1,744,100,000
Long-term Debt, Current Maturities				0		0	0
Long-term Debt, Excluding Current Maturities				$ 0		0	0
Utility Plant Generation Resources \| GW				1.6
Generation and Marketing [Member] \| Dry Lake Solar Project [Member]
Asset Impairment Charges
Payments to Acquire Property, Plant, and Equipment				$ 114,000,000
Generation and Marketing [Member] \| Dry Lake Solar Project [Member] \| Payment When Put in Service
Asset Impairment Charges
Payments to Acquire Property, Plant, and Equipment				11,000,000
Generation and Marketing [Member] \| Dry Lake Solar Project [Member] \| Payment at Closing
Asset Impairment Charges
Payments to Acquire Property, Plant, and Equipment				103,000,000
Transmission and Distribution Companies [Member]
Disposal Group, Including Discontinued Operation, Income Statement Disclosures
Asset Impairments and Other Related Charges				0			32,500,000
Asset Impairment Charges
Total Property, Plant and Equipment, Net				18,598,300,000		17,265,700,000
Long-term Debt, Current Maturities				716,100,000		588,800,000	392,200,000
Long-term Debt, Excluding Current Maturities				7,433,200,000		6,661,900,000	6,248,100,000
AEP Transmission Holdco
Disposal Group, Including Discontinued Operation, Income Statement Disclosures
Asset Impairments and Other Related Charges				0			0
Asset Impairment Charges
Total Property, Plant and Equipment, Net				12,411,200,000		11,231,500,000
Long-term Debt, Current Maturities				106,400,000		52,300,000	0
Long-term Debt, Excluding Current Maturities				4,442,700,000		4,075,700,000	3,593,800,000
Enterprise Value				2,850,000,000
AEP Transmission Holdco \| Kentucky Transmission Company
Asset Impairment Charges
Customers				1,500,000
Materials and Supplies				0
Total Property, Plant and Equipment, Net				165,300,000
Noncurrent Regulatory Assets				0
Disposal Group, Including Discontinued Operation, Other Assets				1,100,000
Assets Held for Sale				167,900,000
Accounts Payable, Current				1,100,000
Long-term Debt, Current Maturities				0
Customer Deposits, Current				0
Deferred Tax Liabilities, Net, Noncurrent				15,400,000
Regulatory Liabilities and Deferred Investment Tax Credits				7,600,000
Disposal Group, Including Discontinued Operation, Other Liabilities, Current				3,500,000
Long-term Debt, Excluding Current Maturities				0
Liabilities Held for Sale				$ 27,600,000
AEP Texas Inc. [Member]
Jointly Owned Utility Plant, Proportionate Ownership Share				54.69%
Disposal Group, Including Discontinued Operation, Income Statement Disclosures
Asset Impairments and Other Related Charges				$ 0		0	32,500,000
Asset Impairment Charges
Utilities Operating Expense, Operations				489,500,000		488,900,000	492,000,000
Additional Paid in Capital				1,553,900,000		1,457,900,000
Asset Retirement Obligation, Liabilities Settled	[3],[4]			400,000		8,500,000
Obligations Under Operating Leases				61,300,000		71,000,000
Customers				123,400,000		112,800,000
Materials and Supplies				73,900,000		70,000,000
Total Property, Plant and Equipment, Net				10,635,400,000		9,813,600,000
Noncurrent Regulatory Assets				275,200,000		266,800,000
Accounts Payable, Current				306,300,000		231,700,000
Long-term Debt, Current Maturities				716,000,000		88,700,000
Deferred Tax Liabilities, Net, Noncurrent				1,088,900,000		1,016,700,000
Regulatory Liabilities and Deferred Investment Tax Credits				1,242,000,000		1,270,800,000
Long-term Debt, Excluding Current Maturities				4,464,800,000		4,731,700,000
Property, Plant and Equipment, Other				961,100,000		868,400,000
AEP Transmission Co [Member]
Asset Impairment Charges
Utilities Operating Expense, Operations				105,500,000		99,800,000	93,900,000
Payments to Acquire Property, Plant, and Equipment				17,900,000		6,000,000	9,400,000
Obligations Under Operating Leases				1,300,000		400,000
Customers				22,500,000		22,900,000
Materials and Supplies				9,300,000		8,500,000
Total Property, Plant and Equipment, Net				11,935,700,000	[6]	10,772,800,000
Noncurrent Regulatory Assets				8,500,000		15,100,000
Assets Held for Sale				167,900,000		0
Accounts Payable, Current				460,100,000		380,400,000
Long-term Debt, Current Maturities				104,000,000		50,000,000
Deferred Tax Liabilities, Net, Noncurrent				962,900,000		906,900,000
Regulatory Liabilities and Deferred Investment Tax Credits				644,100,000	[9]	581,800,000
Long-term Debt, Excluding Current Maturities				4,239,900,000		3,898,500,000
Liabilities Held for Sale				27,600,000		0
Property, Plant and Equipment, Other				427,400,000		329,500,000
AEP Transmission Co [Member] \| AEP Transmission Holdco
Asset Impairment Charges
Proceeds from Divestiture of Businesses				1,450,000,000
Appalachian Power Co [Member]
Disposal Group, Including Discontinued Operation, Income Statement Disclosures
Asset Impairments and Other Related Charges				0		0	92,900,000
Asset Impairment Charges
Utilities Operating Expense, Operations				610,000,000		530,500,000	567,600,000
Additional Paid in Capital				1,828,700,000		1,828,700,000
Asset Retirement Obligation, Liabilities Settled	[3],[4]			6,900,000		7,800,000
Property, Plant and Equipment, Generation				6,683,900,000		6,633,700,000
Obligations Under Operating Leases				52,400,000		64,400,000
Customers				158,500,000		142,800,000
Materials and Supplies				109,800,000		99,600,000
Total Property, Plant and Equipment, Net				11,804,300,000		11,394,100,000
Noncurrent Regulatory Assets				757,600,000		686,300,000
Accounts Payable, Current				262,200,000		212,000,000
Long-term Debt, Current Maturities				480,700,000		518,300,000
Customer Deposits, Current				73,900,000		77,800,000
Deferred Tax Liabilities, Net, Noncurrent				1,804,700,000		1,749,900,000
Regulatory Liabilities and Deferred Investment Tax Credits				1,238,800,000		1,224,700,000
Long-term Debt, Excluding Current Maturities				4,458,200,000		4,315,800,000
Property, Plant and Equipment, Other				696,600,000		627,200,000
Indiana Michigan Power Co [Member]
Cost of Purchased Power from Affiliate				217,900,000		172,800,000	214,900,000
Asset Impairment Charges
Utilities Operating Expense, Operations				645,200,000		650,000,000	641,200,000
Additional Paid in Capital				980,900,000		980,900,000
Asset Retirement Obligation, Liabilities Settled	[3],[4],[5]			100,000		200,000
Property, Plant and Equipment, Generation				5,531,800,000		5,264,700,000
Obligations Under Operating Leases				48,900,000		135,900,000
Customers				40,600,000		44,000,000
Materials and Supplies				175,200,000		175,800,000
Total Property, Plant and Equipment, Net				7,310,900,000		7,052,300,000
Noncurrent Regulatory Assets				410,900,000		404,800,000
Accounts Payable, Current				174,400,000		153,200,000
Long-term Debt, Current Maturities				67,000,000		369,600,000
Customer Deposits, Current				45,200,000		41,700,000
Deferred Tax Liabilities, Net, Noncurrent				1,100,200,000		1,064,400,000
Regulatory Liabilities and Deferred Investment Tax Credits				2,447,900,000		2,041,900,000
Long-term Debt, Excluding Current Maturities				3,128,000,000		2,660,300,000
Property, Plant and Equipment, Other				792,900,000		686,700,000
Ohio Power Co [Member]
Cost of Purchased Power from Affiliate				51,900,000		119,700,000	156,000,000
Asset Impairment Charges
Utilities Operating Expense, Operations				836,800,000		822,600,000	742,600,000
Additional Paid in Capital				838,800,000		838,800,000
Asset Retirement Obligation, Liabilities Settled	[3]			100,000		0
Obligations Under Operating Leases				68,600,000		79,500,000
Customers				71,600,000		50,000,000
Materials and Supplies				74,100,000		66,900,000
Total Property, Plant and Equipment, Net				7,963,000,000		7,452,100,000
Noncurrent Regulatory Assets				293,000,000		385,800,000
Accounts Payable, Current				213,500,000		181,000,000
Long-term Debt, Current Maturities				100,000		500,100,000
Customer Deposits, Current				66,400,000		55,100,000
Deferred Tax Liabilities, Net, Noncurrent				1,000,900,000		955,100,000
Regulatory Liabilities and Deferred Investment Tax Credits				1,020,900,000		1,005,200,000
Long-term Debt, Excluding Current Maturities				2,968,400,000		1,930,100,000
Property, Plant and Equipment, Other				$ 992,900,000		899,600,000
Public Service Co Of Oklahoma [Member]
Percentage of an Asset Acquired				45.50%
Asset Impairment Charges
Utilities Operating Expense, Operations				$ 353,800,000		327,300,000	315,000,000
Additional Paid in Capital				1,039,000,000		414,000,000
Asset Retirement Obligation, Liabilities Settled	[3],[4]			700,000		3,100,000
Payments to Acquire Property, Plant, and Equipment				(297,000,000)		0	0
Property, Plant and Equipment, Generation				1,802,400,000		1,480,700,000
Obligations Under Operating Leases				62,200,000		36,200,000
Customers				41,500,000		30,800,000
Materials and Supplies				56,200,000		54,000,000
Total Property, Plant and Equipment, Net				4,802,800,000		4,320,000,000
Noncurrent Regulatory Assets				1,037,400,000		375,000,000
Accounts Payable, Current				157,400,000		107,000,000
Long-term Debt, Current Maturities				125,500,000		500,000
Customer Deposits, Current				56,200,000		54,800,000
Deferred Tax Liabilities, Net, Noncurrent				782,300,000		688,500,000
Regulatory Liabilities and Deferred Investment Tax Credits				835,300,000		802,200,000
Long-term Debt, Excluding Current Maturities				1,788,000,000		1,373,300,000
Property, Plant and Equipment, Other				437,000,000		393,300,000
Public Service Co Of Oklahoma [Member] \| Vertically Integrated Utilities [Member] \| Sundance [Member]
Asset Impairment Charges
Obligations Under Operating Leases				13,000,000
Public Service Co Of Oklahoma [Member] \| Vertically Integrated Utilities [Member] \| Maverick [Member]
Asset Impairment Charges
Obligations Under Operating Leases				$ 18,000,000
Southwestern Electric Power Co [Member]
Percentage of an Asset Acquired				54.50%
Disposal Group, Including Discontinued Operation, Income Statement Disclosures
Asset Impairments and Other Related Charges				$ 11,600,000		0	0
Asset Impairment Charges
Utilities Operating Expense, Operations				360,300,000		338,300,000	348,000,000
Additional Paid in Capital				1,092,200,000		812,200,000
Asset Retirement Obligation, Liabilities Settled	[2],[3],[4]			20,900,000		10,900,000
Payments to Acquire Property, Plant, and Equipment				(355,800,000)		0	0
Property, Plant and Equipment, Generation				4,734,500,000		4,681,400,000
Obligations Under Operating Leases				77,700,000		44,100,000
Customers				35,800,000		27,100,000
Materials and Supplies				81,900,000		95,800,000
Total Property, Plant and Equipment, Net				7,400,100,000		7,088,200,000
Noncurrent Regulatory Assets				1,005,300,000		403,100,000
Accounts Payable, Current				163,600,000		135,900,000
Long-term Debt, Current Maturities				6,200,000		106,200,000
Customer Deposits, Current				62,400,000		61,300,000
Deferred Tax Liabilities, Net, Noncurrent				1,087,600,000		1,017,600,000
Regulatory Liabilities and Deferred Investment Tax Credits				806,900,000		863,400,000
Long-term Debt, Excluding Current Maturities				3,389,000,000		2,530,200,000
Property, Plant and Equipment, Other				764,000,000		788,800,000
Southwestern Electric Power Co [Member] \| Vertically Integrated Utilities [Member] \| Sundance [Member]
Asset Impairment Charges
Obligations Under Operating Leases				15,000,000
Southwestern Electric Power Co [Member] \| Vertically Integrated Utilities [Member] \| Maverick [Member]
Asset Impairment Charges
Obligations Under Operating Leases				22,000,000
Conesville Generating Station (Unit No. 4) [Member] \| Generation and Marketing [Member]
Asset Impairment Charges
Fair Value of Impaired Assets							0
Utilities Operating Expense, Operations							31,000,000
Payments for (Proceeds from) Removal Costs		$ 26,000,000				98,000,000
Asset Retirement Obligation, Liabilities Settled						106,000,000
Payments for Removal Costs				$ 15,000,000		57,000,000
Trent and Desert Sky Wind Farms [Member] \| Generation and Marketing [Member]
Asset Impairment Charges
Payments to Acquire Businesses, Gross						57,000,000
Redeemable Noncontrolling Interest						63,000,000
Additional Paid in Capital						6,000,000
Mitchell Power Plant
Asset Impairment Charges
Approximate OVEC Generating Capacity (MWs) \| MW				1,560
Mitchell Power Plant \| Kentucky Power Co [Member]
Asset Impairment Charges
Ownership Interest in Mitchell Power Plant				50.00%
Mitchell Power Plant \| Wheeling Power Company
Asset Impairment Charges
Ownership Interest in Mitchell Power Plant				50.00%
AEP Wind Holdings LLC [Member]
Noncash or Part Noncash Acquisition, Other Assets Acquired							134,800,000
WindGenerationMWs \| MW			724
AEP Wind Holdings LLC [Member] \| Noncontrolling Interests [Member]
Noncash or Part Noncash Acquisition, Other Assets Acquired							134,800,000
AEP Wind Holdings LLC [Member] \| Generation and Marketing [Member]
Percentage of an Asset Acquired \| Rate				50.00%
WindGenerationMWs \| MW				724
Noncash or Part Noncash Acquisition, Value of Assets Acquired							1,100,000,000
Asset Impairment Charges
Payments to Acquire Businesses, Gross							580,400,000
Maximum Potential Amount of Future Payments Associated with Guarantee				$ 142,000,000
Guarantor Obligations, Current Carrying Value				28,000,000
Guarantor Obligations, Current Carrying Value, Contingent Portion				2,000,000
AEP Wind Holdings LLC [Member] \| Generation and Marketing [Member] \| Noncontrolling Interests [Member]
Noncash or Part Noncash Acquisition, Other Assets Acquired							135,000,000
AEP Wind Holdings LLC [Member] \| Indiana Michigan Power Co [Member] \| Generation and Marketing [Member]
Cost of Purchased Power from Affiliate				10,000,000		11,000,000	9,000,000
AEP Wind Holdings LLC [Member] \| Ohio Power Co [Member] \| Generation and Marketing [Member]
Cost of Purchased Power from Affiliate				20,000,000		23,000,000	17,000,000
AEP Wind Holdings LLC [Member] \| Southwestern Electric Power Co [Member] \| Generation and Marketing [Member]
Cost of Purchased Power from Affiliate				$ 14,000,000		14,000,000	10,000,000
Santa Rita East [Member]
Noncash or Part Noncash Acquisition, Other Assets Acquired						(43,700,000)	118,800,000
Percentage of an Asset Acquired				85.00%
Santa Rita East [Member] \| Noncontrolling Interests [Member]
Noncash or Part Noncash Acquisition, Other Assets Acquired						(43,700,000)	$ 118,800,000
Santa Rita East [Member] \| Generation and Marketing [Member]
Noncash Contribution of Assets by Noncontrolling Interest						$ 44,000,000
Percentage of an Asset Acquired				85.00%		10.00%	75.00%
WindGenerationMWs \| MW				302			227
Asset Impairment Charges
Payments to Acquire Businesses, Gross						$ 44,000,000	$ 356,000,000
Dry Lake Solar Project [Member]
Noncash or Part Noncash Acquisition, Other Assets Acquired				$ 18,900,000
Percentage of an Asset Acquired				75.00%
Dry Lake Solar Project [Member] \| Noncontrolling Interests [Member]
Noncash or Part Noncash Acquisition, Other Assets Acquired				$ 18,900,000
Dry Lake Solar Project [Member] \| Generation and Marketing [Member]
Asset Impairment Charges
Solar Generation MWs \| MW				100
North Central Wind Energy Facilities
Asset Impairment Charges
Payments to Acquire Property, Plant, and Equipment				$ 2,000,000,000
North Central Wind Energy Facilities \| Vertically Integrated Utilities [Member]
WindGenerationMWs \| MW				1,484
North Central Wind Energy Facilities \| Public Service Co Of Oklahoma [Member] \| Vertically Integrated Utilities [Member]
Asset Impairment Charges
Property, Plant and Equipment, Generation				$ 316,000,000
North Central Wind Energy Facilities \| Southwestern Electric Power Co [Member] \| Vertically Integrated Utilities [Member]
Asset Impairment Charges
Property, Plant and Equipment, Generation				378,000,000
Sempra Renewable LLC and Santa Rita \| Generation and Marketing [Member]
Asset Impairment Charges
Noncash or Part Noncash Acquisition, Debt Assumed							364,000,000
Property, Plant and Equipment, Other							404,000,000
Current Liabilities [Member] \| AEP Wind Holdings LLC [Member] \| Generation and Marketing [Member]
Noncash or Part Noncash Acquisition, Value of Liabilities Assumed							12,900,000
Current Assets [Member] \| AEP Wind Holdings LLC [Member] \| Generation and Marketing [Member]
Noncash or Part Noncash Acquisition, Other Assets Acquired							8,800,000
Property, Plant and Equipment [Member] \| AEP Wind Holdings LLC [Member] \| Generation and Marketing [Member]
Noncash or Part Noncash Acquisition, Other Assets Acquired							238,100,000
Asset Retirement Obligation [Member] \| AEP Wind Holdings LLC [Member] \| Generation and Marketing [Member]
Noncash or Part Noncash Acquisition, Value of Liabilities Assumed							5,700,000
Equity Method Investments [Member] \| AEP Wind Holdings LLC [Member] \| Generation and Marketing [Member]
Noncash or Part Noncash Acquisition, Other Assets Acquired							404,000,000
Liabilities, Total [Member] \| AEP Wind Holdings LLC [Member] \| Generation and Marketing [Member]
Noncash or Part Noncash Acquisition, Value of Liabilities Assumed							18,600,000
Other Noncurrent Assets [Member] \| AEP Wind Holdings LLC [Member] \| Generation and Marketing [Member]
Noncash or Part Noncash Acquisition, Other Assets Acquired							82,900,000
Noncontrolling Interests [Member] \| Dry Lake Solar Project [Member]
Noncash Contribution of Assets by Noncontrolling Interest				$ 35,300,000		$ 0	0
Noncontrolling Interests [Member] \| AEP Wind Holdings LLC [Member] \| Generation and Marketing [Member]
Noncash Contribution of Assets by Noncontrolling Interest							134,800,000
Total Assets [Member] \| AEP Wind Holdings LLC [Member] \| Generation and Marketing [Member]
Noncash or Part Noncash Acquisition, Other Assets Acquired							733,800,000
Total Liabilities And Equity [Member] \| AEP Wind Holdings LLC [Member] \| Generation and Marketing [Member]
Noncash or Part Noncash Acquisition, Value of Liabilities Assumed							153,400,000
2019 Texas Base Rate Case [Member] \| AEP Texas Inc. [Member] \| Transmission and Distribution Companies [Member]
Disposal Group, Including Discontinued Operation, Income Statement Disclosures
Asset Impairments and Other Related Charges							33,000,000
2017-2019 Virginia Triennial Review [Member] \| Appalachian Power Co [Member] \| Vertically Integrated Utilities [Member] \| Plant Retirement Costs - Unrecovered Plant [Member]
Disposal Group, Including Discontinued Operation, Income Statement Disclosures
Asset Impairments and Other Related Charges							$ 93,000,000

[1]	Includes $18 million of ARO classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[2]	Includes ARO related to Sabine and DHLC.
[3]	Includes ARO related to asbestos removal.
[4]	Includes ARO related to ash disposal facilities.
[5]	Includes ARO related to nuclear decommissioning costs for the Cook Plant of $1.93 billion and $1.80 billion as of December 31, 2021 and 2020, respectively.
[6]	Amount excludes $2.3 billion and $165 million for AEP and AEPTCo, respectively, of Property, Plant and Equipment - Net classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[7]	2021 amounts exclude $485 million of regulatory assets classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[8]	2021 amounts exclude $148 million of regulatory liabilities classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[9]	2021 amounts exclude $8 million of regulatory liabilities classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.

Benefit Plans 1 (Details)

Benefit Plans 1 (Details) - USD ($) $ in Millions		12 Months Ended
Benefit Plans 1 (Details) - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Benefit Amounts Recognized on the Balance Sheets
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		$ 4,398.3	$ 3,852.3
Deferred Credits and Other Noncurrent Liabilities - Accrued Long-term Benefit Liability		(601.3)	(728)
AEP Texas Inc. [Member]
Benefit Amounts Recognized on the Balance Sheets
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		211.3	192.1
Deferred Credits and Other Noncurrent Liabilities - Accrued Long-term Benefit Liability		(73.8)	(57.2)
Appalachian Power Co [Member]
Benefit Amounts Recognized on the Balance Sheets
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		129.2	121.7
Deferred Credits and Other Noncurrent Liabilities - Accrued Long-term Benefit Liability		(34.6)	(49.6)
Indiana Michigan Power Co [Member]
Benefit Amounts Recognized on the Balance Sheets
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		316.5	237.6
Deferred Credits and Other Noncurrent Liabilities - Accrued Long-term Benefit Liability		(58.3)	(69.2)
Ohio Power Co [Member]
Benefit Amounts Recognized on the Balance Sheets
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		601.1	524.2
Deferred Credits and Other Noncurrent Liabilities - Accrued Long-term Benefit Liability		(29.2)	(40)
Public Service Co Of Oklahoma [Member]
Benefit Amounts Recognized on the Balance Sheets
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		7.9	6
Deferred Credits and Other Noncurrent Liabilities - Accrued Long-term Benefit Liability		(19.4)	(20.6)
Southwestern Electric Power Co [Member]
Benefit Amounts Recognized on the Balance Sheets
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		251.8	234.8
Deferred Credits and Other Noncurrent Liabilities - Accrued Long-term Benefit Liability		$ (63)	$ (95.2)
Pension Plans [Member]
Actuarial Assumptions for Benefit Obligations
Discount Rate		2.90%	2.50%
Interest Crediting Rate		4.00%	4.00%
Rate of Compensation Increase	[1]	5.10%	5.00%
Actuarial Assumptions for Net Periodic Benefit Costs
Discount Rate		2.50%	3.25%	4.30%
Interest Crediting Rate		4.00%	4.00%	4.00%
Expected Return on Plan Assets		4.75%	5.75%	6.25%
Rate of Compensation Increase	[2]	5.10%	5.00%	4.95%
Change in Benefit Obligation
Benefit Obligation as of January 1		$ 5,544.5	$ 5,236.8
Service Cost		129.2	111.9	$ 95.5
Interest Cost		137.2	167.9	204.4
Actuarial (Gain) Loss		(173.9)	434.7
Plan Amendments		0	0
Benefit Payments		(450)	(406.8)
Participant Contributions		0	0
Medicare Subsidy		0	0
Benefit Obligation as of December 31		5,187	5,544.5	5,236.8
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1		5,556.6	5,015.4
Actual Gain (Loss) on Plan Assets		239.2	832.4
Company Contributions	[3]	7.1	115.6
Participant Contributions		0	0
Benefit Payments		(450)	(406.8)
Fair Value of Plan Assets as of December 31		5,352.9	5,556.6	$ 5,015.4
Funded (Underfunded) Status as of December 31		165.9	12.1
Benefit Amounts Recognized on the Balance Sheets
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		244.3	93.5
Other Current Liabilities - Accrued Short-term Benefit Liability		(7.6)	(6.7)
Employee Benefits and Pension Obligations - Accrued Long-term Benefit Liability		(70.8)	(74.7)
Funded (Underfunded) Status		165.9	12.1
Components
Net Actuarial Loss		894.7	1,179.6
Prior Service Cost (Credit)		0.2	0.2
Components of Change in Amounts Included in AOCI and Regulatory Assets
Actuarial (Gain) Loss During the Year		(183.4)	(132.9)
Amortization of Actuarial Gain (Loss)		(101.5)	(93.7)
Prior Service (Credit) Cost		0	0
Amortization of Prior Service Credit (Cost)		0	0
Change for the Year		$ (284.9)	$ (226.6)
Benefit Plans (Textuals) [Abstract]
Rate of Compensation Increase	[1]	5.10%	5.00%
Company Contributions	[3]	$ 7.1	$ 115.6
Pension Plans [Member] \| Regulatory Assets [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		878	1,182.4
Pension Plans [Member] \| Deferred Income Taxes [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		3.6	(0.5)
Pension Plans [Member] \| Net of Tax AOCI [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		$ 13.3	$ (2.1)
Pension Plans [Member] \| AEP Texas Inc. [Member]
Actuarial Assumptions for Benefit Obligations
Discount Rate		2.90%	2.50%
Interest Crediting Rate		4.00%	4.00%
Rate of Compensation Increase	[1]	5.10%	5.05%
Actuarial Assumptions for Net Periodic Benefit Costs
Discount Rate		2.50%	3.25%	4.30%
Interest Crediting Rate		4.00%	4.00%	4.00%
Expected Return on Plan Assets		4.75%	5.75%	6.25%
Rate of Compensation Increase	[2]	5.10%	5.05%	5.00%
Change in Benefit Obligation
Benefit Obligation as of January 1		$ 453.2	$ 441.2
Service Cost		11.8	10	$ 8.6
Interest Cost		11.2	13.9	17.5
Actuarial (Gain) Loss		(10.9)	28.1
Plan Amendments		0	0
Benefit Payments		(45.5)	(40)
Participant Contributions		0	0
Benefit Obligation as of December 31		419.8	453.2	441.2
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1		474	435.1
Actual Gain (Loss) on Plan Assets		16	67.2
Company Contributions		0.4	11.7
Participant Contributions		0	0
Benefit Payments		(45.5)	(40)
Fair Value of Plan Assets as of December 31		444.9	474	$ 435.1
Funded (Underfunded) Status as of December 31		25.1	20.8
Benefit Amounts Recognized on the Balance Sheets
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		28.7	24.7
Other Current Liabilities - Accrued Short-term Benefit Liability		(0.3)	(0.4)
Deferred Credits and Other Noncurrent Liabilities - Accrued Long-term Benefit Liability		(3.3)	(3.5)
Funded (Underfunded) Status		25.1	20.8
Components
Net Actuarial Loss		144.7	160.5
Prior Service Cost (Credit)		0	0
Components of Change in Amounts Included in AOCI and Regulatory Assets
Actuarial (Gain) Loss During the Year		(7.5)	(16.4)
Amortization of Actuarial Gain (Loss)		(8.3)	(7.8)
Prior Service (Credit) Cost		0	0
Amortization of Prior Service Credit (Cost)		0	0
Change for the Year		$ (15.8)	$ (24.2)
Benefit Plans (Textuals) [Abstract]
Rate of Compensation Increase	[1]	5.10%	5.05%
Company Contributions		$ 0.4	$ 11.7
Pension Plans [Member] \| AEP Texas Inc. [Member] \| Regulatory Assets [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		136.7	151.3
Pension Plans [Member] \| AEP Texas Inc. [Member] \| Deferred Income Taxes [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		1.8	2
Pension Plans [Member] \| AEP Texas Inc. [Member] \| Net of Tax AOCI [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		$ 6.2	$ 7.2
Pension Plans [Member] \| Appalachian Power Co [Member]
Actuarial Assumptions for Benefit Obligations
Discount Rate		2.90%	2.50%
Interest Crediting Rate		4.00%	4.00%
Rate of Compensation Increase	[1]	4.85%	4.85%
Actuarial Assumptions for Net Periodic Benefit Costs
Discount Rate		2.50%	3.25%	4.30%
Interest Crediting Rate		4.00%	4.00%	4.00%
Expected Return on Plan Assets		4.75%	5.75%	6.25%
Rate of Compensation Increase	[2]	4.85%	4.85%	4.75%
Change in Benefit Obligation
Benefit Obligation as of January 1		$ 670.8	$ 647.2
Service Cost		11.9	10.5	$ 9.4
Interest Cost		16.4	20.3	25.2
Actuarial (Gain) Loss		(28.5)	40
Plan Amendments		0	0
Benefit Payments		(48.9)	(47.2)
Participant Contributions		0	0
Medicare Subsidy		0	0
Benefit Obligation as of December 31		621.7	670.8	647.2
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1		701.3	637
Actual Gain (Loss) on Plan Assets		30.9	104.5
Company Contributions		0	7
Participant Contributions		0	0
Benefit Payments		(48.9)	(47.2)
Fair Value of Plan Assets as of December 31		683.3	701.3	$ 637
Funded (Underfunded) Status as of December 31		61.6	30.5
Benefit Amounts Recognized on the Balance Sheets
Employee Benefits and Pension Assets - Prepaid Benefit Costs		62.4	31
Other Current Liabilities - Accrued Short-term Benefit Liability		0	0
Employee Benefits and Pension Obligations - Accrued Long-term Benefit Liability		(0.8)	(0.5)
Funded (Underfunded) Status		61.6	30.5
Components
Net Actuarial Loss		83.9	126.3
Prior Service Cost (Credit)		0	0
Components of Change in Amounts Included in AOCI and Regulatory Assets
Actuarial (Gain) Loss During the Year		(30.4)	(30.8)
Amortization of Actuarial Gain (Loss)		(12)	(11.2)
Prior Service (Credit) Cost		0	0
Amortization of Prior Service Credit (Cost)		0	0
Change for the Year		$ (42.4)	$ (42)
Benefit Plans (Textuals) [Abstract]
Rate of Compensation Increase	[1]	4.85%	4.85%
Company Contributions		$ 0	$ 7
Pension Plans [Member] \| Appalachian Power Co [Member] \| Regulatory Assets [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		82.5	124.7
Pension Plans [Member] \| Appalachian Power Co [Member] \| Deferred Income Taxes [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		0.3	0.3
Pension Plans [Member] \| Appalachian Power Co [Member] \| Net of Tax AOCI [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		$ 1.1	$ 1.3
Pension Plans [Member] \| Indiana Michigan Power Co [Member]
Actuarial Assumptions for Benefit Obligations
Discount Rate		2.90%	2.50%
Interest Crediting Rate		4.00%	4.00%
Rate of Compensation Increase	[1]	5.00%	5.00%
Actuarial Assumptions for Net Periodic Benefit Costs
Discount Rate		2.50%	3.25%	4.30%
Interest Crediting Rate		4.00%	4.00%	4.00%
Expected Return on Plan Assets		4.75%	5.75%	6.25%
Rate of Compensation Increase	[2]	5.00%	5.00%	4.95%
Change in Benefit Obligation
Benefit Obligation as of January 1		$ 653.3	$ 616.1
Service Cost		17.5	15.4	$ 13.4
Interest Cost		16.2	19.7	23.8
Actuarial (Gain) Loss		(29.5)	44.3
Plan Amendments		0	0
Benefit Payments		(45.4)	(42.2)
Participant Contributions		0	0
Benefit Obligation as of December 31		612.1	653.3	616.1
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1		698.1	630.5
Actual Gain (Loss) on Plan Assets		28.8	103.3
Company Contributions		0	6.5
Participant Contributions		0	0
Benefit Payments		(45.4)	(42.2)
Fair Value of Plan Assets as of December 31		681.5	698.1	$ 630.5
Funded (Underfunded) Status as of December 31		69.4	44.8
Benefit Amounts Recognized on the Balance Sheets
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		71.4	46.5
Other Current Liabilities - Accrued Short-term Benefit Liability		(0.1)	0
Deferred Credits and Other Noncurrent Liabilities - Accrued Long-term Benefit Liability		(1.9)	(1.7)
Funded (Underfunded) Status		69.4	44.8
Components
Net Actuarial Loss		(1.6)	39.5
Prior Service Cost (Credit)		0	0
Components of Change in Amounts Included in AOCI and Regulatory Assets
Actuarial (Gain) Loss During the Year		(29.4)	(25.7)
Amortization of Actuarial Gain (Loss)		(11.7)	(10.8)
Prior Service (Credit) Cost		0	0
Amortization of Prior Service Credit (Cost)		0	0
Change for the Year		$ (41.1)	$ (36.5)
Benefit Plans (Textuals) [Abstract]
Rate of Compensation Increase	[1]	5.00%	5.00%
Company Contributions		$ 0	$ 6.5
Pension Plans [Member] \| Indiana Michigan Power Co [Member] \| Regulatory Assets [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets	[4]	3.1	40.3
Pension Plans [Member] \| Indiana Michigan Power Co [Member] \| Deferred Income Taxes [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		(1)	(0.1)
Pension Plans [Member] \| Indiana Michigan Power Co [Member] \| Net of Tax AOCI [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		$ (3.7)	$ (0.7)
Pension Plans [Member] \| Ohio Power Co [Member]
Actuarial Assumptions for Benefit Obligations
Discount Rate		2.90%	2.50%
Interest Crediting Rate		4.00%	4.00%
Rate of Compensation Increase	[1]	5.30%	5.25%
Actuarial Assumptions for Net Periodic Benefit Costs
Discount Rate		2.50%	3.25%	4.30%
Interest Crediting Rate		4.00%	4.00%	4.00%
Expected Return on Plan Assets		4.75%	5.75%	6.25%
Rate of Compensation Increase	[2]	5.30%	5.25%	5.20%
Change in Benefit Obligation
Benefit Obligation as of January 1		$ 510.3	$ 487.8
Service Cost		11.4	9.7	$ 7.9
Interest Cost		12.5	15.4	19.1
Actuarial (Gain) Loss		(24.1)	33.4
Plan Amendments		0	0
Benefit Payments		(39.4)	(36)
Participant Contributions		0	0
Benefit Obligation as of December 31		470.7	510.3	487.8
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1		543.1	499.1
Actual Gain (Loss) on Plan Assets		21.1	79.9
Company Contributions		0	0.1
Participant Contributions		0	0
Benefit Payments		(39.4)	(36)
Fair Value of Plan Assets as of December 31		524.8	543.1	$ 499.1
Funded (Underfunded) Status as of December 31		54.1	32.8
Benefit Amounts Recognized on the Balance Sheets
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		54.8	33.3
Deferred Credits and Other Noncurrent Liabilities - Accrued Long-term Benefit Liability		(0.7)	(0.5)
Funded (Underfunded) Status		54.1	32.8
Components
Net Actuarial Loss		118.1	150
Prior Service Cost (Credit)		0	0
Components of Change in Amounts Included in AOCI and Regulatory Assets
Actuarial (Gain) Loss During the Year		(22.8)	(20.2)
Amortization of Actuarial Gain (Loss)		(9.1)	(8.5)
Prior Service (Credit) Cost		0	0
Amortization of Prior Service Credit (Cost)		0	0
Change for the Year		$ (31.9)	$ (28.7)
Benefit Plans (Textuals) [Abstract]
Rate of Compensation Increase	[1]	5.30%	5.25%
Company Contributions		$ 0	$ 0.1
Pension Plans [Member] \| Ohio Power Co [Member] \| Regulatory Assets [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		$ 118.1	$ 150
Pension Plans [Member] \| Public Service Co Of Oklahoma [Member]
Actuarial Assumptions for Benefit Obligations
Discount Rate		2.90%	2.50%
Interest Crediting Rate		4.00%	4.00%
Rate of Compensation Increase	[1]	5.10%	5.05%
Actuarial Assumptions for Net Periodic Benefit Costs
Discount Rate		2.50%	3.25%	4.30%
Interest Crediting Rate		4.00%	4.00%	4.00%
Expected Return on Plan Assets		4.75%	5.75%	6.25%
Rate of Compensation Increase	[2]	5.10%	5.05%	5.05%
Change in Benefit Obligation
Benefit Obligation as of January 1		$ 279.9	$ 267.5
Service Cost		8	7.3	$ 6.5
Interest Cost		6.7	8.5	10.6
Actuarial (Gain) Loss		(17.2)	17.7
Plan Amendments		0	0
Benefit Payments		(24.8)	(21.1)
Participant Contributions		0	0
Benefit Obligation as of December 31		252.6	279.9	267.5
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1		299.8	276.2
Actual Gain (Loss) on Plan Assets		11.1	44.6
Company Contributions		0.1	0.1
Participant Contributions		0	0
Benefit Payments		(24.8)	(21.1)
Fair Value of Plan Assets as of December 31		286.2	299.8	$ 276.2
Funded (Underfunded) Status as of December 31		33.6	19.9
Benefit Amounts Recognized on the Balance Sheets
Employee Benefits and Pension Assets - Prepaid Benefit Costs		35.5	21.9
Other Current Liabilities - Accrued Short-term Benefit Liability		(0.1)	(0.1)
Deferred Credits and Other Noncurrent Liabilities - Accrued Long-term Benefit Liability		(1.8)	(1.9)
Funded (Underfunded) Status		33.6	19.9
Components
Net Actuarial Loss		35	55.9
Prior Service Cost (Credit)		0	0
Components of Change in Amounts Included in AOCI and Regulatory Assets
Actuarial (Gain) Loss During the Year		(16)	(12.4)
Amortization of Actuarial Gain (Loss)		(4.9)	(4.7)
Prior Service (Credit) Cost		0	0
Amortization of Prior Service Credit (Cost)		0	0
Change for the Year		$ (20.9)	$ (17.1)
Benefit Plans (Textuals) [Abstract]
Rate of Compensation Increase	[1]	5.10%	5.05%
Company Contributions		$ 0.1	$ 0.1
Pension Plans [Member] \| Public Service Co Of Oklahoma [Member] \| Regulatory Assets [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		$ 35	$ 55.9
Pension Plans [Member] \| Southwestern Electric Power Co [Member]
Actuarial Assumptions for Benefit Obligations
Discount Rate		2.90%	2.50%
Interest Crediting Rate		4.00%	4.00%
Rate of Compensation Increase	[1]	4.95%	4.90%
Actuarial Assumptions for Net Periodic Benefit Costs
Discount Rate		2.50%	3.25%	4.30%
Interest Crediting Rate		4.00%	4.00%	4.00%
Expected Return on Plan Assets		4.75%	5.75%	6.25%
Rate of Compensation Increase	[2]	4.95%	4.90%	4.90%
Change in Benefit Obligation
Benefit Obligation as of January 1		$ 334.5	$ 314.2
Service Cost		11.2	9.9	$ 8.6
Interest Cost		8.5	10.2	12.4
Actuarial (Gain) Loss		(3.5)	27.4
Plan Amendments		0	0
Benefit Payments		(33)	(27.2)
Participant Contributions		0	0
Benefit Obligation as of December 31		317.7	334.5	314.2
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1		326.9	296.9
Actual Gain (Loss) on Plan Assets		14.3	48.2
Company Contributions		0.1	9
Participant Contributions		0	0
Benefit Payments		(33)	(27.2)
Fair Value of Plan Assets as of December 31		308.3	326.9	$ 296.9
Funded (Underfunded) Status as of December 31		(9.4)	(7.6)
Benefit Amounts Recognized on the Balance Sheets
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		0	0
Other Current Liabilities - Accrued Short-term Benefit Liability		(0.1)	(0.1)
Employee Benefits and Pension Obligations - Accrued Long-term Benefit Liability		(9.3)	(7.5)
Funded (Underfunded) Status		(9.4)	(7.6)
Components
Net Actuarial Loss		76.4	86.9
Prior Service Cost (Credit)		0	0
Components of Change in Amounts Included in AOCI and Regulatory Assets
Actuarial (Gain) Loss During the Year		(4.3)	(5.2)
Amortization of Actuarial Gain (Loss)		(6.2)	(5.7)
Prior Service (Credit) Cost		0	0
Amortization of Prior Service Credit (Cost)		0	0
Change for the Year		$ (10.5)	$ (10.9)
Benefit Plans (Textuals) [Abstract]
Rate of Compensation Increase	[1]	4.95%	4.90%
Company Contributions		$ 0.1	$ 9
Pension Plans [Member] \| Southwestern Electric Power Co [Member] \| Regulatory Assets [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		76.4	86.9
Pension Plans [Member] \| Southwestern Electric Power Co [Member] \| Deferred Income Taxes [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		0	0
Pension Plans [Member] \| Southwestern Electric Power Co [Member] \| Net of Tax AOCI [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		$ 0	0
Pension Plans [Member] \| Minimum [Member]
Actuarial Assumptions for Benefit Obligations
Rate of Compensation Increase		3.00%
Benefit Plans (Textuals) [Abstract]
Rate of Compensation Increase		3.00%
Pension Plans [Member] \| Minimum [Member] \| AEP Texas Inc. [Member]
Actuarial Assumptions for Benefit Obligations
Rate of Compensation Increase		3.00%
Benefit Plans (Textuals) [Abstract]
Rate of Compensation Increase		3.00%
Pension Plans [Member] \| Minimum [Member] \| Appalachian Power Co [Member]
Actuarial Assumptions for Benefit Obligations
Rate of Compensation Increase		3.00%
Benefit Plans (Textuals) [Abstract]
Rate of Compensation Increase		3.00%
Pension Plans [Member] \| Minimum [Member] \| Indiana Michigan Power Co [Member]
Actuarial Assumptions for Benefit Obligations
Rate of Compensation Increase		3.00%
Benefit Plans (Textuals) [Abstract]
Rate of Compensation Increase		3.00%
Pension Plans [Member] \| Minimum [Member] \| Ohio Power Co [Member]
Actuarial Assumptions for Benefit Obligations
Rate of Compensation Increase		3.00%
Benefit Plans (Textuals) [Abstract]
Rate of Compensation Increase		3.00%
Pension Plans [Member] \| Minimum [Member] \| Public Service Co Of Oklahoma [Member]
Actuarial Assumptions for Benefit Obligations
Rate of Compensation Increase		3.00%
Benefit Plans (Textuals) [Abstract]
Rate of Compensation Increase		3.00%
Pension Plans [Member] \| Minimum [Member] \| Southwestern Electric Power Co [Member]
Actuarial Assumptions for Benefit Obligations
Rate of Compensation Increase		3.00%
Benefit Plans (Textuals) [Abstract]
Rate of Compensation Increase		3.00%
Pension Plans [Member] \| Maximum [Member]
Actuarial Assumptions for Benefit Obligations
Rate of Compensation Increase		11.50%
Benefit Plans (Textuals) [Abstract]
Rate of Compensation Increase		11.50%
Pension Plans [Member] \| Maximum [Member] \| AEP Texas Inc. [Member]
Actuarial Assumptions for Benefit Obligations
Rate of Compensation Increase		11.50%
Benefit Plans (Textuals) [Abstract]
Rate of Compensation Increase		11.50%
Pension Plans [Member] \| Maximum [Member] \| Appalachian Power Co [Member]
Actuarial Assumptions for Benefit Obligations
Rate of Compensation Increase		11.50%
Benefit Plans (Textuals) [Abstract]
Rate of Compensation Increase		11.50%
Pension Plans [Member] \| Maximum [Member] \| Indiana Michigan Power Co [Member]
Actuarial Assumptions for Benefit Obligations
Rate of Compensation Increase		11.50%
Benefit Plans (Textuals) [Abstract]
Rate of Compensation Increase		11.50%
Pension Plans [Member] \| Maximum [Member] \| Ohio Power Co [Member]
Actuarial Assumptions for Benefit Obligations
Rate of Compensation Increase		11.50%
Benefit Plans (Textuals) [Abstract]
Rate of Compensation Increase		11.50%
Pension Plans [Member] \| Maximum [Member] \| Public Service Co Of Oklahoma [Member]
Actuarial Assumptions for Benefit Obligations
Rate of Compensation Increase		11.50%
Benefit Plans (Textuals) [Abstract]
Rate of Compensation Increase		11.50%
Pension Plans [Member] \| Maximum [Member] \| Southwestern Electric Power Co [Member]
Actuarial Assumptions for Benefit Obligations
Rate of Compensation Increase		11.50%
Benefit Plans (Textuals) [Abstract]
Rate of Compensation Increase		11.50%
Qualified Pension Plans [Member]
Change in Fair Value of Plan Assets
Company Contributions		$ 0	110
Benefit Plans (Textuals) [Abstract]
Company Contributions		0	110
Nonqualified Pension Plans [Member]
Change in Benefit Obligation
Benefit Obligation as of January 1		81.4
Benefit Obligation as of December 31		78.4	81.4
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1		0
Company Contributions		7	6
Fair Value of Plan Assets as of December 31		0	0
Benefit Plans (Textuals) [Abstract]
Company Contributions		7	6
Nonqualified Pension Plans [Member] \| AEP Texas Inc. [Member]
Change in Benefit Obligation
Benefit Obligation as of January 1		3.9
Benefit Obligation as of December 31		3.6	3.9
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1		0
Fair Value of Plan Assets as of December 31		0	0
Nonqualified Pension Plans [Member] \| Appalachian Power Co [Member]
Change in Benefit Obligation
Benefit Obligation as of January 1		0.5
Benefit Obligation as of December 31		0.8	0.5
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1		0
Fair Value of Plan Assets as of December 31		0	0
Nonqualified Pension Plans [Member] \| Indiana Michigan Power Co [Member]
Change in Benefit Obligation
Benefit Obligation as of January 1		1.7
Benefit Obligation as of December 31		1.9	1.7
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1		0
Fair Value of Plan Assets as of December 31		0	0
Nonqualified Pension Plans [Member] \| Ohio Power Co [Member]
Change in Benefit Obligation
Benefit Obligation as of January 1		0.6
Benefit Obligation as of December 31		0.7	0.6
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1		0
Fair Value of Plan Assets as of December 31		0	0
Nonqualified Pension Plans [Member] \| Public Service Co Of Oklahoma [Member]
Change in Benefit Obligation
Benefit Obligation as of January 1		2
Benefit Obligation as of December 31		1.9	2
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1		0
Fair Value of Plan Assets as of December 31		0	0
Nonqualified Pension Plans [Member] \| Southwestern Electric Power Co [Member]
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1		0
Fair Value of Plan Assets as of December 31		$ 0	$ 0
Other Postretirement Benefit Plans [Member]
Actuarial Assumptions for Benefit Obligations
Discount Rate		2.90%	2.55%
Actuarial Assumptions for Net Periodic Benefit Costs
Discount Rate		2.55%	3.30%	4.30%
Expected Return on Plan Assets		4.75%	5.50%	6.25%
Health Care Trend Rates
Initial		6.25%	6.50%
Ultimate		4.50%	4.50%
Year Ultimate Reached		2029	2029
Change in Benefit Obligation
Benefit Obligation as of January 1		$ 1,210.9	$ 1,225.4
Service Cost		9.5	10	$ 9.5
Interest Cost		30.5	39.8	50.5
Actuarial (Gain) Loss		(120.1)	39.3
Plan Amendments		(5.4)	(11.4)
Benefit Payments		(126)	(131)
Participant Contributions		41.3	38.2
Medicare Subsidy		0.6	0.6
Benefit Obligation as of December 31		1,041.3	1,210.9	1,225.4
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1		1,946.7	1,781.8
Actual Gain (Loss) on Plan Assets		176.5	253
Company Contributions	[3]	5.8	4.7
Participant Contributions		41.3	38.2
Benefit Payments		(126)	(131)
Fair Value of Plan Assets as of December 31		2,044.3	1,946.7	$ 1,781.8
Funded (Underfunded) Status as of December 31		1,003	735.8
Benefit Amounts Recognized on the Balance Sheets
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		1,040.8	771.9
Other Current Liabilities - Accrued Short-term Benefit Liability		(2.7)	(2.4)
Employee Benefits and Pension Obligations - Accrued Long-term Benefit Liability		(35.1)	(33.7)
Funded (Underfunded) Status		1,003	735.8
Components
Net Actuarial Loss		(103.6)	101.9
Prior Service Cost (Credit)		(161.9)	(227.3)
Components of Change in Amounts Included in AOCI and Regulatory Assets
Actuarial (Gain) Loss During the Year		(205.5)	(118)
Amortization of Actuarial Gain (Loss)		0	(5.9)
Prior Service (Credit) Cost		(5.5)	(11.4)
Amortization of Prior Service Credit (Cost)		70.9	69.8
Change for the Year		(140.1)	(65.5)
Benefit Plans (Textuals) [Abstract]
Company Contributions	[3]	5.8	4.7
Other Postretirement Benefit Plans [Member] \| Regulatory Assets [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		(195.1)	(99)
Other Postretirement Benefit Plans [Member] \| Deferred Income Taxes [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		(14.7)	(5.5)
Other Postretirement Benefit Plans [Member] \| Net of Tax AOCI [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		$ (55.7)	$ (20.9)
Other Postretirement Benefit Plans [Member] \| AEP Texas Inc. [Member]
Actuarial Assumptions for Benefit Obligations
Discount Rate		2.90%	2.55%
Actuarial Assumptions for Net Periodic Benefit Costs
Discount Rate		2.55%	3.30%	4.30%
Expected Return on Plan Assets		4.75%	5.50%	6.25%
Health Care Trend Rates
Initial		6.25%	6.50%
Ultimate		4.50%	4.50%
Year Ultimate Reached		2029	2029
Change in Benefit Obligation
Benefit Obligation as of January 1		$ 96.3	$ 97.8
Service Cost		0.7	0.8	$ 0.8
Interest Cost		2.4	3.2	4
Actuarial (Gain) Loss		(12.3)	2.4
Plan Amendments		(0.5)	(1)
Benefit Payments		(9.3)	(10)
Participant Contributions		3.2	3.1
Benefit Obligation as of December 31		80.5	96.3	97.8
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1		162.3	148.1
Actual Gain (Loss) on Plan Assets		12.5	21.1
Company Contributions		0.1	0
Participant Contributions		3.2	3.1
Benefit Payments		(9.3)	(10)
Fair Value of Plan Assets as of December 31		168.8	162.3	$ 148.1
Funded (Underfunded) Status as of December 31		88.3	66
Benefit Amounts Recognized on the Balance Sheets
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		88.3	66
Other Current Liabilities - Accrued Short-term Benefit Liability		0	0
Deferred Credits and Other Noncurrent Liabilities - Accrued Long-term Benefit Liability		0	0
Funded (Underfunded) Status		88.3	66
Components
Net Actuarial Loss		(5.2)	12.3
Prior Service Cost (Credit)		(13.7)	(19.3)
Components of Change in Amounts Included in AOCI and Regulatory Assets
Actuarial (Gain) Loss During the Year		(17.5)	(10.7)
Amortization of Actuarial Gain (Loss)		0	(0.5)
Prior Service (Credit) Cost		(0.4)	(1)
Amortization of Prior Service Credit (Cost)		6	5.9
Change for the Year		(11.9)	(6.3)
Benefit Plans (Textuals) [Abstract]
Company Contributions		0.1	0
Other Postretirement Benefit Plans [Member] \| AEP Texas Inc. [Member] \| Regulatory Assets [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		(17.7)	(6.3)
Other Postretirement Benefit Plans [Member] \| AEP Texas Inc. [Member] \| Deferred Income Taxes [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		(0.2)	(0.1)
Other Postretirement Benefit Plans [Member] \| AEP Texas Inc. [Member] \| Net of Tax AOCI [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		$ (1)	$ (0.6)
Other Postretirement Benefit Plans [Member] \| Appalachian Power Co [Member]
Actuarial Assumptions for Benefit Obligations
Discount Rate		2.90%	2.55%
Actuarial Assumptions for Net Periodic Benefit Costs
Discount Rate		2.55%	3.30%	4.30%
Expected Return on Plan Assets		4.75%	5.50%	6.25%
Health Care Trend Rates
Initial		6.25%	6.50%
Ultimate		4.50%	4.50%
Year Ultimate Reached		2029	2029
Change in Benefit Obligation
Benefit Obligation as of January 1		$ 198.2	$ 203.5
Service Cost		1	1	$ 1
Interest Cost		4.9	6.6	8.7
Actuarial (Gain) Loss		(21.4)	5.6
Plan Amendments		(0.9)	(1.8)
Benefit Payments		(21.3)	(23.2)
Participant Contributions		6.6	6.3
Medicare Subsidy		0.2	0.2
Benefit Obligation as of December 31		167.3	198.2	203.5
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1		293	271
Actual Gain (Loss) on Plan Assets		21.9	36.8
Company Contributions		2.1	2.1
Participant Contributions		6.6	6.3
Benefit Payments		(21.3)	(23.2)
Fair Value of Plan Assets as of December 31		302.3	293	$ 271
Funded (Underfunded) Status as of December 31		135	94.8
Benefit Amounts Recognized on the Balance Sheets
Employee Benefits and Pension Assets - Prepaid Benefit Costs		158.1	119.1
Other Current Liabilities - Accrued Short-term Benefit Liability		(1.8)	(1.8)
Employee Benefits and Pension Obligations - Accrued Long-term Benefit Liability		(21.3)	(22.5)
Funded (Underfunded) Status		135	94.8
Components
Net Actuarial Loss		(18.9)	11.1
Prior Service Cost (Credit)		(23.8)	(33.2)
Components of Change in Amounts Included in AOCI and Regulatory Assets
Actuarial (Gain) Loss During the Year		(30)	(16.8)
Amortization of Actuarial Gain (Loss)		0	(0.9)
Prior Service (Credit) Cost		(0.9)	(1.8)
Amortization of Prior Service Credit (Cost)		10.3	10.2
Change for the Year		(20.6)	(9.3)
Benefit Plans (Textuals) [Abstract]
Company Contributions		2.1	2.1
Other Postretirement Benefit Plans [Member] \| Appalachian Power Co [Member] \| Regulatory Assets [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		(19.8)	(10.3)
Other Postretirement Benefit Plans [Member] \| Appalachian Power Co [Member] \| Deferred Income Taxes [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		(4.9)	(2.5)
Other Postretirement Benefit Plans [Member] \| Appalachian Power Co [Member] \| Net of Tax AOCI [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		$ (18)	$ (9.3)
Other Postretirement Benefit Plans [Member] \| Indiana Michigan Power Co [Member]
Actuarial Assumptions for Benefit Obligations
Discount Rate		2.90%	2.55%
Actuarial Assumptions for Net Periodic Benefit Costs
Discount Rate		2.55%	3.30%	4.30%
Expected Return on Plan Assets		4.75%	5.50%	6.25%
Health Care Trend Rates
Initial		6.25%	6.50%
Ultimate		4.50%	4.50%
Year Ultimate Reached		2029	2029
Change in Benefit Obligation
Benefit Obligation as of January 1		$ 141.4	$ 142.9
Service Cost		1.3	1.4	$ 1.4
Interest Cost		3.5	4.7	5.8
Actuarial (Gain) Loss		(16.8)	5.1
Plan Amendments		(0.7)	(1.6)
Benefit Payments		(15.3)	(15.9)
Participant Contributions		5.2	4.8
Benefit Obligation as of December 31		118.6	141.4	142.9
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1		238.2	216.3
Actual Gain (Loss) on Plan Assets		20.6	33
Company Contributions		0	0
Participant Contributions		5.2	4.8
Benefit Payments		(15.3)	(15.9)
Fair Value of Plan Assets as of December 31		248.7	238.2	$ 216.3
Funded (Underfunded) Status as of December 31		130.1	96.8
Benefit Amounts Recognized on the Balance Sheets
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		130.1	96.8
Other Current Liabilities - Accrued Short-term Benefit Liability		0	0
Deferred Credits and Other Noncurrent Liabilities - Accrued Long-term Benefit Liability		0	0
Funded (Underfunded) Status		130.1	96.8
Components
Net Actuarial Loss		(10.7)	15.6
Prior Service Cost (Credit)		(22.1)	(31)
Components of Change in Amounts Included in AOCI and Regulatory Assets
Actuarial (Gain) Loss During the Year		(26.3)	(16.4)
Amortization of Actuarial Gain (Loss)		0	(0.7)
Prior Service (Credit) Cost		(0.7)	(1.5)
Amortization of Prior Service Credit (Cost)		9.6	9.5
Change for the Year		(17.4)	(9.1)
Benefit Plans (Textuals) [Abstract]
Company Contributions		0	0
Other Postretirement Benefit Plans [Member] \| Indiana Michigan Power Co [Member] \| Regulatory Assets [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets	[4]	(30.7)	(14.6)
Other Postretirement Benefit Plans [Member] \| Indiana Michigan Power Co [Member] \| Deferred Income Taxes [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		(0.4)	(0.2)
Other Postretirement Benefit Plans [Member] \| Indiana Michigan Power Co [Member] \| Net of Tax AOCI [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		$ (1.7)	$ (0.6)
Other Postretirement Benefit Plans [Member] \| Ohio Power Co [Member]
Actuarial Assumptions for Benefit Obligations
Discount Rate		2.90%	2.55%
Actuarial Assumptions for Net Periodic Benefit Costs
Discount Rate		2.55%	3.30%	4.30%
Expected Return on Plan Assets		4.75%	5.50%	6.25%
Health Care Trend Rates
Initial		6.25%	6.50%
Ultimate		4.50%	4.50%
Year Ultimate Reached		2029	2029
Change in Benefit Obligation
Benefit Obligation as of January 1		$ 126.4	$ 130.2
Service Cost		0.8	0.9	$ 0.8
Interest Cost		3	4.2	5.5
Actuarial (Gain) Loss		(15.6)	3.1
Plan Amendments		(0.6)	(1.3)
Benefit Payments		(13.6)	(15)
Participant Contributions		4.5	4.3
Benefit Obligation as of December 31		104.9	126.4	130.2
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1		213	197.1
Actual Gain (Loss) on Plan Assets		16.1	26.6
Company Contributions		0	0
Participant Contributions		4.5	4.3
Benefit Payments		(13.6)	(15)
Fair Value of Plan Assets as of December 31		220	213	$ 197.1
Funded (Underfunded) Status as of December 31		115.1	86.6
Benefit Amounts Recognized on the Balance Sheets
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		115.1	86.6
Deferred Credits and Other Noncurrent Liabilities - Accrued Long-term Benefit Liability		0	0
Funded (Underfunded) Status		115.1	86.6
Components
Net Actuarial Loss		(18.5)	3.6
Prior Service Cost (Credit)		(16.3)	(22.9)
Components of Change in Amounts Included in AOCI and Regulatory Assets
Actuarial (Gain) Loss During the Year		(22.1)	(12.9)
Amortization of Actuarial Gain (Loss)		0	(0.7)
Prior Service (Credit) Cost		(0.6)	(1.3)
Amortization of Prior Service Credit (Cost)		7.2	7
Change for the Year		(15.5)	(7.9)
Benefit Plans (Textuals) [Abstract]
Company Contributions		0	0
Other Postretirement Benefit Plans [Member] \| Ohio Power Co [Member] \| Regulatory Assets [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		$ (34.8)	$ (19.3)
Other Postretirement Benefit Plans [Member] \| Public Service Co Of Oklahoma [Member]
Actuarial Assumptions for Benefit Obligations
Discount Rate		2.90%	2.55%
Actuarial Assumptions for Net Periodic Benefit Costs
Discount Rate		2.55%	3.30%	4.30%
Expected Return on Plan Assets		4.75%	5.50%	6.25%
Health Care Trend Rates
Initial		6.25%	6.50%
Ultimate		4.50%	4.50%
Year Ultimate Reached		2029	2029
Change in Benefit Obligation
Benefit Obligation as of January 1		$ 64	$ 64.7
Service Cost		0.6	0.7	$ 0.6
Interest Cost		1.6	2.1	2.6
Actuarial (Gain) Loss		(6.8)	1.9
Plan Amendments		(0.3)	(0.7)
Benefit Payments		(7)	(6.8)
Participant Contributions		2.3	2.1
Benefit Obligation as of December 31		54.4	64	64.7
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1		107.8	98
Actual Gain (Loss) on Plan Assets		10.9	14.5
Company Contributions		0	0
Participant Contributions		2.3	2.1
Benefit Payments		(7)	(6.8)
Fair Value of Plan Assets as of December 31		114	107.8	$ 98
Funded (Underfunded) Status as of December 31		59.6	43.8
Benefit Amounts Recognized on the Balance Sheets
Employee Benefits and Pension Assets - Prepaid Benefit Costs		59.6	43.8
Other Current Liabilities - Accrued Short-term Benefit Liability		0	0
Deferred Credits and Other Noncurrent Liabilities - Accrued Long-term Benefit Liability		0	0
Funded (Underfunded) Status		59.6	43.8
Components
Net Actuarial Loss		(2.1)	10.5
Prior Service Cost (Credit)		(10)	(14.1)
Components of Change in Amounts Included in AOCI and Regulatory Assets
Actuarial (Gain) Loss During the Year		(12.6)	(7.4)
Amortization of Actuarial Gain (Loss)		0	(0.3)
Prior Service (Credit) Cost		(0.3)	(0.7)
Amortization of Prior Service Credit (Cost)		4.4	4.4
Change for the Year		(8.5)	(4)
Benefit Plans (Textuals) [Abstract]
Company Contributions		0	0
Other Postretirement Benefit Plans [Member] \| Public Service Co Of Oklahoma [Member] \| Regulatory Assets [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		$ (12.1)	$ (3.6)
Other Postretirement Benefit Plans [Member] \| Southwestern Electric Power Co [Member]
Actuarial Assumptions for Benefit Obligations
Discount Rate		2.90%	2.55%
Actuarial Assumptions for Net Periodic Benefit Costs
Discount Rate		2.55%	3.30%	4.30%
Expected Return on Plan Assets		4.75%	5.50%	6.25%
Health Care Trend Rates
Initial		6.25%	6.50%
Ultimate		4.50%	4.50%
Year Ultimate Reached		2029	2029
Change in Benefit Obligation
Benefit Obligation as of January 1		$ 77.1	$ 77.4
Service Cost		0.8	0.8	$ 0.8
Interest Cost		1.9	2.5	3.1
Actuarial (Gain) Loss		(9.2)	2.5
Plan Amendments		(0.4)	(0.8)
Benefit Payments		(7.6)	(7.7)
Participant Contributions		2.6	2.4
Benefit Obligation as of December 31		65.2	77.1	77.4
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1		129.9	117.2
Actual Gain (Loss) on Plan Assets		11.7	18
Company Contributions		0	0
Participant Contributions		2.6	2.4
Benefit Payments		(7.6)	(7.7)
Fair Value of Plan Assets as of December 31		136.6	129.9	$ 117.2
Funded (Underfunded) Status as of December 31		71.4	52.8
Benefit Amounts Recognized on the Balance Sheets
Deferred Charges and Other Noncurrent Assets - Prepaid Benefit Costs		71.4	52.8
Other Current Liabilities - Accrued Short-term Benefit Liability		0	0
Employee Benefits and Pension Obligations - Accrued Long-term Benefit Liability		0	0
Funded (Underfunded) Status		71.4	52.8
Components
Net Actuarial Loss		(3.5)	11.5
Prior Service Cost (Credit)		(12.3)	(17.2)
Components of Change in Amounts Included in AOCI and Regulatory Assets
Actuarial (Gain) Loss During the Year		(15)	(9.2)
Amortization of Actuarial Gain (Loss)		0	(0.4)
Prior Service (Credit) Cost		(0.4)	(0.8)
Amortization of Prior Service Credit (Cost)		5.3	5.2
Change for the Year		(10.1)	(5.2)
Benefit Plans (Textuals) [Abstract]
Company Contributions		0	0
Other Postretirement Benefit Plans [Member] \| Southwestern Electric Power Co [Member] \| Regulatory Assets [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		(8.9)	(3)
Other Postretirement Benefit Plans [Member] \| Southwestern Electric Power Co [Member] \| Deferred Income Taxes [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		(1.4)	(0.5)
Other Postretirement Benefit Plans [Member] \| Southwestern Electric Power Co [Member] \| Net of Tax AOCI [Member]
Recorded as
Total of Amounts Included in AOCI, Income Tax Expense and Regulatory Assets		$ (5.5)	$ (2.2)

[1]	Rates are for base pay only. In addition, an amount is added to reflect target incentive compensation for exempt employees and overtime and incentive pay for nonexempt employees.
[2]	Rates are for base pay only. In addition, an amount is added to reflect target incentive compensation for exempt employees and overtime and incentive pay for nonexempt employees.
[3]	Contributions to the qualified pension plan were $0 and $110 million for the years ended December 31, 2021 and 2020, respectively. Contributions to the non-qualified pension plans were $7 million and $6 million for the years ended December 31, 2021 and 2020, respectively.
[4]	Recorded as a Regulatory Liability as of December 31, 2021 and recorded as a Regulatory Asset as of December 31, 2020.

Benefit Plans 2 (Details)

Benefit Plans 2 (Details) - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		$ 5,352.9	$ 5,556.6	$ 5,015.4
Year End Allocation
Total		100.00%	100.00%
Pension Plan [Member] \| AEP Texas Inc. [Member]
Allocated Assets of Investments		8.30%	8.50%
Pension and Other Postretirement Plans' Assets
Asset Class		$ 444.9	$ 474	435.1
Pension Plan [Member] \| Appalachian Power Co [Member]
Allocated Assets of Investments		12.80%	12.60%
Pension and Other Postretirement Plans' Assets
Asset Class		$ 683.3	$ 701.3	637
Pension Plan [Member] \| Indiana Michigan Power Co [Member]
Allocated Assets of Investments		12.70%	12.60%
Pension and Other Postretirement Plans' Assets
Asset Class		$ 681.5	$ 698.1	630.5
Pension Plan [Member] \| Ohio Power Co [Member]
Allocated Assets of Investments		9.80%	9.80%
Pension and Other Postretirement Plans' Assets
Asset Class		$ 524.8	$ 543.1	499.1
Pension Plan [Member] \| Public Service Co Of Oklahoma [Member]
Allocated Assets of Investments		5.30%	5.40%
Pension and Other Postretirement Plans' Assets
Asset Class		$ 286.2	$ 299.8	276.2
Pension Plan [Member] \| Southwestern Electric Power Co [Member]
Allocated Assets of Investments		5.80%	5.90%
Pension and Other Postretirement Plans' Assets
Asset Class		$ 308.3	$ 326.9	296.9
Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		$ 2,044.3	$ 1,946.7	1,781.8
Year End Allocation
Total		100.00%	100.00%
Other Postretirement Benefit Plans [Member] \| AEP Texas Inc. [Member]
Allocated Assets of Investments		8.30%	8.30%
Pension and Other Postretirement Plans' Assets
Asset Class		$ 168.8	$ 162.3	148.1
Other Postretirement Benefit Plans [Member] \| Appalachian Power Co [Member]
Allocated Assets of Investments		14.80%	15.10%
Pension and Other Postretirement Plans' Assets
Asset Class		$ 302.3	$ 293	271
Other Postretirement Benefit Plans [Member] \| Indiana Michigan Power Co [Member]
Allocated Assets of Investments		12.20%	12.20%
Pension and Other Postretirement Plans' Assets
Asset Class		$ 248.7	$ 238.2	216.3
Other Postretirement Benefit Plans [Member] \| Ohio Power Co [Member]
Allocated Assets of Investments		10.80%	10.90%
Pension and Other Postretirement Plans' Assets
Asset Class		$ 220	$ 213	197.1
Other Postretirement Benefit Plans [Member] \| Public Service Co Of Oklahoma [Member]
Allocated Assets of Investments		5.60%	5.50%
Pension and Other Postretirement Plans' Assets
Asset Class		$ 114	$ 107.8	98
Other Postretirement Benefit Plans [Member] \| Southwestern Electric Power Co [Member]
Allocated Assets of Investments		6.70%	6.70%
Pension and Other Postretirement Plans' Assets
Asset Class		$ 136.6	$ 129.9	$ 117.2
Other [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		1,262.6	1,460.2
Other [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		445.4	459
Level 1 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		854.7	1,217.2
Level 1 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		895.2	790.6
Level 2 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		3,235.6	2,879.2
Level 2 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		703.7	697.1
Level 3 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
Level 3 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
Equity Securities [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	$ 1,318.5	$ 1,868.6
Year End Allocation
Total	[1]	24.60%	33.60%
Equity Securities [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		$ 1,035.3	$ 955.3
Year End Allocation
Total		50.70%	49.10%
Equity Securities [Member] \| Other [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	$ 463.9	$ 650
Equity Securities [Member] \| Other [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		265	264.7
Equity Securities [Member] \| Level 1 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	854.6	1,218.6
Equity Securities [Member] \| Level 1 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		770.3	690.6
Equity Securities [Member] \| Level 2 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	0	0
Equity Securities [Member] \| Level 2 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
Equity Securities [Member] \| Level 3 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	0	0
Equity Securities [Member] \| Level 3 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
Domestic [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	$ 388.9	$ 542.3
Year End Allocation
Total	[1]	7.20%	9.70%
Domestic [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		$ 474	$ 399.9
Year End Allocation
Total		23.20%	20.60%
Domestic [Member] \| Other [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	$ 0	$ 0
Domestic [Member] \| Other [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
Domestic [Member] \| Level 1 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	388.9	542.3
Domestic [Member] \| Level 1 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		474	399.9
Domestic [Member] \| Level 2 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	0	0
Domestic [Member] \| Level 2 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
Domestic [Member] \| Level 3 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	0	0
Domestic [Member] \| Level 3 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
International [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	$ 465.7	$ 676.3
Year End Allocation
Total	[1]	8.70%	12.20%
International [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		$ 296.3	$ 290.7
Year End Allocation
Total		14.50%	14.90%
International [Member] \| Other [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	$ 0	$ 0
International [Member] \| Other [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
International [Member] \| Level 1 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	465.7	676.3
International [Member] \| Level 1 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		296.3	290.7
International [Member] \| Level 2 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	0	0
International [Member] \| Level 2 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
International [Member] \| Level 3 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	0	0
International [Member] \| Level 3 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
Common Collective Trusts [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1],[2]	$ 463.9	$ 650
Year End Allocation
Total	[1],[2]	8.70%	11.70%
Common Collective Trusts [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[3]	$ 265	$ 264.7
Year End Allocation
Total	[3]	13.00%	13.60%
Common Collective Trusts [Member] \| Other [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1],[2]	$ 463.9	$ 650
Common Collective Trusts [Member] \| Other [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[3]	265	264.7
Common Collective Trusts [Member] \| Level 1 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1],[2]	0	0
Common Collective Trusts [Member] \| Level 1 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[3]	0	0
Common Collective Trusts [Member] \| Level 2 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1],[2]	0	0
Common Collective Trusts [Member] \| Level 2 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[3]	0	0
Common Collective Trusts [Member] \| Level 3 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1],[2]	0	0
Common Collective Trusts [Member] \| Level 3 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[3]	0	0
Fixed Income [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	$ 3,171.4	$ 2,828.5
Year End Allocation
Total	[1]	59.20%	50.90%
Fixed Income [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		$ 768.6	$ 756.5
Year End Allocation
Total		37.60%	38.90%
Fixed Income [Member] \| Other [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	$ 0	$ 0
Fixed Income [Member] \| Other [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		167.7	186.4
Fixed Income [Member] \| Level 1 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	0.1	(1.4)
Fixed Income [Member] \| Level 1 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		91.9	73.7
Fixed Income [Member] \| Level 2 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	3,171.3	2,829.9
Fixed Income [Member] \| Level 2 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		509	496.4
Fixed Income [Member] \| Level 3 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	0	0
Fixed Income [Member] \| Level 3 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
Common Collective Trust - Debt [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[3]	$ 167.7	$ 186.4
Year End Allocation
Total	[3]	8.20%	9.60%
Common Collective Trust - Debt [Member] \| Other [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[3]	$ 167.7	$ 186.4
Common Collective Trust - Debt [Member] \| Level 1 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[3]	0	0
Common Collective Trust - Debt [Member] \| Level 2 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[3]	0	0
Common Collective Trust - Debt [Member] \| Level 3 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[3]	0	0
United States Government and Agency Securities [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	$ 1,557.7	$ 1,132.7
Year End Allocation
Total	[1]	29.10%	20.40%
United States Government and Agency Securities [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		$ 222.4	$ 199.5
Year End Allocation
Total		10.90%	10.20%
United States Government and Agency Securities [Member] \| Other [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	$ 0	$ 0
United States Government and Agency Securities [Member] \| Other [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
United States Government and Agency Securities [Member] \| Level 1 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	0.1	(1.4)
United States Government and Agency Securities [Member] \| Level 1 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	(0.2)
United States Government and Agency Securities [Member] \| Level 2 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	1,557.6	1,134.1
United States Government and Agency Securities [Member] \| Level 2 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		222.4	199.7
United States Government and Agency Securities [Member] \| Level 3 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	0	0
United States Government and Agency Securities [Member] \| Level 3 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
Corporate Debt [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	$ 1,295.9	$ 1,425
Year End Allocation
Total	[1]	24.20%	25.60%
Corporate Debt [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		$ 233.2	$ 248.7
Year End Allocation
Total		11.40%	12.80%
Corporate Debt [Member] \| Other [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	$ 0	$ 0
Corporate Debt [Member] \| Other [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
Corporate Debt [Member] \| Level 1 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	0	0
Corporate Debt [Member] \| Level 1 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
Corporate Debt [Member] \| Level 2 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	1,295.9	1,425
Corporate Debt [Member] \| Level 2 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		233.2	248.7
Corporate Debt [Member] \| Level 3 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	0	0
Corporate Debt [Member] \| Level 3 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
Foreign Debt [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	$ 259.4	$ 214
Year End Allocation
Total	[1]	4.80%	3.90%
Foreign Debt [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		$ 39.8	$ 34.9
Year End Allocation
Total		2.00%	1.80%
Foreign Debt [Member] \| Other [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	$ 0	$ 0
Foreign Debt [Member] \| Other [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
Foreign Debt [Member] \| Level 1 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	0	0
Foreign Debt [Member] \| Level 1 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
Foreign Debt [Member] \| Level 2 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	259.4	214
Foreign Debt [Member] \| Level 2 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		39.8	34.9
Foreign Debt [Member] \| Level 3 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	0	0
Foreign Debt [Member] \| Level 3 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
State and Local Government [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	$ 57.1	$ 56
Year End Allocation
Total	[1]	1.10%	1.00%
State and Local Government [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		$ 105.5	$ 87
Year End Allocation
Total		5.10%	4.50%
State and Local Government [Member] \| Other [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	$ 0	$ 0
State and Local Government [Member] \| Other [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
State and Local Government [Member] \| Level 1 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	0	0
State and Local Government [Member] \| Level 1 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		91.9	73.9
State and Local Government [Member] \| Level 2 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	57.1	56
State and Local Government [Member] \| Level 2 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		13.6	13.1
State and Local Government [Member] \| Level 3 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	0	0
State and Local Government [Member] \| Level 3 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
Other - Asset Backed [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	$ 1.3	$ 0.8
Year End Allocation
Total	[1]	0.00%	0.00%
Other - Asset Backed [Member] \| Other [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	$ 0	$ 0
Other - Asset Backed [Member] \| Level 1 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	0	0
Other - Asset Backed [Member] \| Level 2 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	1.3	0.8
Other - Asset Backed [Member] \| Level 3 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[1]	0	0
Infrastructure [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[2]	$ 92.1	$ 91.1
Year End Allocation
Total	[2]	1.70%	1.60%
Infrastructure [Member] \| Other [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[2]	$ 92.1	$ 91.1
Infrastructure [Member] \| Level 1 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[2]	0	0
Infrastructure [Member] \| Level 2 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[2]	0	0
Infrastructure [Member] \| Level 3 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[2]	0	0
Real Estate [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[2]	$ 232.6	$ 231.6
Year End Allocation
Total	[2]	4.40%	4.20%
Real Estate [Member] \| Other [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[2]	$ 232.6	$ 231.6
Real Estate [Member] \| Level 1 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[2]	0	0
Real Estate [Member] \| Level 2 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[2]	0	0
Real Estate [Member] \| Level 3 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[2]	0	0
Alternative Investments [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[2]	$ 448.8	$ 431.8
Year End Allocation
Total	[2]	8.40%	7.80%
Alternative Investments [Member] \| Other [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[2]	$ 448.8	$ 431.8
Alternative Investments [Member] \| Level 1 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[2]	0	0
Alternative Investments [Member] \| Level 2 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[2]	0	0
Alternative Investments [Member] \| Level 3 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[2]	0	0
Trusted Owned Life Insurance [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		$ 194.7	$ 200.7
Year End Allocation
Total		9.50%	10.30%
Trusted Owned Life Insurance [Member] \| Other [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		$ 0	$ 0
Trusted Owned Life Insurance [Member] \| Level 1 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
Trusted Owned Life Insurance [Member] \| Level 2 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		194.7	200.7
Trusted Owned Life Insurance [Member] \| Level 3 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
International Equities [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		$ 23.4	$ 64.8
Year End Allocation
Total		1.10%	3.30%
International Equities [Member] \| Other [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		$ 0	$ 0
International Equities [Member] \| Level 1 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
International Equities [Member] \| Level 2 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		23.4	64.8
International Equities [Member] \| Level 3 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
United States Bonds [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		$ 171.3	$ 135.9
Year End Allocation
Total		8.40%	7.00%
United States Bonds [Member] \| Other [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		$ 0	$ 0
United States Bonds [Member] \| Level 1 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
United States Bonds [Member] \| Level 2 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		171.3	135.9
United States Bonds [Member] \| Level 3 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class		0	0
Cash and Cash Equivalents [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[2]	$ 117.7	$ 107.5
Year End Allocation
Total	[2]	2.20%	1.90%
Cash and Cash Equivalents [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[3]	$ 39.7	$ 32
Year End Allocation
Total	[3]	1.90%	1.60%
Cash and Cash Equivalents [Member] \| Other [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[2]	$ 53.4	$ 58.2
Cash and Cash Equivalents [Member] \| Other [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[3]	6.7	5.7
Cash and Cash Equivalents [Member] \| Level 1 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[2]	0	0
Cash and Cash Equivalents [Member] \| Level 1 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[3]	33	26.3
Cash and Cash Equivalents [Member] \| Level 2 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[2]	64.3	49.3
Cash and Cash Equivalents [Member] \| Level 2 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[3]	0	0
Cash and Cash Equivalents [Member] \| Level 3 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[2]	0	0
Cash and Cash Equivalents [Member] \| Level 3 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[3]	0	0
Other - Pending Transactions and Accrued Income [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[4]	$ (28.2)	$ (2.5)
Year End Allocation
Total	[4]	(0.50%)	0.00%
Other - Pending Transactions and Accrued Income [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[5]	$ 6	$ 2.2
Year End Allocation
Total	[5]	0.30%	0.10%
Other - Pending Transactions and Accrued Income [Member] \| Other [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[4]	$ (28.2)	$ (2.5)
Other - Pending Transactions and Accrued Income [Member] \| Other [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[5]	6	2.2
Other - Pending Transactions and Accrued Income [Member] \| Level 1 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[4]	0	0
Other - Pending Transactions and Accrued Income [Member] \| Level 1 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[5]	0	0
Other - Pending Transactions and Accrued Income [Member] \| Level 2 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[4]	0	0
Other - Pending Transactions and Accrued Income [Member] \| Level 2 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[5]	0	0
Other - Pending Transactions and Accrued Income [Member] \| Level 3 [Member] \| Pension Plan [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[4]	0	0
Other - Pending Transactions and Accrued Income [Member] \| Level 3 [Member] \| Other Postretirement Benefit Plans [Member]
Pension and Other Postretirement Plans' Assets
Asset Class	[5]	$ 0	$ 0

[1]	Includes investment securities loaned to borrowers under the securities lending program. See the “Investments Held in Trust for Future Liabilities” section of Note 1 for additional information.
[2]	Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share.
[3]	Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share.
[4]	Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement.
[5]	Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement.

Benefit Plans 3 (Details)

Benefit Plans 3 (Details) - USD ($) $ in Millions	12 Months Ended
Benefit Plans 3 (Details) - USD ($) $ in Millions	Dec. 31, 2021		Dec. 31, 2020	Dec. 31, 2019
American Electric Power System Retirement Savings Plans
Cost of Company Matching Contributions	$ 79.9		$ 81.8	$ 76.4
Benefit Plans Textuals [Abstract]
Matching Contributions Provided Percentage	100.00%
Eligible Compensation Contribution by Employee Percentage	1.00%
Second Matching Contributions Provided Percentage	70.00%
Second Eligible Compensation Contribution by Employee Percentage	5.00%
Multiemployer Plans Withdrawal Obligation	$ 22		25
Noncurrent Regulatory Assets	4,142.3	[1]	3,527
Noncurrent Regulatory Liabilities	8,686.3	[2]	8,378.7
UMWA Withdrawal Obligation [Member]
Benefit Plans Textuals [Abstract]
Noncurrent Regulatory Assets	1		6
AEP Texas Inc. [Member]
American Electric Power System Retirement Savings Plans
Cost of Company Matching Contributions	$ 6.4		6.4	5.9
Benefit Plans Textuals [Abstract]
Matching Contributions Provided Percentage	100.00%
Eligible Compensation Contribution by Employee Percentage	1.00%
Second Matching Contributions Provided Percentage	70.00%
Second Eligible Compensation Contribution by Employee Percentage	5.00%
Noncurrent Regulatory Assets	$ 275.2		266.8
Noncurrent Regulatory Liabilities	1,242		1,270.8
Appalachian Power Co [Member]
American Electric Power System Retirement Savings Plans
Cost of Company Matching Contributions	$ 7.6		7.7	7.5
Benefit Plans Textuals [Abstract]
Matching Contributions Provided Percentage	100.00%
Eligible Compensation Contribution by Employee Percentage	1.00%
Second Matching Contributions Provided Percentage	70.00%
Second Eligible Compensation Contribution by Employee Percentage	5.00%
Noncurrent Regulatory Assets	$ 757.6		686.3
Noncurrent Regulatory Liabilities	1,238.8		1,224.7
Indiana Michigan Power Co [Member]
American Electric Power System Retirement Savings Plans
Cost of Company Matching Contributions	$ 10.9		11.3	11
Benefit Plans Textuals [Abstract]
Matching Contributions Provided Percentage	100.00%
Eligible Compensation Contribution by Employee Percentage	1.00%
Second Matching Contributions Provided Percentage	70.00%
Second Eligible Compensation Contribution by Employee Percentage	5.00%
Noncurrent Regulatory Assets	$ 410.9		404.8
Noncurrent Regulatory Liabilities	2,447.9		2,041.9
Ohio Power Co [Member]
American Electric Power System Retirement Savings Plans
Cost of Company Matching Contributions	$ 7.2		7.3	6.6
Benefit Plans Textuals [Abstract]
Matching Contributions Provided Percentage	100.00%
Eligible Compensation Contribution by Employee Percentage	1.00%
Second Matching Contributions Provided Percentage	70.00%
Second Eligible Compensation Contribution by Employee Percentage	5.00%
Noncurrent Regulatory Assets	$ 293		385.8
Noncurrent Regulatory Liabilities	1,020.9		1,005.2
Public Service Co Of Oklahoma [Member]
American Electric Power System Retirement Savings Plans
Cost of Company Matching Contributions	$ 4.6		4.9	4.6
Benefit Plans Textuals [Abstract]
Matching Contributions Provided Percentage	100.00%
Eligible Compensation Contribution by Employee Percentage	1.00%
Second Matching Contributions Provided Percentage	70.00%
Second Eligible Compensation Contribution by Employee Percentage	5.00%
Noncurrent Regulatory Assets	$ 1,037.4		375
Noncurrent Regulatory Liabilities	835.3		802.2
Southwestern Electric Power Co [Member]
American Electric Power System Retirement Savings Plans
Cost of Company Matching Contributions	$ 6.4		6.7	6.2
Benefit Plans Textuals [Abstract]
Matching Contributions Provided Percentage	100.00%
Eligible Compensation Contribution by Employee Percentage	1.00%
Second Matching Contributions Provided Percentage	70.00%
Second Eligible Compensation Contribution by Employee Percentage	5.00%
Noncurrent Regulatory Assets	$ 1,005.3		403.1
Noncurrent Regulatory Liabilities	806.9		863.4
Pension Plans [Member]
Accumulated Benefit Obligation
Accumulated Benefit Obligation	4,892.2		5,244.2
Underfunded Benefit Obligation
Projected Benefit Obligation	5,187		5,544.5	5,236.8
Accumulated Benefit Obligation	4,892.2		5,244.2
Fair Value of Plan Assets	5,352.9		5,556.6	5,015.4
Estimated Future Benefit Payments and Contributions
Expected Contributions and Payments During 2022	133.6
Components of Net Periodic Benefit Cost
Service Cost	129.2		111.9	95.5
Interest Cost	137.2		167.9	204.4
Expected Return on Plan Assets	(229.7)		(264.9)	(296)
Amortization of Prior Service Cost (Credit)	0		0	0
Amortization of Net Actuarial Loss	101.5		93.7	57.6
Settlements	0		0	0
Net Periodic Benefit Cost (Credit)	138.2		108.6	61.5
Capitalized Portion	(55.7)		(47)	(38.6)
Net Periodic Benefit Cost (Credit) Recognized in Expense	82.5		61.6	22.9
Pension Plans [Member] \| Pension Payments [Member]
Estimated Future Benefit Payments and Contributions
2022	378.1
2023	380.8
2024	381.1
2025	373.7
2026	373.6
Years 2027 to 2031, in Total	1,722.9
Pension Plans [Member] \| AEP Texas Inc. [Member]
Accumulated Benefit Obligation
Accumulated Benefit Obligation	394.7		428.1
Underfunded Benefit Obligation
Projected Benefit Obligation	419.8		453.2	441.2
Accumulated Benefit Obligation	394.7		428.1
Fair Value of Plan Assets	444.9		474	435.1
Estimated Future Benefit Payments and Contributions
Expected Contributions and Payments During 2022	5.9
Components of Net Periodic Benefit Cost
Service Cost	11.8		10	8.6
Interest Cost	11.2		13.9	17.5
Expected Return on Plan Assets	(19.5)		(22.7)	(25.8)
Amortization of Prior Service Cost (Credit)	0		0	0
Amortization of Net Actuarial Loss	8.3		7.8	4.9
Net Periodic Benefit Cost (Credit)	11.8		9	5.2
Capitalized Portion	(6.6)		(5.5)	(4.5)
Net Periodic Benefit Cost (Credit) Recognized in Expense	5.2		3.5	0.7
Pension Plans [Member] \| AEP Texas Inc. [Member] \| Pension Payments [Member]
Estimated Future Benefit Payments and Contributions
2022	36.3
2023	35.9
2024	35.8
2025	34.9
2026	34.7
Years 2027 to 2031, in Total	145.5
Pension Plans [Member] \| Appalachian Power Co [Member]
Accumulated Benefit Obligation
Accumulated Benefit Obligation	597.4		646
Underfunded Benefit Obligation
Projected Benefit Obligation	621.7		670.8	647.2
Accumulated Benefit Obligation	597.4		646
Fair Value of Plan Assets	683.3		701.3	637
Estimated Future Benefit Payments and Contributions
Expected Contributions and Payments During 2022	1.4
Components of Net Periodic Benefit Cost
Service Cost	11.9		10.5	9.4
Interest Cost	16.4		20.3	25.2
Expected Return on Plan Assets	(29.1)		(33.6)	(37.4)
Amortization of Prior Service Cost (Credit)	0		0	0
Amortization of Net Actuarial Loss	12		11.2	7
Net Periodic Benefit Cost (Credit)	11.2		8.4	4.2
Capitalized Portion	(5.2)		(4.5)	(4)
Net Periodic Benefit Cost (Credit) Recognized in Expense	6		3.9	0.2
Pension Plans [Member] \| Appalachian Power Co [Member] \| Pension Payments [Member]
Estimated Future Benefit Payments and Contributions
2022	43.9
2023	45
2024	45.5
2025	43.1
2026	43.5
Years 2027 to 2031, in Total	202.9
Pension Plans [Member] \| Indiana Michigan Power Co [Member]
Accumulated Benefit Obligation
Accumulated Benefit Obligation	576.4		616.6
Underfunded Benefit Obligation
Projected Benefit Obligation	612.1		653.3	616.1
Accumulated Benefit Obligation	576.4		616.6
Fair Value of Plan Assets	681.5		698.1	630.5
Estimated Future Benefit Payments and Contributions
Expected Contributions and Payments During 2022	1.1
Components of Net Periodic Benefit Cost
Service Cost	17.5		15.4	13.4
Interest Cost	16.2		19.7	23.8
Expected Return on Plan Assets	(28.9)		(33.3)	(36.8)
Amortization of Prior Service Cost (Credit)	0		0	0
Amortization of Net Actuarial Loss	11.7		10.8	6.6
Net Periodic Benefit Cost (Credit)	16.5		12.6	7
Capitalized Portion	(4.9)		(4.3)	(3.4)
Net Periodic Benefit Cost (Credit) Recognized in Expense	11.6		8.3	3.6
Pension Plans [Member] \| Indiana Michigan Power Co [Member] \| Pension Payments [Member]
Estimated Future Benefit Payments and Contributions
2022	41.3
2023	40.9
2024	42.1
2025	42
2026	42.2
Years 2027 to 2031, in Total	201.8
Pension Plans [Member] \| Ohio Power Co [Member]
Accumulated Benefit Obligation
Accumulated Benefit Obligation	440.3		479.4
Underfunded Benefit Obligation
Projected Benefit Obligation	470.7		510.3	487.8
Accumulated Benefit Obligation	440.3		479.4
Fair Value of Plan Assets	524.8		543.1	499.1
Components of Net Periodic Benefit Cost
Service Cost	11.4		9.7	7.9
Interest Cost	12.5		15.4	19.1
Expected Return on Plan Assets	(22.3)		(26.3)	(29.3)
Amortization of Prior Service Cost (Credit)	0		0	0
Amortization of Net Actuarial Loss	9.1		8.5	5.3
Net Periodic Benefit Cost (Credit)	10.7		7.3	3
Capitalized Portion	(6.2)		(5)	(3.7)
Net Periodic Benefit Cost (Credit) Recognized in Expense	4.5		2.3	(0.7)
Pension Plans [Member] \| Ohio Power Co [Member] \| Pension Payments [Member]
Estimated Future Benefit Payments and Contributions
2022	35.1
2023	33.7
2024	32.9
2025	33
2026	32.4
Years 2027 to 2031, in Total	149.1
Pension Plans [Member] \| Public Service Co Of Oklahoma [Member]
Accumulated Benefit Obligation
Accumulated Benefit Obligation	233.6		259.9
Underfunded Benefit Obligation
Projected Benefit Obligation	252.6		279.9	267.5
Accumulated Benefit Obligation	233.6		259.9
Fair Value of Plan Assets	286.2		299.8	276.2
Estimated Future Benefit Payments and Contributions
Expected Contributions and Payments During 2022	0.1
Components of Net Periodic Benefit Cost
Service Cost	8		7.3	6.5
Interest Cost	6.7		8.5	10.6
Expected Return on Plan Assets	(12.3)		(14.5)	(16.3)
Amortization of Prior Service Cost (Credit)	0		0	0
Amortization of Net Actuarial Loss	4.9		4.7	2.9
Net Periodic Benefit Cost (Credit)	7.3		6	3.7
Capitalized Portion	(3.4)		(2.8)	(2.4)
Net Periodic Benefit Cost (Credit) Recognized in Expense	3.9		3.2	1.3
Pension Plans [Member] \| Public Service Co Of Oklahoma [Member] \| Pension Payments [Member]
Estimated Future Benefit Payments and Contributions
2022	20.3
2023	21.3
2024	20.5
2025	20.4
2026	20
Years 2027 to 2031, in Total	87.1
Pension Plans [Member] \| Southwestern Electric Power Co [Member]
Accumulated Benefit Obligation
Accumulated Benefit Obligation	292.7		308.5
Underfunded Benefit Obligation
Projected Benefit Obligation	317.7		334.5	314.2
Accumulated Benefit Obligation	292.7		308.5
Fair Value of Plan Assets	308.3		326.9	296.9
Underfunded Status, Projected Benefit Obligation	(9.4)		(7.6)
Estimated Future Benefit Payments and Contributions
Expected Contributions and Payments During 2022	6.5
Components of Net Periodic Benefit Cost
Service Cost	11.2		9.9	8.6
Interest Cost	8.5		10.2	12.4
Expected Return on Plan Assets	(13.5)		(15.7)	(17.7)
Amortization of Prior Service Cost (Credit)	0		0	0
Amortization of Net Actuarial Loss	6.2		5.7	3.4
Net Periodic Benefit Cost (Credit)	12.4		10.1	6.7
Capitalized Portion	(4.1)		(3.4)	(2.9)
Net Periodic Benefit Cost (Credit) Recognized in Expense	8.3		6.7	3.8
Pension Plans [Member] \| Southwestern Electric Power Co [Member] \| Pension Payments [Member]
Estimated Future Benefit Payments and Contributions
2022	24.7
2023	25.4
2024	25.5
2025	25.8
2026	27.3
Years 2027 to 2031, in Total	112.4
Qualified Pension Plans [Member]
Accumulated Benefit Obligation
Accumulated Benefit Obligation	4,822.5		5,171.3
Underfunded Benefit Obligation
Accumulated Benefit Obligation	4,822.5		5,171.3
Qualified Pension Plans [Member] \| AEP Texas Inc. [Member]
Accumulated Benefit Obligation
Accumulated Benefit Obligation	391.4		424.5
Underfunded Benefit Obligation
Accumulated Benefit Obligation	391.4		424.5
Qualified Pension Plans [Member] \| Appalachian Power Co [Member]
Accumulated Benefit Obligation
Accumulated Benefit Obligation	597		645.8
Underfunded Benefit Obligation
Accumulated Benefit Obligation	597		645.8
Qualified Pension Plans [Member] \| Indiana Michigan Power Co [Member]
Accumulated Benefit Obligation
Accumulated Benefit Obligation	575.2		615.8
Underfunded Benefit Obligation
Accumulated Benefit Obligation	575.2		615.8
Qualified Pension Plans [Member] \| Ohio Power Co [Member]
Accumulated Benefit Obligation
Accumulated Benefit Obligation	440		479.2
Underfunded Benefit Obligation
Accumulated Benefit Obligation	440		479.2
Qualified Pension Plans [Member] \| Public Service Co Of Oklahoma [Member]
Accumulated Benefit Obligation
Accumulated Benefit Obligation	232.1		258.3
Underfunded Benefit Obligation
Accumulated Benefit Obligation	232.1		258.3
Qualified Pension Plans [Member] \| Southwestern Electric Power Co [Member]
Accumulated Benefit Obligation
Accumulated Benefit Obligation	291.4		307.1
Underfunded Benefit Obligation
Accumulated Benefit Obligation	291.4		307.1
Nonqualified Pension Plans [Member]
Accumulated Benefit Obligation
Accumulated Benefit Obligation	69.7		72.9
Underfunded Benefit Obligation
Projected Benefit Obligation	78.4		81.4
Accumulated Benefit Obligation	69.7		72.9
Fair Value of Plan Assets	0		0
Underfunded Status, Projected Benefit Obligation	(78.4)		(81.4)
Underfunded Status, Accumulated Benefit Obligation	(69.7)		(72.9)
Nonqualified Pension Plans [Member] \| AEP Texas Inc. [Member]
Accumulated Benefit Obligation
Accumulated Benefit Obligation	3.3		3.6
Underfunded Benefit Obligation
Projected Benefit Obligation	3.6		3.9
Accumulated Benefit Obligation	3.3		3.6
Fair Value of Plan Assets	0		0
Underfunded Status, Projected Benefit Obligation	(3.6)		(3.9)
Underfunded Status, Accumulated Benefit Obligation	(3.3)		(3.6)
Nonqualified Pension Plans [Member] \| Appalachian Power Co [Member]
Accumulated Benefit Obligation
Accumulated Benefit Obligation	0.4		0.2
Underfunded Benefit Obligation
Projected Benefit Obligation	0.8		0.5
Accumulated Benefit Obligation	0.4		0.2
Fair Value of Plan Assets	0		0
Underfunded Status, Projected Benefit Obligation	(0.8)		(0.5)
Underfunded Status, Accumulated Benefit Obligation	(0.4)		(0.2)
Nonqualified Pension Plans [Member] \| Indiana Michigan Power Co [Member]
Accumulated Benefit Obligation
Accumulated Benefit Obligation	1.2		0.8
Underfunded Benefit Obligation
Projected Benefit Obligation	1.9		1.7
Accumulated Benefit Obligation	1.2		0.8
Fair Value of Plan Assets	0		0
Underfunded Status, Projected Benefit Obligation	(1.9)		(1.7)
Underfunded Status, Accumulated Benefit Obligation	(1.2)		(0.8)
Nonqualified Pension Plans [Member] \| Ohio Power Co [Member]
Accumulated Benefit Obligation
Accumulated Benefit Obligation	0.3		0.2
Underfunded Benefit Obligation
Projected Benefit Obligation	0.7		0.6
Accumulated Benefit Obligation	0.3		0.2
Fair Value of Plan Assets	0		0
Underfunded Status, Projected Benefit Obligation	(0.7)		(0.6)
Underfunded Status, Accumulated Benefit Obligation	(0.3)		(0.2)
Nonqualified Pension Plans [Member] \| Public Service Co Of Oklahoma [Member]
Accumulated Benefit Obligation
Accumulated Benefit Obligation	1.5		1.6
Underfunded Benefit Obligation
Projected Benefit Obligation	1.9		2
Accumulated Benefit Obligation	1.5		1.6
Fair Value of Plan Assets	0		0
Underfunded Status, Projected Benefit Obligation	(1.9)		(2)
Underfunded Status, Accumulated Benefit Obligation	(1.5)		(1.6)
Nonqualified Pension Plans [Member] \| Southwestern Electric Power Co [Member]
Accumulated Benefit Obligation
Accumulated Benefit Obligation	1.3		1.4
Underfunded Benefit Obligation
Accumulated Benefit Obligation	1.3		1.4
Fair Value of Plan Assets	0		0
Underfunded Status, Accumulated Benefit Obligation	(1.3)		(1.4)
Other Postretirement Benefit Plans [Member]
Underfunded Benefit Obligation
Projected Benefit Obligation	1,041.3		1,210.9	1,225.4
Fair Value of Plan Assets	2,044.3		1,946.7	1,781.8
Estimated Future Benefit Payments and Contributions
Expected Contributions and Payments During 2022	3.4
Components of Net Periodic Benefit Cost
Service Cost	9.5		10	9.5
Interest Cost	30.5		39.8	50.5
Expected Return on Plan Assets	(91.1)		(95.6)	(93.7)
Amortization of Prior Service Cost (Credit)	(70.9)		(69.8)	(69.1)
Amortization of Net Actuarial Loss	0		5.9	22.1
Settlements	0		0	0
Net Periodic Benefit Cost (Credit)	(122)		(109.7)	(80.7)
Capitalized Portion	(4.1)		(4.2)	(3.8)
Net Periodic Benefit Cost (Credit) Recognized in Expense	(126.1)		(113.9)	(84.5)
Other Postretirement Benefit Plans [Member] \| Benefit Payments [Member]
Estimated Future Benefit Payments and Contributions
2022	123.9
2023	115.4
2024	119.4
2025	117.9
2026	116
Years 2027 to 2031, in Total	545.1
Other Postretirement Benefit Plans [Member] \| Medicare Subsidy Receipts [Member]
Estimated Future Benefit Payments and Contributions
2022	0.2
2023	0.3
2024	0.3
2025	0.3
2026	0.3
Years 2027 to 2031, in Total	1.5
Other Postretirement Benefit Plans [Member] \| AEP Texas Inc. [Member]
Underfunded Benefit Obligation
Projected Benefit Obligation	80.5		96.3	97.8
Fair Value of Plan Assets	168.8		162.3	148.1
Estimated Future Benefit Payments and Contributions
Expected Contributions and Payments During 2022	0.1
Components of Net Periodic Benefit Cost
Service Cost	0.7		0.8	0.8
Interest Cost	2.4		3.2	4
Expected Return on Plan Assets	(7.5)		(8)	(7.8)
Amortization of Prior Service Cost (Credit)	(6)		(5.9)	(5.9)
Amortization of Net Actuarial Loss	0		0.5	1.8
Net Periodic Benefit Cost (Credit)	(10.4)		(9.4)	(7.1)
Capitalized Portion	(0.4)		(0.4)	(0.4)
Net Periodic Benefit Cost (Credit) Recognized in Expense	(10.8)		(9.8)	(7.5)
Other Postretirement Benefit Plans [Member] \| AEP Texas Inc. [Member] \| Benefit Payments [Member]
Estimated Future Benefit Payments and Contributions
2022	9.6
2023	9.1
2024	9.8
2025	9.8
2026	9.8
Years 2027 to 2031, in Total	44.7
Other Postretirement Benefit Plans [Member] \| AEP Texas Inc. [Member] \| Medicare Subsidy Receipts [Member]
Estimated Future Benefit Payments and Contributions
2022	0
2023	0
2024	0
2025	0
2026	0
Years 2027 to 2031, in Total	0
Other Postretirement Benefit Plans [Member] \| Appalachian Power Co [Member]
Underfunded Benefit Obligation
Projected Benefit Obligation	167.3		198.2	203.5
Fair Value of Plan Assets	302.3		293	271
Estimated Future Benefit Payments and Contributions
Expected Contributions and Payments During 2022	1.8
Components of Net Periodic Benefit Cost
Service Cost	1		1	1
Interest Cost	4.9		6.6	8.7
Expected Return on Plan Assets	(13.5)		(14.4)	(14.6)
Amortization of Prior Service Cost (Credit)	(10.3)		(10.2)	(10.1)
Amortization of Net Actuarial Loss	0		0.9	3.7
Net Periodic Benefit Cost (Credit)	(17.9)		(16.1)	(11.3)
Capitalized Portion	(0.4)		(0.4)	(0.4)
Net Periodic Benefit Cost (Credit) Recognized in Expense	(18.3)		(16.5)	(11.7)
Other Postretirement Benefit Plans [Member] \| Appalachian Power Co [Member] \| Benefit Payments [Member]
Estimated Future Benefit Payments and Contributions
2022	20.5
2023	19.1
2024	19.7
2025	19.2
2026	18.8
Years 2027 to 2031, in Total	87.5
Other Postretirement Benefit Plans [Member] \| Appalachian Power Co [Member] \| Medicare Subsidy Receipts [Member]
Estimated Future Benefit Payments and Contributions
2022	0.1
2023	0.1
2024	0.1
2025	0.1
2026	0.1
Years 2027 to 2031, in Total	0.5
Other Postretirement Benefit Plans [Member] \| Indiana Michigan Power Co [Member]
Underfunded Benefit Obligation
Projected Benefit Obligation	118.6		141.4	142.9
Fair Value of Plan Assets	248.7		238.2	216.3
Estimated Future Benefit Payments and Contributions
Expected Contributions and Payments During 2022	0
Components of Net Periodic Benefit Cost
Service Cost	1.3		1.4	1.4
Interest Cost	3.5		4.7	5.8
Expected Return on Plan Assets	(11.1)		(11.7)	(11.4)
Amortization of Prior Service Cost (Credit)	(9.6)		(9.5)	(9.4)
Amortization of Net Actuarial Loss	0		0.7	2.7
Net Periodic Benefit Cost (Credit)	(15.9)		(14.4)	(10.9)
Capitalized Portion	(0.4)		(0.4)	(0.4)
Net Periodic Benefit Cost (Credit) Recognized in Expense	(16.3)		(14.8)	(11.3)
Other Postretirement Benefit Plans [Member] \| Indiana Michigan Power Co [Member] \| Benefit Payments [Member]
Estimated Future Benefit Payments and Contributions
2022	15.2
2023	14.1
2024	14.7
2025	14.5
2026	14.4
Years 2027 to 2031, in Total	66.8
Other Postretirement Benefit Plans [Member] \| Indiana Michigan Power Co [Member] \| Medicare Subsidy Receipts [Member]
Estimated Future Benefit Payments and Contributions
2022	0
2023	0
2024	0
2025	0
2026	0
Years 2027 to 2031, in Total	0
Other Postretirement Benefit Plans [Member] \| Ohio Power Co [Member]
Underfunded Benefit Obligation
Projected Benefit Obligation	104.9		126.4	130.2
Fair Value of Plan Assets	220		213	197.1
Components of Net Periodic Benefit Cost
Service Cost	0.8		0.9	0.8
Interest Cost	3		4.2	5.5
Expected Return on Plan Assets	(9.7)		(10.5)	(10.8)
Amortization of Prior Service Cost (Credit)	(7.2)		(7)	(6.9)
Amortization of Net Actuarial Loss	0		0.7	2.5
Net Periodic Benefit Cost (Credit)	(13.1)		(11.7)	(8.9)
Capitalized Portion	(0.4)		(0.5)	(0.4)
Net Periodic Benefit Cost (Credit) Recognized in Expense	(13.5)		(12.2)	(9.3)
Other Postretirement Benefit Plans [Member] \| Ohio Power Co [Member] \| Benefit Payments [Member]
Estimated Future Benefit Payments and Contributions
2022	13.5
2023	12.5
2024	12.9
2025	12.7
2026	12.3
Years 2027 to 2031, in Total	57.1
Other Postretirement Benefit Plans [Member] \| Ohio Power Co [Member] \| Medicare Subsidy Receipts [Member]
Estimated Future Benefit Payments and Contributions
2022	0
2023	0
2024	0
2025	0
2026	0
Years 2027 to 2031, in Total	0
Other Postretirement Benefit Plans [Member] \| Public Service Co Of Oklahoma [Member]
Underfunded Benefit Obligation
Projected Benefit Obligation	54.4		64	64.7
Fair Value of Plan Assets	114		107.8	98
Estimated Future Benefit Payments and Contributions
Expected Contributions and Payments During 2022	0
Components of Net Periodic Benefit Cost
Service Cost	0.6		0.7	0.6
Interest Cost	1.6		2.1	2.6
Expected Return on Plan Assets	(5)		(5.2)	(5.1)
Amortization of Prior Service Cost (Credit)	(4.4)		(4.4)	(4.3)
Amortization of Net Actuarial Loss	0		0.3	1.2
Net Periodic Benefit Cost (Credit)	(7.2)		(6.5)	(5)
Capitalized Portion	(0.3)		(0.3)	(0.2)
Net Periodic Benefit Cost (Credit) Recognized in Expense	(7.5)		(6.8)	(5.2)
Other Postretirement Benefit Plans [Member] \| Public Service Co Of Oklahoma [Member] \| Benefit Payments [Member]
Estimated Future Benefit Payments and Contributions
2022	7.1
2023	6.7
2024	7
2025	7
2026	6.8
Years 2027 to 2031, in Total	29.7
Other Postretirement Benefit Plans [Member] \| Public Service Co Of Oklahoma [Member] \| Medicare Subsidy Receipts [Member]
Estimated Future Benefit Payments and Contributions
2022	0
2023	0
2024	0
2025	0
2026	0
Years 2027 to 2031, in Total	0
Other Postretirement Benefit Plans [Member] \| Southwestern Electric Power Co [Member]
Underfunded Benefit Obligation
Projected Benefit Obligation	65.2		77.1	77.4
Fair Value of Plan Assets	136.6		129.9	117.2
Estimated Future Benefit Payments and Contributions
Expected Contributions and Payments During 2022	0
Components of Net Periodic Benefit Cost
Service Cost	0.8		0.8	0.8
Interest Cost	1.9		2.5	3.1
Expected Return on Plan Assets	(6.1)		(6.3)	(5.9)
Amortization of Prior Service Cost (Credit)	(5.3)		(5.2)	(5.2)
Amortization of Net Actuarial Loss	0		0.4	1.4
Net Periodic Benefit Cost (Credit)	(8.7)		(7.8)	(5.8)
Capitalized Portion	(0.3)		(0.3)	(0.3)
Net Periodic Benefit Cost (Credit) Recognized in Expense	(9)		$ (8.1)	$ (6.1)
Other Postretirement Benefit Plans [Member] \| Southwestern Electric Power Co [Member] \| Benefit Payments [Member]
Estimated Future Benefit Payments and Contributions
2022	7.7
2023	7.4
2024	7.9
2025	8
2026	7.9
Years 2027 to 2031, in Total	37.1
Other Postretirement Benefit Plans [Member] \| Southwestern Electric Power Co [Member] \| Medicare Subsidy Receipts [Member]
Estimated Future Benefit Payments and Contributions
2022	0
2023	0
2024	0
2025	0
2026	0
Years 2027 to 2031, in Total	$ 0

[1]	2021 amounts exclude $485 million of regulatory assets classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[2]	2021 amounts exclude $148 million of regulatory liabilities classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.

Business Segments (Details)

Business Segments (Details) - USD ($) $ in Millions		12 Months Ended
Business Segments (Details) - USD ($) $ in Millions		Dec. 31, 2021		Dec. 31, 2020		Dec. 31, 2019
Reportable Segment Information
Revenue from Contracts with Customers		$ 16,792		$ 14,918.5		$ 15,561.4
Sales to AEP Affiliates		0		0		0
Total Revenues		16,792		14,918.5		15,561.4
Asset Impairments and Other Related Charges		11.6		0		156.4
Utilities Operating Expense, Depreciation and Amortization		2,825.7		2,682.8		2,514.5
Allowance for Equity Funds Used During Construction		139.7		148.1		168.4
Interest Expense		1,199.1		1,165.7		1,072.5
Income Tax Expense (Benefit)		115.5		40.5		(12.9)
Equity Earnings (Loss) of Unconsolidated Subsidiaries		91.7		91.1		72.1
Net Income (Loss)		2,488.1		2,196.7		1,919.8
Gross Property Additions		6,426.8		6,246.3		6,969.8
Balance Sheet Information
Property, Plant and Equipment, Gross, Period Increase (Decrease)		86,806.4		84,313
Accumulated Depreciation and Amortization		20,805.1		20,411.4
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		66,001.3	[1]	63,901.6
Total Assets		87,668.7	[2]	80,757.2		75,892.3
Investments in Equity Method Investees		1,447.5		1,406.3		1,356.6
Affiliated Long Term Debt Current						0
Long-term Debt Due Within One Year		2,153.8		2,086.1		1,598.7
Long-term Debt - Affiliated		0		0		0
Long-term Debt		31,300.7		28,986.4		25,126.8
Total Long-term Debt Outstanding		33,454.5	[3],[4],[5]	31,072.5		26,725.5
AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Contracts with Customers		1,410.9		1,232.7		1,042.1
Sales to AEP Affiliates		1,153.9		896.3		806.7
Total Revenues		1,469.3		1,145.7		1,021.4
Utilities Operating Expense, Depreciation and Amortization		297.3		249		176
Interest Income		0.5		2.4		3
Allowance for Equity Funds Used During Construction		67.2		74		84.3
Interest Expense		141.2		127.8		97.4
Income Tax Expense (Benefit)		144.1		106.7		117.4
Net Income (Loss)		591.7		423.4		439.7
Gross Property Additions		1,442.7		1,621.9		1,419.5
Balance Sheet Information
Property, Plant and Equipment, Gross, Period Increase (Decrease)		12,708.5		11,345.6
Accumulated Depreciation and Amortization		772.8		572.8
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		11,935.7	[1]	10,772.8
Notes Receivable, Related Parties		0		0
Total Assets		12,524.4	[6]	11,246		9,890.8
Long-term Debt Due Within One Year		104		50
Long-term Debt		4,239.9		3,898.5
Total Long-term Debt Outstanding		4,343.9		3,948.5		3,427.3
Vertically Integrated Utilities [Member]
Reportable Segment Information
Revenue from Contracts with Customers		9,852.2		8,753.2		9,245.7
Transmission and Distribution Utilities Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		4,464.1		4,238.7		4,319
Transmission [Member] \| AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Contracts with Customers		315.1		248.8		214.6
Generation and Marketing Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		2,108.3		1,621		1,721.8
Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		367.4		305.6		274.9
Total Revenues		227.6	[7],[8]	61.5	[9],[10]	61.7	[11],[12]
Other Revenues [Member] \| AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0.3		0.6		0.1
Total Revenues		0	[13]	0	[14]	0	[15]
Reconciling Adjustments [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0		0		0
Sales to AEP Affiliates		(1,461.5)		(1,328)		(1,314.8)
Total Revenues		(1,461.5)		(1,328)		(1,314.8)
Asset Impairments and Other Related Charges		0				0
Utilities Operating Expense, Depreciation and Amortization		0		0		24.5	[16]
Interest Expense		(18.7)		(42.1)		(66.1)	[16]
Income Tax Expense (Benefit)		0		0		0
Equity Earnings (Loss) of Unconsolidated Subsidiaries		0		0		0
Net Income (Loss)		0		0		0
Gross Property Additions		(29.2)		(15.3)		(20.4)
Balance Sheet Information
Property, Plant and Equipment, Gross, Period Increase (Decrease)		0		0
Accumulated Depreciation and Amortization		0		0
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		0		0
Total Assets	[17]	(4,409.1)		(3,961.7)		(3,801.3)	[16]
Investments in Equity Method Investees		0		0		0
Affiliated Long Term Debt Current						(20)
Long-term Debt Due Within One Year		0		0		0
Long-term Debt - Affiliated		(65)		(65)		(39)
Long-term Debt		0		0		0
Total Long-term Debt Outstanding		(65)		(65)		(59)
Reconciling Adjustments [Member] \| AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0		0		0
Sales to AEP Affiliates		0		0		0
Total Revenues		0		0		0
Utilities Operating Expense, Depreciation and Amortization		0		0		0
Interest Income	[18]	(157.7)		(148.1)		(122.1)
Allowance for Equity Funds Used During Construction		0		0		0
Interest Expense	[18]	(157.7)		(148.1)		(122.1)
Income Tax Expense (Benefit)		0		0		0
Net Income (Loss)		0		0		0
Gross Property Additions		0		0		0
Balance Sheet Information
Property, Plant and Equipment, Gross, Period Increase (Decrease)		0		0
Accumulated Depreciation and Amortization		0		0
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		0		0
Notes Receivable, Related Parties	[19]	(4,343.9)		(3,948.5)
Total Assets	[20]	(4,429.4)	[6]	(4,023.1)		(3,493.3)
Total Long-term Debt Outstanding	[19]	(4,390)		(3,990)		(3,465)
Reconciling Adjustments [Member] \| Other Revenues [Member]
Reportable Segment Information
Total Revenues		(10.7)	[7],[8]	(74.9)	[9],[10]	(139.3)	[11],[12]
Reconciling Adjustments [Member] \| Other Revenues [Member] \| AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0		0		0
Vertically Integrated Utilities [Member]
Reportable Segment Information
Sales to AEP Affiliates		146.3		126.2		121.4
Total Revenues		9,998.5		8,879.4		9,367.1
Asset Impairments and Other Related Charges		11.6				92.9
Utilities Operating Expense, Depreciation and Amortization		1,747.6		1,600.5		1,447
Interest Expense		574.2		565		568.3
Income Tax Expense (Benefit)		(11.2)		(7)		(97.7)
Equity Earnings (Loss) of Unconsolidated Subsidiaries		3.4		2.9		3
Net Income (Loss)		1,116.7		1,064.5		985.6
Gross Property Additions		2,963.1		2,291.2		2,437.4
Balance Sheet Information
Property, Plant and Equipment, Gross, Period Increase (Decrease)		48,368.9		49,023.3
Accumulated Depreciation and Amortization		15,471.6		15,586.2
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		32,897.3		33,437.1
Total Assets		46,974.2	[2]	42,752.7		41,228.8
Investments in Equity Method Investees		33.5		37.1		41.7
Affiliated Long Term Debt Current						20
Long-term Debt Due Within One Year		1,022.4		1,034.6		704.7
Long-term Debt - Affiliated		65		65		39
Long-term Debt		12,964.4		12,375.6		12,162
Total Long-term Debt Outstanding		14,051.8		13,475.2		12,925.7
Vertically Integrated Utilities [Member] \| Vertically Integrated Utilities [Member]
Reportable Segment Information
Revenue from Contracts with Customers		9,852.2		8,753.2		9,245.7
Vertically Integrated Utilities [Member] \| Other Revenues [Member]
Reportable Segment Information
Total Revenues		(0.5)	[7],[8]	0	[9],[10]	0	[11],[12]
Transmission and Distribution Companies [Member]
Reportable Segment Information
Sales to AEP Affiliates		28.8		107.2		163.5
Total Revenues		4,492.9		4,345.9		4,482.5
Asset Impairments and Other Related Charges		0				32.5
Utilities Operating Expense, Depreciation and Amortization		690.3		751.1		789.5
Interest Expense		300.9		289.2		243.3
Income Tax Expense (Benefit)		77.5		29.7		(25.2)
Equity Earnings (Loss) of Unconsolidated Subsidiaries		0		0		0
Net Income (Loss)		543.4		496.4		451
Gross Property Additions		1,766		2,108.1		2,074.3
Balance Sheet Information
Property, Plant and Equipment, Gross, Period Increase (Decrease)		22,700.7		21,145
Accumulated Depreciation and Amortization		4,102.4		3,879.3
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		18,598.3		17,265.7
Total Assets		21,120.2		19,765.9		18,757.5
Investments in Equity Method Investees		2.5		2.1		2.5
Affiliated Long Term Debt Current						0
Long-term Debt Due Within One Year		716.1		588.8		392.2
Long-term Debt - Affiliated		0		0		0
Long-term Debt		7,433.2		6,661.9		6,248.1
Total Long-term Debt Outstanding		8,149.3		7,250.7		6,640.3
Transmission and Distribution Companies [Member] \| Transmission and Distribution Utilities Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		4,464.1		4,238.7		4,319
Transmission and Distribution Companies [Member] \| Other Revenues [Member]
Reportable Segment Information
Total Revenues		19	[7],[8]	83	[9],[10]	150	[11],[12]
AEP Transmission Holdco
Reportable Segment Information
Sales to AEP Affiliates		1,175.1		901.4		813
Total Revenues		1,526.2		1,198.8		1,073.2
Asset Impairments and Other Related Charges		0				0
Utilities Operating Expense, Depreciation and Amortization		306		257.6		183.4
Interest Expense		146.3		133.2		103.3
Income Tax Expense (Benefit)		159.6		130.8		136.2
Equity Earnings (Loss) of Unconsolidated Subsidiaries		75		82.4		72.8
Net Income (Loss)		682		508.5		520.1
Gross Property Additions		1,468.6		1,649.3		1,458.9
Balance Sheet Information
Property, Plant and Equipment, Gross, Period Increase (Decrease)		13,213		11,827.2
Accumulated Depreciation and Amortization		801.8		595.7
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		12,411.2		11,231.5
Total Assets		13,873.3	[2]	12,627.3		11,143.5
Investments in Equity Method Investees		830.4		831.3		787.5
Affiliated Long Term Debt Current						0
Long-term Debt Due Within One Year		106.4		52.3		0
Long-term Debt - Affiliated		0		0		0
Long-term Debt		4,442.7		4,075.7		3,593.8
Total Long-term Debt Outstanding		4,549.1		4,128		3,593.8
AEP Transmission Holdco \| Transmission [Member]
Reportable Segment Information
Revenue from Contracts with Customers		351.1		297.4		260.2
Generation and Marketing [Member]
Reportable Segment Information
Sales to AEP Affiliates		55.4		104.6		135.8
Total Revenues		2,163.7		1,725.6		1,857.6
Asset Impairments and Other Related Charges		0				31
Utilities Operating Expense, Depreciation and Amortization		80.9		72.8		69.5
Interest Expense		15.6		24		30
Income Tax Expense (Benefit)		(48.8)		(108)		(53.8)
Equity Earnings (Loss) of Unconsolidated Subsidiaries		(10.6)		3.2		(3.8)
Net Income (Loss)		210.2		216.9		104.1
Gross Property Additions		232.8		197		1,005.1
Balance Sheet Information
Property, Plant and Equipment, Gross, Period Increase (Decrease)		2,105.4		1,910.2
Accumulated Depreciation and Amortization		241		166.1
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		1,864.4		1,744.1
Total Assets		4,263.6		3,585.9		3,123.8
Investments in Equity Method Investees		487.8		467		459.5
Affiliated Long Term Debt Current						0
Long-term Debt Due Within One Year		0		0		0
Long-term Debt - Affiliated		0		0		0
Long-term Debt		0		0		0
Total Long-term Debt Outstanding		0		0		0
Generation and Marketing [Member] \| Generation and Marketing Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		2,108.3		1,621		1,721.8
Generation and Marketing [Member] \| Other Revenues [Member]
Reportable Segment Information
Total Revenues		209.1	[7],[8]	43.6	[9],[10]	59.9	[11],[12]
All Other [Member]
Reportable Segment Information
Sales to AEP Affiliates	[21]	55.9		88.6		81.1
Total Revenues	[21]	72.2		96.8		95.8
Asset Impairments and Other Related Charges	[21]	0				0
Utilities Operating Expense, Depreciation and Amortization	[21]	0.9		0.8		0.6
Interest Expense	[21]	180.8		196.4		193.7
Income Tax Expense (Benefit)	[21]	(61.6)		(5)		27.6
Equity Earnings (Loss) of Unconsolidated Subsidiaries	[21]	23.9		2.6		0.1
Net Income (Loss)	[21]	(64.2)		(89.6)		(141)
Gross Property Additions	[21]	25.5		16		14.5
Balance Sheet Information
Property, Plant and Equipment, Gross, Period Increase (Decrease)	[21]	418.4		407.3
Accumulated Depreciation and Amortization	[21]	188.3		184.1
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET	[21]	230.1		223.2
Total Assets	[21],[22]	5,846.5		5,987.1		5,440
Investments in Equity Method Investees	[21]	93.3		68.8		65.4
Affiliated Long Term Debt Current	[21]					0
Long-term Debt Due Within One Year	[21],[23]	308.9		410.4		501.8
Long-term Debt - Affiliated	[21]	0		0		0
Long-term Debt	[21],[23]	6,460.4		5,873.2		3,122.9
Total Long-term Debt Outstanding	[21]	6,769.3		6,283.6		3,624.7
All Other [Member] \| Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers	[21]	16.3		8.2		14.7
Total Revenues		10.7	[7],[8]	9.8	[9],[10]	(8.9)	[11],[12]
State Transcos [Member] \| AEP Transmission Co [Member]
Reportable Segment Information
Sales to AEP Affiliates		1,153.9		896.3		806.7
Total Revenues		1,469.3		1,145.7		1,021.4
Utilities Operating Expense, Depreciation and Amortization		297.3		249		176
Interest Income		0.1		0.9		1.3
Allowance for Equity Funds Used During Construction		67.2		74		84.3
Interest Expense		141.2		127.8		97.4
Income Tax Expense (Benefit)		144.1		106.5		117.1
Net Income (Loss)		591.5		422.3		438.6
Gross Property Additions		1,442.7		1,621.9		1,419.5
Balance Sheet Information
Property, Plant and Equipment, Gross, Period Increase (Decrease)		12,708.5		11,345.6
Accumulated Depreciation and Amortization		772.8		572.8
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		11,935.7		10,772.8
Notes Receivable, Related Parties		0		0
Total Assets		12,564.3	[6]	11,185.1		9,865
Total Long-term Debt Outstanding		4,390		3,990		3,465
State Transcos [Member] \| Transmission [Member] \| AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Contracts with Customers		315.1		248.8		214.6
State Transcos [Member] \| Other Revenues [Member] \| AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0.3		0.6		0.1
AEPTCo Parent [Member] \| AEP Transmission Co [Member]
Reportable Segment Information
Sales to AEP Affiliates		0		0		0
Total Revenues		0		0		0
Utilities Operating Expense, Depreciation and Amortization		0		0		0
Interest Income		158.1		149.6		123.8
Allowance for Equity Funds Used During Construction		0		0		0
Interest Expense		157.7		148.1		122.1
Income Tax Expense (Benefit)		0		0.2		0.3
Net Income (Loss)	[24]	0.2		1.1		1.1
Gross Property Additions		0		0		0
Balance Sheet Information
Property, Plant and Equipment, Gross, Period Increase (Decrease)		0		0
Accumulated Depreciation and Amortization		0		0
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		0		0
Notes Receivable, Related Parties		4,343.9		3,948.5
Total Assets	[25]	4,389.5	[6]	4,084		3,519.1
Total Long-term Debt Outstanding		4,343.9		3,948.5		3,427.3
AEPTCo Parent [Member] \| Transmission [Member] \| AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0		0		0
AEPTCo Parent [Member] \| Other Revenues [Member] \| AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Contracts with Customers		$ 0		$ 0		$ 0

[1]	Amount excludes $2.3 billion and $165 million for AEP and AEPTCo, respectively, of Property, Plant and Equipment - Net classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[2]	Amount includes Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[3]	2021 amount excludes $1.1 billion of Total Long-term Debt Outstanding classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[4]	Amount excludes $1.1 billion of Total Long-term Debt Outstanding classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information
[5]	The 2021 book value amount excludes Long-term Debt of $1.1 billion classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[6]	Amount includes Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[7]	Amounts include affiliated and nonaffiliated revenues.
[8]	Generation & Marketing includes economic hedge activity.
[9]	Amounts include affiliated and nonaffiliated revenues.
[10]	Generation & Marketing includes economic hedge activity.
[11]	Amounts include affiliated and nonaffiliated revenues.
[12]	Generation & Marketing includes economic hedge activity.
[13]	Amounts include affiliated and nonaffiliated revenues.
[14]	Amounts include affiliated and nonaffiliated revenues.
[15]	Amounts include affiliated and nonaffiliated revenues.
[16]	Includes eliminations due to an intercompany finance lease.
[17]	Reconciling Adjustments for Total Assets primarily include elimination of intercompany advances to affiliates and intercompany accounts receivable.
[18]	Elimination of intercompany interest income/interest expense on affiliated debt arrangement.
[19]	Elimination of intercompany debt.
[20]	Primarily relates to elimination of Notes Receivable from the State Transcos.
[21]	Corporate and Other primarily includes the purchasing of receivables from certain AEP utility subsidiaries. This segment also includes Parent’s guarantee revenue received from affiliates, investment income, interest income, interest expense and other nonallocated costs.
[22]	Includes elimination of AEP Parent’s investments in wholly-owned subsidiary companies.
[23]	Amounts reflect the impact of fair value hedge accounting. See “Accounting for Fair Value Hedging Strategies” section of Note 10 for additional information.
[24]	Includes elimination of AEPTCo Parent’s equity earnings in the State Transcos.
[25]	Includes elimination of AEPTCo Parent’s investments in the State Transcos.

Derivatives and Hedging (Detail

Derivatives and Hedging (Details) gal in Millions, MWh in Millions, MMBTU in Millions		12 Months Ended
		Dec. 31, 2021USD ($)MWhMMBTUgal		Dec. 31, 2020USD ($)MWhMMBTUgal		Dec. 31, 2019USD ($)
Cash Collateral Netting
Cash Collateral Received Netted Against Risk Management Assets		$ 263,000,000		$ 3,000,000
Cash Collateral Paid Netted Against Risk Management Liabilities		3,000,000		7,000,000
Fair Value of Derivative Instruments
Current Risk Management Assets		194,400,000		94,700,000
Derivative Asset, Noncurrent		267,000,000		242,200,000
Total Assets		461,400,000		336,900,000
Current Risk Management Liabilities		75,400,000		78,800,000
Derivative Liability, Noncurrent		230,300,000		232,800,000
Total Liabilities		305,700,000		311,600,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		324,000,000		116,900,000		$ 125,000,000
Impact of Fair Value Hedges on the Balance Sheet
Carrying Amount of Hedged Asset (Liability)	[1],[2]	(952,300,000)		(995,900,000)
Cumulative Fair Value Hedging Adjustment in the Carrying Amount of the Hedged Asset (Liability)	[1],[2]	(8,500,000)		(51,700,000)
Impact of Cash Flow Hedges on the Balance Sheet
Gain (Loss) on Fair Value Hedging Instruments	[3]	(35,500,000)		41,100,000		31,900,000
Gain (Loss) on Fair Value Portion of Long Term Debt	[3]	35,500,000		(41,100,000)		(31,900,000)
Collateral Triggering Events
Liabilities for Contracts with Cross Default Provisions Prior to Contractural Netting Arrangements		159,500,000		188,400,000
Amount of Cash Collateral Posted		0		0
Additional Settlement Liability if Cross Default Provision is Triggered		115,400,000		169,200,000
Derivatives and Hedging (Textuals)
Hedged Liability, Discontinued Fair Value Hedge, Cumulative Increase (Decrease)		(46,000,000)		(53,000,000)
Notional Amount of a Discontinued Hedge		500,000,000
Deferred (Gain) Loss on Discontinuation of Fair Value Hedge		57,000,000
Credit Downgrade Trigger Exposure		9,000,000
Assets Held for Sale		2,919,700,000		0
Liabilities Held for Sale		1,880,900,000		0
Investment in ChargePoint
Derivatives and Hedging (Textuals)
Equity Method Investments, Fair Value Disclosure		29,000,000
Unrealized Gain (Loss) on Investments		26,000,000
AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		2,000,000		(1,000,000)		300,000
AEP Transmission Co [Member]
Derivatives and Hedging (Textuals)
Assets Held for Sale		167,900,000		0
Liabilities Held for Sale		27,600,000		0
Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		42,000,000		22,400,000
Total Assets				22,500,000
Total Liabilities				4,700,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		55,300,000		21,300,000		4,100,000
Collateral Triggering Events
Liabilities for Contracts with Cross Default Provisions Prior to Contractural Netting Arrangements		500,000		4,300,000
Amount of Cash Collateral Posted		0		0
Additional Settlement Liability if Cross Default Provision is Triggered		300,000		3,500,000
Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		3,300,000		3,600,000
Current Risk Management Liabilities		5,000,000		100,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(18,200,000)		12,000,000		25,200,000
Collateral Triggering Events
Liabilities for Contracts with Cross Default Provisions Prior to Contractural Netting Arrangements		300,000		500,000
Amount of Cash Collateral Posted		0		0
Additional Settlement Liability if Cross Default Provision is Triggered		200,000		100,000
Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Liabilities		6,700,000		8,700,000
Derivative Liability, Noncurrent		85,800,000		101,600,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		11,100,000		5,000,000		6,000,000
Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		12,100,000		10,300,000
Current Risk Management Liabilities		3,700,000		0
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		46,000,000		38,600,000		35,600,000
Collateral Triggering Events
Liabilities for Contracts with Cross Default Provisions Prior to Contractural Netting Arrangements		1,700,000
Amount of Cash Collateral Posted		0
Additional Settlement Liability if Cross Default Provision is Triggered		1,700,000
Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		9,800,000		3,200,000
Current Risk Management Liabilities		2,100,000		700,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		41,500,000		21,000,000		25,000,000
Collateral Triggering Events
Liabilities for Contracts with Cross Default Provisions Prior to Contractural Netting Arrangements		2,700,000		1,800,000
Amount of Cash Collateral Posted		0		0
Additional Settlement Liability if Cross Default Provision is Triggered		2,700,000		1,800,000
Risk Management Contracts [Member]
Fair Value of Derivative Instruments
Total Assets	[5]	239,800,000	[4],[6]	322,100,000	[7]
Total Liabilities	[5]	254,700,000	[6],[8]	218,900,000	[7]
Derivatives and Hedging (Textuals)
Assets Held for Sale		6,000,000
Liabilities Held for Sale		100,000
Risk Management Contracts [Member] \| AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Total Assets		0	[5]	0
Risk Management Contracts [Member] \| Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[5],[9]	42,000,000		20,100,000
Total Liabilities	[5],[9]	800,000		1,300,000
Risk Management Contracts [Member] \| Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[5],[9]	3,300,000		3,700,000
Total Liabilities	[5],[9]	5,000,000		200,000
Risk Management Contracts [Member] \| Ohio Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[5],[9]	0		0
Total Liabilities	[5],[9]	92,500,000		110,300,000
Risk Management Contracts [Member] \| Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Total Assets	[5],[9]	12,100,000		10,300,000
Total Liabilities	[5],[9]	3,700,000
Risk Management Contracts [Member] \| Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[5],[9]	10,900,000		3,200,000
Total Liabilities	[5],[9]	2,100,000		1,700,000
Commodity [Member]
Impact of Cash Flow Hedges on the Balance Sheet
AOCI Gain (Loss) Net of Tax		163,700,000		(60,600,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		$ 106,700,000		(27,100,000)
Derivatives and Hedging (Textuals)
Maximum Length of Time Hedged in Price Risk Cash Flow Hedge		111 months
Cross Default Provisions Maximum Third Party Obligation Amount		$ 50,000,000
Commodity [Member] \| Risk Management Contracts [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[11]	513,400,000	[10]	239,100,000
Derivative Asset, Noncurrent	[11]	370,500,000		275,900,000
Total Assets	[11]	883,900,000		515,000,000
Current Risk Management Liabilities	[11]	395,700,000	[12]	193,000,000
Derivative Liability, Noncurrent	[11]	243,900,000		222,200,000
Total Liabilities	[11]	639,600,000		415,200,000
Total MTM Derivative Contract Net Assets (Liabilities)	[11]	244,300,000		99,800,000
Commodity [Member] \| Risk Management Contracts [Member] \| AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[11]	600,000		400,000
Derivative Asset, Noncurrent	[11]	0		0
Total Assets	[11]	600,000		400,000
Current Risk Management Liabilities	[11]	0		0
Derivative Liability, Noncurrent	[11]	0		0
Total Liabilities	[11]	0		0
Total MTM Derivative Contract Net Assets (Liabilities)	[11]	600,000		400,000
Commodity [Member] \| Risk Management Contracts [Member] \| Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[11]	47,500,000		38,800,000
Derivative Asset, Noncurrent	[11]	200,000		700,000
Total Assets	[11]	47,700,000		39,500,000
Current Risk Management Liabilities	[11]	7,200,000		19,700,000
Derivative Liability, Noncurrent	[11]	200,000		600,000
Total Liabilities	[11]	7,400,000		20,300,000
Total MTM Derivative Contract Net Assets (Liabilities)	[11]	40,300,000		19,200,000
Commodity [Member] \| Risk Management Contracts [Member] \| Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[11]	11,100,000		17,200,000
Derivative Asset, Noncurrent	[11]	200,000		500,000
Total Assets	[11]	11,300,000		17,700,000
Current Risk Management Liabilities	[11]	14,800,000		12,100,000
Derivative Liability, Noncurrent	[11]	200,000		400,000
Total Liabilities	[11]	15,000,000		12,500,000
Total MTM Derivative Contract Net Assets (Liabilities)	[11]	(3,700,000)		5,200,000
Commodity [Member] \| Risk Management Contracts [Member] \| Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[11]	500,000		300,000
Derivative Asset, Noncurrent	[11]	0		0
Total Assets	[11]	500,000		300,000
Current Risk Management Liabilities	[11]	6,700,000		8,700,000
Derivative Liability, Noncurrent	[11]	85,800,000		101,600,000
Total Liabilities	[11]	92,500,000		110,300,000
Total MTM Derivative Contract Net Assets (Liabilities)	[11]	(92,000,000)		(110,000,000)
Commodity [Member] \| Risk Management Contracts [Member] \| Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[11]	12,400,000		10,500,000
Derivative Asset, Noncurrent	[11]	0		0
Total Assets	[11]	12,400,000		10,500,000
Current Risk Management Liabilities	[11]	3,700,000		0
Derivative Liability, Noncurrent	[11]	0		0
Total Liabilities	[11]	3,700,000		0
Total MTM Derivative Contract Net Assets (Liabilities)	[11]	8,700,000		10,500,000
Commodity [Member] \| Risk Management Contracts [Member] \| Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[11]	10,100,000		3,400,000
Derivative Asset, Noncurrent	[11]	1,100,000		0
Total Assets	[11]	11,200,000		3,400,000
Current Risk Management Liabilities	[11]	2,100,000		700,000
Derivative Liability, Noncurrent	[11]	0		1,000,000
Total Liabilities	[11]	2,100,000		1,700,000
Total MTM Derivative Contract Net Assets (Liabilities)	[11]	9,100,000		1,700,000
Commodity [Member] \| Hedging Contracts [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[11]	176,000,000		21,100,000
Derivative Asset, Noncurrent	[11]	89,100,000		18,000,000
Total Assets	[11]	265,100,000		39,100,000
Current Risk Management Liabilities	[11]	40,900,000		54,400,000
Derivative Liability, Noncurrent	[11]	16,700,000		60,100,000
Total Liabilities	[11]	57,600,000		114,500,000
Total MTM Derivative Contract Net Assets (Liabilities)	[11]	207,500,000		(75,400,000)
Interest Rate [Member]
Commodity
Derivative, Notional Amount		950,000,000		1,150,000,000
Impact of Cash Flow Hedges on the Balance Sheet
AOCI Gain (Loss) Net of Tax		(21,300,000)		(47,500,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		$ (3,300,000)		(5,700,000)
Derivatives and Hedging (Textuals)
Maximum Length of Time Hedged in Price Risk Cash Flow Hedge		108 months
Interest Rate [Member] \| AEP Texas Inc. [Member]
Commodity
Derivative, Notional Amount		$ 0		0
Impact of Cash Flow Hedges on the Balance Sheet
AOCI Gain (Loss) Net of Tax		(1,300,000)		(2,300,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		(1,100,000)		(1,100,000)
Interest Rate [Member] \| Appalachian Power Co [Member]
Commodity
Derivative, Notional Amount		0		200,000,000
Impact of Cash Flow Hedges on the Balance Sheet
AOCI Gain (Loss) Net of Tax		7,500,000		(800,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		800,000		400,000
Interest Rate [Member] \| Indiana Michigan Power Co [Member]
Commodity
Derivative, Notional Amount		0		0
Impact of Cash Flow Hedges on the Balance Sheet
AOCI Gain (Loss) Net of Tax		(6,700,000)		(8,300,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		(1,600,000)		(1,600,000)
Interest Rate [Member] \| Ohio Power Co [Member]
Commodity
Derivative, Notional Amount		0		0
Interest Rate [Member] \| Public Service Co Of Oklahoma [Member]
Commodity
Derivative, Notional Amount		0		0
Impact of Cash Flow Hedges on the Balance Sheet
AOCI Gain (Loss) Net of Tax		0		100,000
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		0		100,000
Interest Rate [Member] \| Southwestern Electric Power Co [Member]
Commodity
Derivative, Notional Amount		0		0
Impact of Cash Flow Hedges on the Balance Sheet
AOCI Gain (Loss) Net of Tax		1,200,000		(300,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		100,000		(1,500,000)
Interest Rate [Member] \| Hedging Contracts [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[11]	1,200,000		5,000,000
Derivative Asset, Noncurrent	[11]	0		0
Total Assets	[11]	1,200,000		5,000,000
Current Risk Management Liabilities	[11]	0		3,400,000
Derivative Liability, Noncurrent	[11]	38,100,000		4,100,000
Total Liabilities	[11]	38,100,000		7,500,000
Total MTM Derivative Contract Net Assets (Liabilities)	[11]	(36,900,000)		(2,500,000)
Interest Rate [Member] \| Hedging Contracts [Member] \| Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets				2,400,000
Derivative Asset, Noncurrent				0
Total Assets				2,400,000
Current Risk Management Liabilities				3,400,000
Derivative Liability, Noncurrent				0
Total Liabilities				3,400,000
Total MTM Derivative Contract Net Assets (Liabilities)				(1,000,000)
Gross Amounts of Risk Management Assets/Liabilities Recognized [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		690,600,000	[10]	265,200,000
Derivative Asset, Noncurrent		459,600,000		293,900,000
Total Assets		1,150,200,000		559,100,000
Current Risk Management Liabilities		436,600,000	[12]	250,800,000
Derivative Liability, Noncurrent		298,700,000		286,400,000
Total Liabilities		735,300,000		537,200,000
Total MTM Derivative Contract Net Assets (Liabilities)		414,900,000		21,900,000
Gross Amounts of Risk Management Assets/Liabilities Recognized [Member] \| Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets				41,200,000
Derivative Asset, Noncurrent				700,000
Total Assets				41,900,000
Current Risk Management Liabilities				23,100,000
Derivative Liability, Noncurrent				600,000
Total Liabilities				23,700,000
Total MTM Derivative Contract Net Assets (Liabilities)				18,200,000
Gross Amounts Offset in the Statement of Financial Position [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[13]	(496,200,000)	[10]	(170,500,000)
Derivative Asset, Noncurrent	[13]	(192,600,000)		(51,700,000)
Total Assets	[13]	(688,800,000)		(222,200,000)
Current Risk Management Liabilities	[13]	(361,200,000)	[12]	(172,000,000)
Derivative Liability, Noncurrent	[13]	(68,400,000)		(53,600,000)
Total Liabilities	[13]	(429,600,000)		(225,600,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[13]	(259,200,000)		3,400,000
Gross Amounts Offset in the Statement of Financial Position [Member] \| AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[13]	(600,000)		(400,000)
Derivative Asset, Noncurrent	[13]	0		0
Total Assets	[13]	(600,000)		(400,000)
Current Risk Management Liabilities	[13]	0		0
Derivative Liability, Noncurrent	[13]	0		0
Total Liabilities	[13]	0		0
Total MTM Derivative Contract Net Assets (Liabilities)	[13]	(600,000)		(400,000)
Gross Amounts Offset in the Statement of Financial Position [Member] \| Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[13]	(5,500,000)		(18,800,000)
Derivative Asset, Noncurrent	[13]	(200,000)		(600,000)
Total Assets	[13]	(5,700,000)		(19,400,000)
Current Risk Management Liabilities	[13]	(6,400,000)		(18,500,000)
Derivative Liability, Noncurrent	[13]	(200,000)		(500,000)
Total Liabilities	[13]	(6,600,000)		(19,000,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[13]	900,000		(400,000)
Gross Amounts Offset in the Statement of Financial Position [Member] \| Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[13]	(7,800,000)		(13,600,000)
Derivative Asset, Noncurrent	[13]	(200,000)		(400,000)
Total Assets	[13]	(8,000,000)		(14,000,000)
Current Risk Management Liabilities	[13]	(9,800,000)		(12,000,000)
Derivative Liability, Noncurrent	[13]	(200,000)		(300,000)
Total Liabilities	[13]	(10,000,000)		(12,300,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[13]	2,000,000		(1,700,000)
Gross Amounts Offset in the Statement of Financial Position [Member] \| Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[13]	(500,000)		(300,000)
Derivative Asset, Noncurrent	[13]	0		0
Total Assets	[13]	(500,000)		(300,000)
Current Risk Management Liabilities	[13]	0		0
Derivative Liability, Noncurrent	[13]	0		0
Total Liabilities	[13]	0		0
Total MTM Derivative Contract Net Assets (Liabilities)	[13]	(500,000)		(300,000)
Gross Amounts Offset in the Statement of Financial Position [Member] \| Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[13]	(300,000)		(200,000)
Derivative Asset, Noncurrent	[13]	0		0
Total Assets	[13]	(300,000)		(200,000)
Current Risk Management Liabilities	[13]	0		0
Derivative Liability, Noncurrent	[13]	0		0
Total Liabilities	[13]	0		0
Total MTM Derivative Contract Net Assets (Liabilities)	[13]	(300,000)		(200,000)
Gross Amounts Offset in the Statement of Financial Position [Member] \| Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[13]	(300,000)		(200,000)
Derivative Asset, Noncurrent	[13]	0		0
Total Assets	[13]	(300,000)		(200,000)
Current Risk Management Liabilities	[13]	0		0
Derivative Liability, Noncurrent	[13]	0		0
Total Liabilities	[13]	0		0
Total MTM Derivative Contract Net Assets (Liabilities)	[13]	(300,000)		(200,000)
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[14]	194,400,000	[10]	94,700,000
Derivative Asset, Noncurrent	[14]	267,000,000		242,200,000
Total Assets	[14]	461,400,000		336,900,000
Current Risk Management Liabilities	[14]	75,400,000	[12]	78,800,000
Derivative Liability, Noncurrent	[14]	230,300,000		232,800,000
Total Liabilities	[14]	305,700,000		311,600,000
Total MTM Derivative Contract Net Assets (Liabilities)	[14]	155,700,000		25,300,000
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member] \| AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[14]	0		0
Derivative Asset, Noncurrent	[14]	0		0
Total Assets	[14]	0		0
Current Risk Management Liabilities	[14]	0		0
Derivative Liability, Noncurrent	[14]	0		0
Total Liabilities	[14]	0		0
Total MTM Derivative Contract Net Assets (Liabilities)	[14]	0		0
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member] \| Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[14]	42,000,000		22,400,000
Derivative Asset, Noncurrent	[14]	0		100,000
Total Assets	[14]	42,000,000		22,500,000
Current Risk Management Liabilities	[14]	800,000		4,600,000
Derivative Liability, Noncurrent	[14]	0		100,000
Total Liabilities	[14]	800,000		4,700,000
Total MTM Derivative Contract Net Assets (Liabilities)	[14]	41,200,000		17,800,000
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member] \| Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[14]	3,300,000		3,600,000
Derivative Asset, Noncurrent	[14]	0		100,000
Total Assets	[14]	3,300,000		3,700,000
Current Risk Management Liabilities	[14]	5,000,000		100,000
Derivative Liability, Noncurrent	[14]	0		100,000
Total Liabilities	[14]	5,000,000		200,000
Total MTM Derivative Contract Net Assets (Liabilities)	[14]	(1,700,000)		3,500,000
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member] \| Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[14]	0		0
Derivative Asset, Noncurrent	[14]	0		0
Total Assets	[14]	0		0
Current Risk Management Liabilities	[14]	6,700,000		8,700,000
Derivative Liability, Noncurrent	[14]	85,800,000		101,600,000
Total Liabilities	[14]	92,500,000		110,300,000
Total MTM Derivative Contract Net Assets (Liabilities)	[14]	(92,500,000)		(110,300,000)
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member] \| Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[14]	12,100,000		10,300,000
Derivative Asset, Noncurrent	[14]	0		0
Total Assets	[14]	12,100,000		10,300,000
Current Risk Management Liabilities	[14]	3,700,000		0
Derivative Liability, Noncurrent	[14]	0		0
Total Liabilities	[14]	3,700,000		0
Total MTM Derivative Contract Net Assets (Liabilities)	[14]	8,400,000		10,300,000
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member] \| Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[14]	9,800,000		3,200,000
Derivative Asset, Noncurrent	[14]	1,100,000		0
Total Assets	[14]	10,900,000		3,200,000
Current Risk Management Liabilities	[14]	2,100,000		700,000
Derivative Liability, Noncurrent	[14]	0		1,000,000
Total Liabilities	[14]	2,100,000		1,700,000
Total MTM Derivative Contract Net Assets (Liabilities)	[14]	8,800,000		$ 1,500,000
Held For Sale [Member]
Derivatives and Hedging (Textuals)
Assets Held for Sale		6,000,000
Liabilities Held for Sale		$ 100,000
Power [Member]
Commodity
Derivative, Energy Notional Amount \| MWh		287.9		331.3
Power [Member] \| AEP Texas Inc. [Member]
Commodity
Derivative, Energy Notional Amount \| MWh		0		0
Power [Member] \| Appalachian Power Co [Member]
Commodity
Derivative, Energy Notional Amount \| MWh		33.1		46.9
Power [Member] \| Indiana Michigan Power Co [Member]
Commodity
Derivative, Energy Notional Amount \| MWh		13.6		19.7
Power [Member] \| Ohio Power Co [Member]
Commodity
Derivative, Energy Notional Amount \| MWh		2.7		3
Power [Member] \| Public Service Co Of Oklahoma [Member]
Commodity
Derivative, Energy Notional Amount \| MWh		11.9		11.9
Power [Member] \| Southwestern Electric Power Co [Member]
Commodity
Derivative, Energy Notional Amount \| MWh		3.4		4
Natural Gas [Member]
Commodity
Derivative, Energy Notional Amount \| MMBTU		34.1		26.9
Natural Gas [Member] \| AEP Texas Inc. [Member]
Commodity
Derivative, Energy Notional Amount \| MMBTU		0		0
Natural Gas [Member] \| Appalachian Power Co [Member]
Commodity
Derivative, Energy Notional Amount \| MMBTU		0		0
Natural Gas [Member] \| Indiana Michigan Power Co [Member]
Commodity
Derivative, Energy Notional Amount \| MMBTU		0		0
Natural Gas [Member] \| Ohio Power Co [Member]
Commodity
Derivative, Energy Notional Amount \| MMBTU		0		0
Natural Gas [Member] \| Public Service Co Of Oklahoma [Member]
Commodity
Derivative, Energy Notional Amount \| MMBTU		1.3		0
Natural Gas [Member] \| Southwestern Electric Power Co [Member]
Commodity
Derivative, Energy Notional Amount \| MMBTU		5.1		7.9
Heating Oil and Gasoline [Member]
Commodity
Derivative, Volume Notional Amount \| gal		7.4		6.9
Heating Oil and Gasoline [Member] \| AEP Texas Inc. [Member]
Commodity
Derivative, Volume Notional Amount \| gal		1.9		1.8
Heating Oil and Gasoline [Member] \| Appalachian Power Co [Member]
Commodity
Derivative, Volume Notional Amount \| gal		1.1		1.1
Heating Oil and Gasoline [Member] \| Indiana Michigan Power Co [Member]
Commodity
Derivative, Volume Notional Amount \| gal		0.7		0.6
Heating Oil and Gasoline [Member] \| Ohio Power Co [Member]
Commodity
Derivative, Volume Notional Amount \| gal		1.5		1.4
Heating Oil and Gasoline [Member] \| Public Service Co Of Oklahoma [Member]
Commodity
Derivative, Volume Notional Amount \| gal		0.8		0.7
Heating Oil and Gasoline [Member] \| Southwestern Electric Power Co [Member]
Commodity
Derivative, Volume Notional Amount \| gal		1		0.9
Interest Rate Contract [Member]
Commodity
Derivative, Notional Amount		$ 116,500,000		$ 129,800,000
Interest Rate Contract [Member] \| AEP Texas Inc. [Member]
Commodity
Derivative, Notional Amount		0		0
Interest Rate Contract [Member] \| Appalachian Power Co [Member]
Commodity
Derivative, Notional Amount		0		0
Interest Rate Contract [Member] \| Indiana Michigan Power Co [Member]
Commodity
Derivative, Notional Amount		0		0
Interest Rate Contract [Member] \| Ohio Power Co [Member]
Commodity
Derivative, Notional Amount		0		0
Interest Rate Contract [Member] \| Public Service Co Of Oklahoma [Member]
Commodity
Derivative, Notional Amount		0		0
Interest Rate Contract [Member] \| Southwestern Electric Power Co [Member]
Commodity
Derivative, Notional Amount		0		0
Warrants Held in Investee [Member]
Fair Value of Derivative Instruments
Total Assets		15,000,000		32,000,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(17,000,000)		32,000,000
Derivatives and Hedging (Textuals)
Cost of Investment in Privately Held Investee				8,000,000
Vertically Integrated Utilities Revenues [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(600,000)		800,000		700,000
Vertically Integrated Utilities Revenues [Member] \| AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0		0
Vertically Integrated Utilities Revenues [Member] \| Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0		0
Vertically Integrated Utilities Revenues [Member] \| Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0		0
Vertically Integrated Utilities Revenues [Member] \| Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0		0
Vertically Integrated Utilities Revenues [Member] \| Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0		0
Vertically Integrated Utilities Revenues [Member] \| Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0		0
Generation and Marketing Revenues [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		169,100,000		9,500,000		25,100,000
Generation and Marketing Revenues [Member] \| AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0		0
Generation and Marketing Revenues [Member] \| Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0		0
Generation and Marketing Revenues [Member] \| Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0		0
Generation and Marketing Revenues [Member] \| Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0		0
Generation and Marketing Revenues [Member] \| Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0		0
Generation and Marketing Revenues [Member] \| Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0		0
Electric Generation, Transmission and Distribution Revenues [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0		0
Electric Generation, Transmission and Distribution Revenues [Member] \| AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0		0
Electric Generation, Transmission and Distribution Revenues [Member] \| Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(500,000)		400,000		100,000
Electric Generation, Transmission and Distribution Revenues [Member] \| Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(100,000)		100,000		500,000
Electric Generation, Transmission and Distribution Revenues [Member] \| Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0		0
Electric Generation, Transmission and Distribution Revenues [Member] \| Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0		0
Electric Generation, Transmission and Distribution Revenues [Member] \| Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		100,000		100,000
Purchased Electricity for Resale [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		2,000,000		1,400,000		1,900,000
Purchased Electricity for Resale [Member] \| AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0		0
Purchased Electricity for Resale [Member] \| Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		1,800,000		1,200,000		1,600,000
Purchased Electricity for Resale [Member] \| Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		100,000		100,000
Purchased Electricity for Resale [Member] \| Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0		0
Purchased Electricity for Resale [Member] \| Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0		0
Purchased Electricity for Resale [Member] \| Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0		0
Other Operation Expense [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		2,800,000		(2,000,000)		(800,000)
Other Operation Expense [Member] \| AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		800,000		(600,000)		(200,000)
Other Operation Expense [Member] \| Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		300,000		(200,000)		(100,000)
Other Operation Expense [Member] \| Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		300,000		(200,000)		(100,000)
Other Operation Expense [Member] \| Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		500,000		(300,000)		(200,000)
Other Operation Expense [Member] \| Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		300,000		(200,000)		(100,000)
Other Operation Expense [Member] \| Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		400,000		(300,000)		(100,000)
Maintenance Expense [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		3,400,000		(2,900,000)		(800,000)
Maintenance Expense [Member] \| AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		1,000,000		(800,000)		(200,000)
Maintenance Expense [Member] \| Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		500,000		(400,000)		(200,000)
Maintenance Expense [Member] \| Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		300,000		(300,000)		(100,000)
Maintenance Expense [Member] \| Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		600,000		(500,000)		(200,000)
Maintenance Expense [Member] \| Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		400,000		(300,000)		(100,000)
Maintenance Expense [Member] \| Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		500,000		(400,000)		(100,000)
Regulatory Assets [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[15]	(9,100,000)		(4,800,000)		(3,700,000)
Regulatory Assets [Member] \| AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[15]	0		0		700,000
Regulatory Assets [Member] \| Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[15]	(2,700,000)		0		300,000
Regulatory Assets [Member] \| Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[15]	(14,800,000)		(100,000)		300,000
Regulatory Assets [Member] \| Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[15]	10,000,000		(6,600,000)		(3,700,000)
Regulatory Assets [Member] \| Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[15]	(3,600,000)		0		1,200,000
Regulatory Assets [Member] \| Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[15]	3,600,000		1,400,000		(1,500,000)
Regulatory Liabilities [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[15]	156,400,000		114,900,000		102,600,000
Regulatory Liabilities [Member] \| AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[15]	200,000		400,000		0
Regulatory Liabilities [Member] \| Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[15]	55,900,000		20,300,000		2,400,000
Regulatory Liabilities [Member] \| Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[15]	(3,900,000)		12,400,000		24,500,000
Regulatory Liabilities [Member] \| Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[15]	0		12,400,000		10,100,000
Regulatory Liabilities [Member] \| Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[15]	48,900,000		39,100,000		34,600,000
Regulatory Liabilities [Member] \| Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[15]	$ 37,000,000		$ 20,200,000		$ 26,600,000

[1]	Amounts include $(46) million and $(53) million as of December 31, 2021 and 2020, respectively, for the fair value hedge adjustment of hedged debt obligations for which hedge accounting has been discontinued
[2]	Amounts included on the balance sheets within Long-term Debt Due within One Year and Long-term Debt, respectively.
[3]	Gain (Loss) is included in Interest Expense on the statements of income.
[4]	Amount excludes Risk Management Assets of $6 million classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[5]	Amounts in “Other” column primarily represent counterparty netting of risk management and hedging contracts and associated cash collateral under the accounting guidance for “Derivatives and Hedging.”
[6]	The December 31, 2021 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $1 million in 2022 and $1 million in periods 2023-2025; Level 2 matures $42 million in 2022, $109 million in periods 2023-2025, $10 million in periods 2026-2027 and $3 million in periods 2028-2033; Level 3 matures $82 million in 2022, $10 million in periods 2023-2025, $9 million in periods 2026-2027 and $(17) million in periods 2028-2033. Risk management commodity contracts are substantially comprised of power contracts.
[7]	The December 31, 2020 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 2 matures $3 million in periods 2022-2024, $11 million in periods 2025-2026 and $1 million in periods 2027-2033; Level 3 matures $47 million in 2021, $37 million in periods 2022-2024, $14 million in periods 2025-2026 and $(13) million in periods 2027-2033. Risk management commodity contracts are substantially comprised of power contracts.
[8]	Amount excludes Risk Management Liabilities of $0.1 million classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[9]	Substantially comprised of power contracts for the Registrant Subsidiaries.
[10]	Amount excludes Risk Management Assets of $6 million classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[11]	Derivative instruments within these categories are disclosed as gross. These instruments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with the accounting guidance for “Derivatives and Hedging.”
[12]	Amount excludes Risk Management Liabilities of $0.1 million classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[13]	Amounts include counterparty netting of risk management and hedging contracts and associated cash collateral in accordance with the accounting guidance for “Derivatives and Hedging.”
[14]	All derivative contracts subject to a master netting arrangement or similar agreement are offset in the statement of financial position.
[15]	Represents realized and unrealized gains and losses subject to regulatory accounting treatment recorded as either current or noncurrent on the balance sheets.

Fair Value Long-term Debt, Othe

Fair Value Long-term Debt, Other Temporary Investments, Nuclear Trusts (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021		Dec. 31, 2020	Dec. 31, 2019
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		$ 33,454.5	[1],[2],[3]	$ 31,072.5	$ 26,725.5
Long-term Debt, Fair Value	[5]	37,564.7	[4]	37,457
Other Temporary Investments
Cost		232		214.9
Gross Unrealized Gains		36.4		31.5
Gross Unrealized Losses		0		0
Fair Value		268.4		246.4
Debt and Equity Securities Within Other Temporary Investments
Proceeds From Investment Sales		15		50.9	21.2
Purchases of Investments		26.9		41.6	45
Gross Realized Gains on Investment Sales		3.6		3.8	0
Gross Realized Losses on Investment Sales		0		0.2	0.4
Nuclear Trust Fund Investments
Fair Value		3,867		3,306.7
Contractual Maturities, Fair Value of Debt Securities
Fair Value		3,867		3,306.7
Fair Value Measurements (Textuals)
Liabilities Held for Sale		1,880.9		0
Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		1,974.7		1,509.8
Other-Than-Temporary Impairments		(10.1)		(9.2)
Securities Activity Within the Decommissioning and SNF Trusts
Proceeds from Investment Sales		1,886.4		1,593.4	1,473
Purchases of Investments		1,928.2		1,637.2	1,531
Gross Realized Gains on Investment Sales		103.2		26.4	76.5
Gross Realized Losses on Investment Sales		16.5		26.1	24.3
Contractual Maturities, Fair Value of Debt Securities
Within 1 year		302.4
After 1 year through 5 years		431.2
After 5 years through 10 years		227.7
After 10 years		279.1
Fair Value Measurements (Textuals)
Adjusted Cost of Debt Securities		1,200		1,100
Adjusted Cost of Domestic Equity Securities		641		654
AEP Texas Inc. [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		5,180.8		4,820.4
Long-term Debt, Fair Value		5,663.8		5,682.6
AEP Transmission Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		4,343.9		3,948.5	3,427.3
Long-term Debt, Fair Value		4,968.2		4,984.3
Fair Value Measurements (Textuals)
Liabilities Held for Sale		27.6		0
Appalachian Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		4,938.9		4,834.1
Long-term Debt, Fair Value		6,037.1		6,391.8
Indiana Michigan Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		3,195		3,029.9
Long-term Debt, Fair Value		3,748		3,775.3
Nuclear Trust Fund Investments
Fair Value		3,867		3,306.7
Contractual Maturities, Fair Value of Debt Securities
Fair Value		3,867		3,306.7
Indiana Michigan Power Co [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		1,974.7		1,509.8
Other-Than-Temporary Impairments		(10.1)		(9.2)
Securities Activity Within the Decommissioning and SNF Trusts
Proceeds from Investment Sales		1,886.4		1,593.4	1,473
Purchases of Investments		1,928.2		1,637.2	1,531
Gross Realized Gains on Investment Sales		103.2		26.4	76.5
Gross Realized Losses on Investment Sales		16.5		26.1	$ 24.3
Contractual Maturities, Fair Value of Debt Securities
Within 1 year		302.4
After 1 year through 5 years		431.2
After 5 years through 10 years		227.7
After 10 years		279.1
Fair Value Measurements (Textuals)
Adjusted Cost of Debt Securities		1,200		1,100
Adjusted Cost of Domestic Equity Securities		641		654
Ohio Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		2,968.5		2,430.2
Long-term Debt, Fair Value		3,437.5		3,154.9
Public Service Co Of Oklahoma [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		1,913.5		1,373.8
Long-term Debt, Fair Value		2,163.7		1,732.1
Southwestern Electric Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		3,395.2		2,636.4
Long-term Debt, Fair Value		3,792.9		3,210.1
Cash [Member]
Other Temporary Investments
Cost	[6]	48		45.6
Gross Unrealized Gains	[6]	0		0
Gross Unrealized Losses	[6]	0		0
Fair Value	[6]	48		45.6
Other Cash Deposits [Member]
Other Temporary Investments
Cost		10		22.7
Gross Unrealized Gains		0		0
Gross Unrealized Losses		0		0
Fair Value	[7]	10		22.7
Mutual Funds Fixed Income [Member]
Other Temporary Investments
Cost	[8]	154.3		120.7
Gross Unrealized Gains	[8]	0.5		2.8
Gross Unrealized Losses	[8]	0		0
Fair Value	[8]	154.8		123.5
Mutual Funds Equity [Member]
Other Temporary Investments
Cost		19.7		25.9
Gross Unrealized Gains		35.9		28.7
Gross Unrealized Losses		0		0
Fair Value		55.6		54.6
Fixed Income Funds [Member]
Nuclear Trust Fund Investments
Fair Value		1,240.4		1,226.2
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,240.4		1,226.2
Fixed Income Funds [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		73.4		109
Other-Than-Temporary Impairments		(10.1)		(9.2)
Fixed Income Funds [Member] \| Indiana Michigan Power Co [Member]
Nuclear Trust Fund Investments
Fair Value		1,240.4		1,226.2
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,240.4		1,226.2
Fixed Income Funds [Member] \| Indiana Michigan Power Co [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		73.4		109
Other-Than-Temporary Impairments		(10.1)		(9.2)
Domestic [Member]
Nuclear Trust Fund Investments
Fair Value	[9]	2,541.9		2,054.7
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[9]	2,541.9		2,054.7
Domestic [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Unrealized Gain on Securities		1,900		1,400
Unrealized Loss on Securities		4		9
Nuclear Trust Fund Investments
Gross Unrealized Gains	[10]	1,901.3		1,400.8
Other-Than-Temporary Impairments		0		0
Domestic [Member] \| Indiana Michigan Power Co [Member]
Nuclear Trust Fund Investments
Fair Value	[9]	2,541.9		2,054.7
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[9]	2,541.9		2,054.7
Domestic [Member] \| Indiana Michigan Power Co [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Unrealized Gain on Securities		1,900		1,400
Unrealized Loss on Securities		4		9
Nuclear Trust Fund Investments
Gross Unrealized Gains	[10]	1,901.3		1,400.8
Other-Than-Temporary Impairments		0		0
Cash and Cash Equivalents [Member]
Nuclear Trust Fund Investments
Fair Value	[11]	84.7		25.8
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[11]	84.7		25.8
Cash and Cash Equivalents [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		0		0
Other-Than-Temporary Impairments		0		0
Cash and Cash Equivalents [Member] \| Indiana Michigan Power Co [Member]
Nuclear Trust Fund Investments
Fair Value	[11]	84.7		25.8
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[11]	84.7		25.8
Cash and Cash Equivalents [Member] \| Indiana Michigan Power Co [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		0		0
Other-Than-Temporary Impairments		0		0
US Government Agencies Debt Securities [Member]
Nuclear Trust Fund Investments
Fair Value		1,156.4		1,025.6
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,156.4		1,025.6
US Government Agencies Debt Securities [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		66.3		98.5
Other-Than-Temporary Impairments		(7.9)		(7.1)
US Government Agencies Debt Securities [Member] \| Indiana Michigan Power Co [Member]
Nuclear Trust Fund Investments
Fair Value		1,156.4		1,025.6
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,156.4		1,025.6
US Government Agencies Debt Securities [Member] \| Indiana Michigan Power Co [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		66.3		98.5
Other-Than-Temporary Impairments		(7.9)		(7.1)
Corporate Debt [Member]
Nuclear Trust Fund Investments
Fair Value		76.7		86.3
Contractual Maturities, Fair Value of Debt Securities
Fair Value		76.7		86.3
Corporate Debt [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		6.7		9.6
Other-Than-Temporary Impairments		(2.1)		(1.7)
Corporate Debt [Member] \| Indiana Michigan Power Co [Member]
Nuclear Trust Fund Investments
Fair Value		76.7		86.3
Contractual Maturities, Fair Value of Debt Securities
Fair Value		76.7		86.3
Corporate Debt [Member] \| Indiana Michigan Power Co [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		6.7		9.6
Other-Than-Temporary Impairments		(2.1)		(1.7)
State and Local Jurisdiction
Nuclear Trust Fund Investments
Fair Value		7.3		114.3
Contractual Maturities, Fair Value of Debt Securities
Fair Value		7.3		114.3
State and Local Jurisdiction \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		0.4		0.9
Other-Than-Temporary Impairments		(0.1)		(0.4)
State and Local Jurisdiction \| Indiana Michigan Power Co [Member]
Nuclear Trust Fund Investments
Fair Value		7.3		114.3
Contractual Maturities, Fair Value of Debt Securities
Fair Value		7.3		114.3
State and Local Jurisdiction \| Indiana Michigan Power Co [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		0.4		0.9
Other-Than-Temporary Impairments		(0.1)		(0.4)
Equity units [Member]
Book Values and Fair Values of Long - term Debt
Long-term Debt, Fair Value		1,700		$ 1,700
Held For Sale [Member]
Fair Value Measurements (Textuals)
Liabilities Held for Sale		1,100
Fair Value Held for Sale [Member]
Fair Value Measurements (Textuals)
Liabilities Held for Sale		$ 1,200

[1]	2021 amount excludes $1.1 billion of Total Long-term Debt Outstanding classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[2]	Amount excludes $1.1 billion of Total Long-term Debt Outstanding classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information
[3]	The 2021 book value amount excludes Long-term Debt of $1.1 billion classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[4]	The 2021 fair value amount excludes Long-term Debt of $1.2 billion related to KPCo. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[5]	The fair value amounts include debt related to AEP’s Equity Units and had a fair value of $1.7 billion and $1.7 billion as of December 31, 2021 and 2020, respectively. See “Equity Units” section of Note 14 for additional information.
[6]	Primarily represents amounts held for the repayment of debt.
[7]	Amounts in “Other” column primarily represent cash deposits in bank accounts with financial institutions or third-parties. Level 1 and Level 2 amounts primarily represent investments in money market funds.
[8]	Primarily short and intermediate maturities which may be sold and do not contain maturity dates.
[9]	Amounts represent publicly-traded equity securities and equity-based mutual funds.
[10]	Amount reported as Gross Unrealized Gains includes unrealized gains of $1.9 billion and $1.4 billion and unrealized losses of $4 million and $9 million as of December 31, 2021 and 2020, respectively.
[11]	Amounts in “Other” column primarily represent accrued interest receivables from financial institutions. Level 1 amounts primarily represent investments in money market funds.

Fair Value Financial Assets Lia

Fair Value Financial Assets Liabilities (Details) - USD ($)		12 Months Ended
Fair Value Financial Assets Liabilities (Details) - USD ($)		Dec. 31, 2021		Dec. 31, 2020		Dec. 31, 2019
Assets, Fair Value Disclosure
Other Temporary Investments		$ 268,400,000		$ 246,400,000
Risk Management Assets
Derivative Assets		461,400,000		336,900,000
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		3,867,000,000		3,306,700,000
Total Assets		4,640,500,000		3,921,800,000
Liabilities, Fair Value Disclosure
Derivative Liabilities		305,700,000		311,600,000
Changes in the Fair Value of Net Trading Derivatives and Other Investments
Beginning Balance		113,300,000		109,900,000		$ 131,200,000
Realized Gain (Loss) Included in Net Income (or Changes in Net Assets)	[1],[2]	48,600,000		39,500,000		15,800,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	(45,200,000)		35,300,000		(100,000)
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	24,200,000		13,800,000		(15,100,000)
Settlements		(89,000,000)		(113,100,000)		(117,600,000)
Transfers into Level 3	[4],[5]	(3,800,000)		(3,800,000)		(600,000)
Transfers out of Level 3	[5]	(34,400,000)		5,600,000		35,600,000
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	89,400,000		26,100,000		60,700,000
Assets and Liabilities Held for Sale related to KPCo	[7],[8]	(5,800,000)
Ending Balance		97,300,000		113,300,000		109,900,000
Fair Value Measurements 1 (Textuals)
Assets Held for Sale		2,919,700,000		0
Liabilities Held for Sale		1,880,900,000		0
Held For Sale [Member]
Fair Value Measurements 1 (Textuals)
Assets Held for Sale		6,400,000
Liabilities Held for Sale		600,000
Other [Member]
Assets, Fair Value Disclosure
Other Temporary Investments		10,000,000		10,500,000
Risk Management Assets
Derivative Assets		(684,100,000)		(218,500,000)
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		7,000,000		9,000,000
Total Assets		(667,100,000)		(199,000,000)
Liabilities, Fair Value Disclosure
Derivative Liabilities		(424,900,000)		(221,900,000)
Level 1 [Member]
Assets, Fair Value Disclosure
Other Temporary Investments		258,400,000		235,900,000
Risk Management Assets
Derivative Assets		7,400,000		900,000
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		2,619,600,000		2,071,500,000
Total Assets		2,914,200,000		2,308,300,000
Liabilities, Fair Value Disclosure
Derivative Liabilities		5,300,000		900,000
Level 2 [Member]
Assets, Fair Value Disclosure
Other Temporary Investments		0		0
Risk Management Assets
Derivative Assets		892,600,000		298,200,000
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,240,400,000		1,226,200,000
Total Assets		2,147,900,000		1,524,400,000
Liabilities, Fair Value Disclosure
Derivative Liabilities		577,100,000		357,800,000
Level 3 [Member]
Assets, Fair Value Disclosure
Other Temporary Investments		0		0
Risk Management Assets
Derivative Assets		245,500,000		256,300,000
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
Total Assets		245,500,000		288,100,000
Liabilities, Fair Value Disclosure
Derivative Liabilities		148,200,000		174,800,000
2021 [Member] \| Level 3 [Member]
Fair Value Measurements 1 (Textuals)
Maturity Of Net Fair Value Of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities				47,000,000
2022 [Member] \| Level 1 [Member]
Fair Value Measurements 1 (Textuals)
Maturity Of Net Fair Value Of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		1,000,000
2022 [Member] \| Level 2 [Member]
Fair Value Measurements 1 (Textuals)
Maturity Of Net Fair Value Of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		42,000,000
2022 [Member] \| Level 3 [Member]
Fair Value Measurements 1 (Textuals)
Maturity Of Net Fair Value Of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		82,000,000
2022 - 2024 [Member] \| Level 2 [Member]
Fair Value Measurements 1 (Textuals)
Maturity Of Net Fair Value Of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities				3,000,000
2022 - 2024 [Member] \| Level 3 [Member]
Fair Value Measurements 1 (Textuals)
Maturity Of Net Fair Value Of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities				37,000,000
2023 - 2025 [Member] \| Level 1 [Member]
Fair Value Measurements 1 (Textuals)
Maturity Of Net Fair Value Of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		1,000,000
2023 - 2025 [Member] \| Level 2 [Member]
Fair Value Measurements 1 (Textuals)
Maturity Of Net Fair Value Of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		109,000,000
2023 - 2025 [Member] \| Level 3 [Member]
Fair Value Measurements 1 (Textuals)
Maturity Of Net Fair Value Of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		10,000,000
2025 - 2026 [Member] \| Level 2 [Member]
Fair Value Measurements 1 (Textuals)
Maturity Of Net Fair Value Of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities				11,000,000
2025 - 2026 [Member] \| Level 3 [Member]
Fair Value Measurements 1 (Textuals)
Maturity Of Net Fair Value Of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities				14,000,000
2026-2027 [Member] \| Level 2 [Member]
Fair Value Measurements 1 (Textuals)
Maturity Of Net Fair Value Of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		10,000,000
2026-2027 [Member] \| Level 3 [Member]
Fair Value Measurements 1 (Textuals)
Maturity Of Net Fair Value Of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		9,000,000
2027 - 2033 [Member] \| Level 2 [Member]
Fair Value Measurements 1 (Textuals)
Maturity Of Net Fair Value Of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities				1,000,000
2027 - 2033 [Member] \| Level 3 [Member]
Fair Value Measurements 1 (Textuals)
Maturity Of Net Fair Value Of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities				(13,000,000)
2028 - 2033 [Member] \| Level 2 [Member]
Fair Value Measurements 1 (Textuals)
Maturity Of Net Fair Value Of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		3,000,000
2028 - 2033 [Member] \| Level 3 [Member]
Fair Value Measurements 1 (Textuals)
Maturity Of Net Fair Value Of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		(17,000,000)
Risk Management Commodity Contracts [Member]
Risk Management Assets
Derivative Assets	[10]	239,800,000	[9],[11]	322,100,000	[12]
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10]	254,700,000	[11],[13]	218,900,000	[12]
Fair Value Measurements 1 (Textuals)
Assets Held for Sale		6,000,000
Liabilities Held for Sale		100,000
Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets
Derivative Assets	[10]	(642,400,000)	[9],[11]	(190,000,000)	[12]
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10]	(383,200,000)	[11],[13]	(193,400,000)	[12]
Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets
Derivative Assets	[10]	7,400,000	[9],[11]	900,000	[12]
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10]	5,300,000	[11],[13]	900,000	[12]
Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets
Derivative Assets	[10]	648,500,000	[9],[11]	258,800,000	[12]
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10]	485,000,000	[11],[13]	244,200,000	[12]
Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets	[10]	226,300,000	[9],[11]	252,400,000	[12]
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10]	147,600,000	[11],[13]	167,200,000	[12]
Energy Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets		164,400,000		213,500,000
Liabilities, Fair Value Disclosure
Derivative Liabilities		135,200,000	[14]	169,700,000
Fair Value Measurements 1 (Textuals)
Liabilities Held for Sale		100,000
Energy Contracts [Member] \| Level 3 [Member] \| Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15]	10.30		5.33
Energy Contracts [Member] \| Level 3 [Member] \| High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15]	76.70		100.47
Energy Contracts [Member] \| Level 3 [Member] \| Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15],[16]	37.11		32.73
Natural Gas Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets		3,600,000		0
Liabilities, Fair Value Disclosure
Derivative Liabilities		0		1,700,000
Natural Gas Contracts [Member] \| Level 3 [Member] \| Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[17]	3.11		2.18
Natural Gas Contracts [Member] \| Level 3 [Member] \| High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[17]	4.02		2.77
Natural Gas Contracts [Member] \| Level 3 [Member] \| Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[16],[17]	3.47		2.40
FTRs [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets		77,500,000	[18]	42,800,000
Liabilities, Fair Value Disclosure
Derivative Liabilities		13,000,000	[19]	3,400,000
Fair Value Measurements 1 (Textuals)
Assets Held for Sale		6,000,000
Liabilities Held for Sale		500,000
FTRs [Member] \| Level 3 [Member] \| Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15]	(23.93)		(15.08)
FTRs [Member] \| Level 3 [Member] \| High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15]	26.38		9.66
FTRs [Member] \| Level 3 [Member] \| Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15],[16]	0.86		0.19
Commodity Hedges [Member]
Risk Management Assets
Derivative Assets	[10]	220,400,000		9,800,000
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10]	12,900,000		85,200,000
Commodity Hedges [Member] \| Other [Member]
Risk Management Assets
Derivative Assets	[10]	(41,700,000)		(28,500,000)
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10]	(41,700,000)		(28,500,000)
Commodity Hedges [Member] \| Level 1 [Member]
Risk Management Assets
Derivative Assets	[10]	0		0
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10]	0		0
Commodity Hedges [Member] \| Level 2 [Member]
Risk Management Assets
Derivative Assets	[10]	242,900,000		34,400,000
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10]	54,000,000		106,100,000
Commodity Hedges [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets	[10]	19,200,000		3,900,000
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10]	600,000		7,600,000
Interest Rate Foreign Currency Hedges [Member]
Risk Management Assets
Derivative Assets				2,400,000
Liabilities, Fair Value Disclosure
Derivative Liabilities				3,400,000
Interest Rate Foreign Currency Hedges [Member] \| Other [Member]
Risk Management Assets
Derivative Assets				0
Liabilities, Fair Value Disclosure
Derivative Liabilities				0
Interest Rate Foreign Currency Hedges [Member] \| Level 1 [Member]
Risk Management Assets
Derivative Assets				0
Liabilities, Fair Value Disclosure
Derivative Liabilities				0
Interest Rate Foreign Currency Hedges [Member] \| Level 2 [Member]
Risk Management Assets
Derivative Assets				2,400,000
Liabilities, Fair Value Disclosure
Derivative Liabilities				3,400,000
Interest Rate Foreign Currency Hedges [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets				0
Liabilities, Fair Value Disclosure
Derivative Liabilities				0
Fair Value Hedges [Member]
Risk Management Assets
Derivative Assets		1,200,000		2,600,000
Liabilities, Fair Value Disclosure
Derivative Liabilities		38,100,000		4,100,000
Fair Value Hedges [Member] \| Other [Member]
Risk Management Assets
Derivative Assets		0		0
Liabilities, Fair Value Disclosure
Derivative Liabilities		0		0
Fair Value Hedges [Member] \| Level 1 [Member]
Risk Management Assets
Derivative Assets		0		0
Liabilities, Fair Value Disclosure
Derivative Liabilities		0		0
Fair Value Hedges [Member] \| Level 2 [Member]
Risk Management Assets
Derivative Assets		1,200,000		2,600,000
Liabilities, Fair Value Disclosure
Derivative Liabilities		38,100,000		4,100,000
Fair Value Hedges [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets		0		0
Liabilities, Fair Value Disclosure
Derivative Liabilities		0		0
Other Investments [Member]
Risk Management Assets
Derivative Assets		43,700,000	[20]	31,800,000
Other Investments [Member] \| Other [Member]
Risk Management Assets
Derivative Assets		0	[20]	0
Other Investments [Member] \| Level 1 [Member]
Risk Management Assets
Derivative Assets		28,800,000	[20]	0
Other Investments [Member] \| Level 2 [Member]
Risk Management Assets
Derivative Assets		14,900,000	[20]	0
Other Investments [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets		0	[20]	31,800,000
Liabilities, Fair Value Disclosure
Derivative Liabilities				0
Other Investments [Member] \| Level 3 [Member] \| Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit				0.10
Other Investments [Member] \| Level 3 [Member] \| High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit				0.20
Other Investments [Member] \| Level 3 [Member] \| Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit				0.15
AEP Texas Inc. [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		30,400,000		28,700,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		30,400,000		28,700,000
AEP Texas Inc. [Member] \| Other [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0		0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		(600,000)		(400,000)
AEP Texas Inc. [Member] \| Level 1 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		30,400,000		28,700,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		30,400,000		28,700,000
AEP Texas Inc. [Member] \| Level 2 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0		0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		600,000		400,000
AEP Texas Inc. [Member] \| Level 3 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0		0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		0		0
AEP Texas Inc. [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Assets
Derivative Assets		0	[10]	0
AEP Texas Inc. [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets
Derivative Assets		(600,000)	[10]	(400,000)
AEP Texas Inc. [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets
Derivative Assets		0	[10]	0
AEP Texas Inc. [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets
Derivative Assets		600,000	[10]	400,000
AEP Texas Inc. [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets		0	[10]	0
AEP Transmission Co [Member]
Fair Value Measurements 1 (Textuals)
Assets Held for Sale		167,900,000		0
Liabilities Held for Sale		27,600,000		0
Appalachian Power Co [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		17,600,000		16,900,000
Risk Management Assets
Derivative Assets				22,500,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		59,600,000		39,400,000
Liabilities, Fair Value Disclosure
Derivative Liabilities				4,700,000
Changes in the Fair Value of Net Trading Derivatives and Other Investments
Beginning Balance		19,300,000		37,700,000		57,800,000
Realized Gain (Loss) Included in Net Income (or Changes in Net Assets)	[1],[2]	8,300,000		13,200,000		(13,900,000)
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	0		0		0
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	0		0		0
Settlements		(28,000,000)		(51,600,000)		(42,500,000)
Transfers into Level 3	[4],[5]	0		0		(500,000)
Transfers out of Level 3	[5]	0		700,000		(700,000)
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	42,100,000		19,300,000		37,500,000
Assets and Liabilities Held for Sale related to KPCo		0
Ending Balance		41,700,000		19,300,000		37,700,000
Appalachian Power Co [Member] \| Other [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0		0
Risk Management Assets
Derivative Assets				(19,200,000)
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		(5,800,000)		(19,200,000)
Liabilities, Fair Value Disclosure
Derivative Liabilities				(18,800,000)
Appalachian Power Co [Member] \| Level 1 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		17,600,000		16,900,000
Risk Management Assets
Derivative Assets				0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		17,600,000		16,900,000
Liabilities, Fair Value Disclosure
Derivative Liabilities				0
Appalachian Power Co [Member] \| Level 2 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0		0
Risk Management Assets
Derivative Assets				21,800,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		5,800,000		21,800,000
Liabilities, Fair Value Disclosure
Derivative Liabilities				22,900,000
Appalachian Power Co [Member] \| Level 3 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0		0
Risk Management Assets
Derivative Assets		42,000,000		19,900,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		42,000,000		19,900,000
Liabilities, Fair Value Disclosure
Derivative Liabilities		300,000		600,000
Appalachian Power Co [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Assets
Derivative Assets	[10],[21]	42,000,000		20,100,000
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	800,000		1,300,000
Appalachian Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets
Derivative Assets	[10],[21]	(5,800,000)		(19,200,000)
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	(6,700,000)		(18,800,000)
Appalachian Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets
Derivative Assets	[10],[21]	0		0
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	0		0
Appalachian Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets
Derivative Assets	[10],[21]	5,800,000		19,400,000
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	7,200,000		19,500,000
Appalachian Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets	[10],[21]	42,000,000		19,900,000
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	300,000		600,000
Appalachian Power Co [Member] \| Energy Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets		0		1,000,000
Liabilities, Fair Value Disclosure
Derivative Liabilities		300,000		600,000
Appalachian Power Co [Member] \| Energy Contracts [Member] \| Level 3 [Member] \| Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15]	32.20		10.84
Appalachian Power Co [Member] \| Energy Contracts [Member] \| Level 3 [Member] \| High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15]	56.54		41.09
Appalachian Power Co [Member] \| Energy Contracts [Member] \| Level 3 [Member] \| Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15],[16]	44.77		25.08
Appalachian Power Co [Member] \| FTRs [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets		42,000,000		18,900,000
Liabilities, Fair Value Disclosure
Derivative Liabilities		0		0
Appalachian Power Co [Member] \| FTRs [Member] \| Level 3 [Member] \| Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15]	(0.30)		0.04
Appalachian Power Co [Member] \| FTRs [Member] \| Level 3 [Member] \| High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15]	26.38		5.61
Appalachian Power Co [Member] \| FTRs [Member] \| Level 3 [Member] \| Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15],[16]	2.63		1.13
Appalachian Power Co [Member] \| Interest Rate Foreign Currency Hedges [Member]
Risk Management Assets
Derivative Assets				2,400,000
Liabilities, Fair Value Disclosure
Derivative Liabilities				3,400,000
Appalachian Power Co [Member] \| Interest Rate Foreign Currency Hedges [Member] \| Other [Member]
Risk Management Assets
Derivative Assets				0
Liabilities, Fair Value Disclosure
Derivative Liabilities				0
Appalachian Power Co [Member] \| Interest Rate Foreign Currency Hedges [Member] \| Level 1 [Member]
Risk Management Assets
Derivative Assets				0
Liabilities, Fair Value Disclosure
Derivative Liabilities				0
Appalachian Power Co [Member] \| Interest Rate Foreign Currency Hedges [Member] \| Level 2 [Member]
Risk Management Assets
Derivative Assets				2,400,000
Liabilities, Fair Value Disclosure
Derivative Liabilities				3,400,000
Appalachian Power Co [Member] \| Interest Rate Foreign Currency Hedges [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets				0
Liabilities, Fair Value Disclosure
Derivative Liabilities				0
Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		3,867,000,000		3,306,700,000
Total Assets		3,870,300,000		3,310,400,000
Changes in the Fair Value of Net Trading Derivatives and Other Investments
Beginning Balance		2,100,000		5,800,000		8,900,000
Realized Gain (Loss) Included in Net Income (or Changes in Net Assets)	[1],[2]	(100,000)		2,500,000		4,700,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	0		0		0
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	0		0		0
Settlements		(2,200,000)		(8,600,000)		(13,000,000)
Transfers into Level 3	[4],[5]	0		0		(300,000)
Transfers out of Level 3	[5]	0		400,000		(400,000)
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	(500,000)		2,000,000		5,900,000
Assets and Liabilities Held for Sale related to KPCo		0
Ending Balance		(700,000)		2,100,000		5,800,000
Indiana Michigan Power Co [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		7,000,000		9,000,000
Total Assets		(1,100,000)		(4,900,000)
Indiana Michigan Power Co [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		2,619,600,000		2,071,500,000
Total Assets		2,619,600,000		2,071,500,000
Indiana Michigan Power Co [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,240,400,000		1,226,200,000
Total Assets		1,244,200,000		1,241,300,000
Indiana Michigan Power Co [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets		7,600,000		2,500,000
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
Total Assets		7,600,000		2,500,000
Liabilities, Fair Value Disclosure
Derivative Liabilities		8,300,000		400,000
Indiana Michigan Power Co [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Assets
Derivative Assets	[10],[21]	3,300,000		3,700,000
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	5,000,000		200,000
Indiana Michigan Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets
Derivative Assets	[10],[21]	(8,100,000)		(13,900,000)
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	(10,000,000)		(12,200,000)
Indiana Michigan Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets
Derivative Assets	[10],[21]	0		0
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	0		0
Indiana Michigan Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets
Derivative Assets	[10],[21]	3,800,000		15,100,000
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	6,700,000		12,000,000
Indiana Michigan Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets	[10],[21]	7,600,000		2,500,000
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	8,300,000		400,000
Indiana Michigan Power Co [Member] \| Energy Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets		0		600,000
Liabilities, Fair Value Disclosure
Derivative Liabilities		200,000		300,000
Indiana Michigan Power Co [Member] \| Energy Contracts [Member] \| Level 3 [Member] \| Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15]	32.20		10.84
Indiana Michigan Power Co [Member] \| Energy Contracts [Member] \| Level 3 [Member] \| High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15]	56.54		41.09
Indiana Michigan Power Co [Member] \| Energy Contracts [Member] \| Level 3 [Member] \| Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15],[16]	44.77		25.08
Indiana Michigan Power Co [Member] \| FTRs [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets		7,600,000		1,900,000
Liabilities, Fair Value Disclosure
Derivative Liabilities		8,100,000		100,000
Indiana Michigan Power Co [Member] \| FTRs [Member] \| Level 3 [Member] \| Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15]	(5.45)		(1.96)
Indiana Michigan Power Co [Member] \| FTRs [Member] \| Level 3 [Member] \| High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15]	17.78		3.69
Indiana Michigan Power Co [Member] \| FTRs [Member] \| Level 3 [Member] \| Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15],[16]	(0.12)		0.33
Ohio Power Co [Member]
Changes in the Fair Value of Net Trading Derivatives and Other Investments
Beginning Balance		(110,300,000)		(103,600,000)		(99,400,000)
Realized Gain (Loss) Included in Net Income (or Changes in Net Assets)	[1],[2]	2,400,000		(1,600,000)		(900,000)
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	0		0		0
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	0		0		0
Settlements		6,300,000		8,900,000		6,600,000
Transfers into Level 3	[4],[5]	0		0		0
Transfers out of Level 3	[5]	0		0		0
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	9,100,000		(14,000,000)		(9,900,000)
Assets and Liabilities Held for Sale related to KPCo		0
Ending Balance		(92,500,000)		(110,300,000)		(103,600,000)
Ohio Power Co [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Assets
Derivative Assets	[10],[21]	0		0
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	92,500,000		110,300,000
Ohio Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets
Derivative Assets	[10],[21]	(500,000)		(300,000)
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	0		0
Ohio Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets
Derivative Assets	[10],[21]	0		0
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	0		0
Ohio Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets
Derivative Assets	[10],[21]	500,000		300,000
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	0		0
Ohio Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets	[10],[21]	0		0
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	92,500,000		110,300,000
Ohio Power Co [Member] \| Energy Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets		0		0
Liabilities, Fair Value Disclosure
Derivative Liabilities		92,500,000		110,300,000
Ohio Power Co [Member] \| Energy Contracts [Member] \| Level 3 [Member] \| Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15]	14.26		16.19
Ohio Power Co [Member] \| Energy Contracts [Member] \| Level 3 [Member] \| High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15]	52.98		46.98
Ohio Power Co [Member] \| Energy Contracts [Member] \| Level 3 [Member] \| Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15],[16]	30.68		28.30
Public Service Co Of Oklahoma [Member]
Changes in the Fair Value of Net Trading Derivatives and Other Investments
Beginning Balance		10,300,000		15,800,000		9,500,000
Realized Gain (Loss) Included in Net Income (or Changes in Net Assets)	[1],[2]	16,100,000		11,900,000		13,500,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	0		0		0
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	0		0		0
Settlements		(26,400,000)		(27,600,000)		(23,000,000)
Transfers into Level 3	[4],[5]	0		0		0
Transfers out of Level 3	[5]	0		0		0
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	12,100,000		10,200,000		15,800,000
Assets and Liabilities Held for Sale related to KPCo		0
Ending Balance		12,100,000		10,300,000		15,800,000
Public Service Co Of Oklahoma [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Assets
Derivative Assets	[10],[21]	12,100,000		10,300,000
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	3,700,000
Public Service Co Of Oklahoma [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets
Derivative Assets	[10],[21]	(400,000)		(200,000)
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	(100,000)
Public Service Co Of Oklahoma [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets
Derivative Assets	[10],[21]	0		0
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	0
Public Service Co Of Oklahoma [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets
Derivative Assets	[10],[21]	300,000		200,000
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	3,700,000
Public Service Co Of Oklahoma [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets	[10],[21]	12,200,000		10,300,000
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	100,000
Public Service Co Of Oklahoma [Member] \| FTRs [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets		12,200,000		10,300,000
Liabilities, Fair Value Disclosure
Derivative Liabilities		100,000		0
Public Service Co Of Oklahoma [Member] \| FTRs [Member] \| Level 3 [Member] \| Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15]	(18.39)		(6.93)
Public Service Co Of Oklahoma [Member] \| FTRs [Member] \| Level 3 [Member] \| High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15]	1.87		0.48
Public Service Co Of Oklahoma [Member] \| FTRs [Member] \| Level 3 [Member] \| Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15],[16]	(2.57)		(1.93)
Southwestern Electric Power Co [Member]
Changes in the Fair Value of Net Trading Derivatives and Other Investments
Beginning Balance		1,600,000		1,400,000		2,300,000
Realized Gain (Loss) Included in Net Income (or Changes in Net Assets)	[1],[2]	9,500,000		2,800,000		6,000,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	0		0		0
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	0		0		0
Settlements		(15,500,000)		(6,600,000)		(9,600,000)
Transfers into Level 3	[4],[5]	0		0		0
Transfers out of Level 3	[5]	0		0		0
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	15,300,000		4,000,000		2,700,000
Assets and Liabilities Held for Sale related to KPCo		0
Ending Balance		10,900,000		1,600,000		$ 1,400,000
Southwestern Electric Power Co [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets		11,000,000		3,300,000
Liabilities, Fair Value Disclosure
Derivative Liabilities		100,000		1,700,000
Southwestern Electric Power Co [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Assets
Derivative Assets	[10],[21]	10,900,000		3,200,000
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	2,100,000		1,700,000
Southwestern Electric Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets
Derivative Assets	[10],[21]	(400,000)		(200,000)
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	(100,000)		0
Southwestern Electric Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets
Derivative Assets	[10],[21]	0		0
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	0		0
Southwestern Electric Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets
Derivative Assets	[10],[21]	300,000		100,000
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	2,100,000		0
Southwestern Electric Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets	[10],[21]	11,000,000		3,300,000
Liabilities, Fair Value Disclosure
Derivative Liabilities	[10],[21]	100,000		1,700,000
Southwestern Electric Power Co [Member] \| Natural Gas Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets		3,600,000		0
Liabilities, Fair Value Disclosure
Derivative Liabilities		0		1,700,000
Southwestern Electric Power Co [Member] \| Natural Gas Contracts [Member] \| Level 3 [Member] \| Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[17]	3.11		2.18
Southwestern Electric Power Co [Member] \| Natural Gas Contracts [Member] \| Level 3 [Member] \| High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[17]	4.02		2.77
Southwestern Electric Power Co [Member] \| Natural Gas Contracts [Member] \| Level 3 [Member] \| Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[16],[17]	3.47		2.41
Southwestern Electric Power Co [Member] \| FTRs [Member] \| Level 3 [Member]
Risk Management Assets
Derivative Assets		7,400,000		3,300,000
Liabilities, Fair Value Disclosure
Derivative Liabilities		100,000		0
Southwestern Electric Power Co [Member] \| FTRs [Member] \| Level 3 [Member] \| Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15]	(18.39)		(6.93)
Southwestern Electric Power Co [Member] \| FTRs [Member] \| Level 3 [Member] \| High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15]	1.87		0.48
Southwestern Electric Power Co [Member] \| FTRs [Member] \| Level 3 [Member] \| Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15],[16]	(2.57)		(1.93)
Cash [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		48,000,000		45,600,000
Other Temporary Investments	[22]	48,000,000		45,600,000
Cash [Member] \| Other [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0		0
Cash [Member] \| Level 1 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		48,000,000		45,600,000
Cash [Member] \| Level 2 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0		0
Cash [Member] \| Level 3 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0		0
Other Cash Deposits [Member]
Assets, Fair Value Disclosure
Other Temporary Investments	[23]	10,000,000		22,700,000
Other Cash Deposits [Member] \| Other [Member]
Assets, Fair Value Disclosure
Other Temporary Investments	[23]	10,000,000		10,500,000
Other Cash Deposits [Member] \| Level 1 [Member]
Assets, Fair Value Disclosure
Other Temporary Investments		0		12,200,000
Other Cash Deposits [Member] \| Level 2 [Member]
Assets, Fair Value Disclosure
Other Temporary Investments		0		0
Other Cash Deposits [Member] \| Level 3 [Member]
Assets, Fair Value Disclosure
Other Temporary Investments		0		0
Mutual Funds Fixed Income [Member]
Assets, Fair Value Disclosure
Other Temporary Investments	[24]	154,800,000		123,500,000
Mutual Funds Fixed Income [Member] \| Other [Member]
Assets, Fair Value Disclosure
Other Temporary Investments		0		0
Mutual Funds Fixed Income [Member] \| Level 1 [Member]
Assets, Fair Value Disclosure
Other Temporary Investments		154,800,000		123,500,000
Mutual Funds Fixed Income [Member] \| Level 2 [Member]
Assets, Fair Value Disclosure
Other Temporary Investments		0		0
Mutual Funds Fixed Income [Member] \| Level 3 [Member]
Assets, Fair Value Disclosure
Other Temporary Investments		0		0
Mutual Funds Equity [Member]
Assets, Fair Value Disclosure
Other Temporary Investments	[25]	55,600,000		54,600,000
Mutual Funds Equity [Member] \| Other [Member]
Assets, Fair Value Disclosure
Other Temporary Investments	[25]	0		0
Mutual Funds Equity [Member] \| Level 1 [Member]
Assets, Fair Value Disclosure
Other Temporary Investments	[25]	55,600,000		54,600,000
Mutual Funds Equity [Member] \| Level 2 [Member]
Assets, Fair Value Disclosure
Other Temporary Investments	[25]	0		0
Mutual Funds Equity [Member] \| Level 3 [Member]
Assets, Fair Value Disclosure
Other Temporary Investments	[25]	0		0
Cash and Cash Equivalents [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[26]	84,700,000		25,800,000
Cash and Cash Equivalents [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[26]	7,000,000		9,000,000
Cash and Cash Equivalents [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[26]	77,700,000		16,800,000
Cash and Cash Equivalents [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[26]	0		0
Cash and Cash Equivalents [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[26]	0		0
Cash and Cash Equivalents [Member] \| Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[26]	84,700,000		25,800,000
Cash and Cash Equivalents [Member] \| Indiana Michigan Power Co [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[26]	7,000,000		9,000,000
Cash and Cash Equivalents [Member] \| Indiana Michigan Power Co [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[26]	77,700,000		16,800,000
Cash and Cash Equivalents [Member] \| Indiana Michigan Power Co [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[26]	0		0
Cash and Cash Equivalents [Member] \| Indiana Michigan Power Co [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[26]	0		0
US Government Agencies Debt Securities [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,156,400,000		1,025,600,000
US Government Agencies Debt Securities [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
US Government Agencies Debt Securities [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
US Government Agencies Debt Securities [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,156,400,000		1,025,600,000
US Government Agencies Debt Securities [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
US Government Agencies Debt Securities [Member] \| Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,156,400,000		1,025,600,000
US Government Agencies Debt Securities [Member] \| Indiana Michigan Power Co [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
US Government Agencies Debt Securities [Member] \| Indiana Michigan Power Co [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
US Government Agencies Debt Securities [Member] \| Indiana Michigan Power Co [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,156,400,000		1,025,600,000
US Government Agencies Debt Securities [Member] \| Indiana Michigan Power Co [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
Corporate Debt Securities [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		76,700,000		86,300,000
Corporate Debt Securities [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
Corporate Debt Securities [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
Corporate Debt Securities [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		76,700,000		86,300,000
Corporate Debt Securities [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
Corporate Debt Securities [Member] \| Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		76,700,000		86,300,000
Corporate Debt Securities [Member] \| Indiana Michigan Power Co [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
Corporate Debt Securities [Member] \| Indiana Michigan Power Co [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
Corporate Debt Securities [Member] \| Indiana Michigan Power Co [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		76,700,000		86,300,000
Corporate Debt Securities [Member] \| Indiana Michigan Power Co [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
State and Local Jurisdiction
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		7,300,000		114,300,000
State and Local Jurisdiction \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
State and Local Jurisdiction \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
State and Local Jurisdiction \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		7,300,000		114,300,000
State and Local Jurisdiction \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
State and Local Jurisdiction \| Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		7,300,000		114,300,000
State and Local Jurisdiction \| Indiana Michigan Power Co [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
State and Local Jurisdiction \| Indiana Michigan Power Co [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
State and Local Jurisdiction \| Indiana Michigan Power Co [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		7,300,000		114,300,000
State and Local Jurisdiction \| Indiana Michigan Power Co [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
Fixed Income Funds [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,240,400,000		1,226,200,000
Fixed Income Funds [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
Fixed Income Funds [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
Fixed Income Funds [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,240,400,000		1,226,200,000
Fixed Income Funds [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
Fixed Income Funds [Member] \| Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,240,400,000		1,226,200,000
Fixed Income Funds [Member] \| Indiana Michigan Power Co [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
Fixed Income Funds [Member] \| Indiana Michigan Power Co [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
Fixed Income Funds [Member] \| Indiana Michigan Power Co [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,240,400,000		1,226,200,000
Fixed Income Funds [Member] \| Indiana Michigan Power Co [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0		0
Domestic [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[25]	2,541,900,000		2,054,700,000
Domestic [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[25]	0		0
Domestic [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[25]	2,541,900,000		2,054,700,000
Domestic [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[25]	0		0
Domestic [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[25]	0		0
Domestic [Member] \| Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[25]	2,541,900,000		2,054,700,000
Domestic [Member] \| Indiana Michigan Power Co [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[25]	0		0
Domestic [Member] \| Indiana Michigan Power Co [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[25]	2,541,900,000		2,054,700,000
Domestic [Member] \| Indiana Michigan Power Co [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[25]	0		0
Domestic [Member] \| Indiana Michigan Power Co [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[25]	$ 0		$ 0

[1]	Included in revenues on the statements of income.
[2]	Represents the change in fair value between the beginning of the reporting period and the settlement of the risk management commodity contract.
[3]	Included in cash flow hedges on the statements of comprehensive income.
[4]	Represents existing assets or liabilities that were previously categorized as Level 2.
[5]	Transfers are recognized based on their value at the beginning of the reporting period that the transfer occurred.
[6]	Relates to the net gains (losses) of those contracts that are not reflected on the statements of income. These changes in fair value are recorded as regulatory liabilities for net gains and as regulatory assets for net losses or accounts payable.
[7]	Amount excludes Risk Management Assets of $6.4 million classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[8]	Amount excludes Risk Management Liabilities of $0.6 million classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[9]	Amount excludes Risk Management Assets of $6 million classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[10]	Amounts in “Other” column primarily represent counterparty netting of risk management and hedging contracts and associated cash collateral under the accounting guidance for “Derivatives and Hedging.”
[11]	The December 31, 2021 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $1 million in 2022 and $1 million in periods 2023-2025; Level 2 matures $42 million in 2022, $109 million in periods 2023-2025, $10 million in periods 2026-2027 and $3 million in periods 2028-2033; Level 3 matures $82 million in 2022, $10 million in periods 2023-2025, $9 million in periods 2026-2027 and $(17) million in periods 2028-2033. Risk management commodity contracts are substantially comprised of power contracts.
[12]	The December 31, 2020 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 2 matures $3 million in periods 2022-2024, $11 million in periods 2025-2026 and $1 million in periods 2027-2033; Level 3 matures $47 million in 2021, $37 million in periods 2022-2024, $14 million in periods 2025-2026 and $(13) million in periods 2027-2033. Risk management commodity contracts are substantially comprised of power contracts.
[13]	Amount excludes Risk Management Liabilities of $0.1 million classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[14]	Amount excludes Risk Management Liabilities of $0.1 million classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[15]	Represents market prices in dollars per MWh.
[16]	The weighted-average is the product of the forward market price of the underlying commodity and volume weighted by term.
[17]	Represents market prices in dollars per MMBtu.
[18]	Amount excludes Risk Management Assets of $6 million classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[19]	Amount excludes Risk Management Liabilities of $0.5 million classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[20]	See “Warrants Held in Investee” section of Note 10 for additional information.
[21]	Substantially comprised of power contracts for the Registrant Subsidiaries.
[22]	Primarily represents amounts held for the repayment of debt.
[23]	Amounts in “Other” column primarily represent cash deposits in bank accounts with financial institutions or third-parties. Level 1 and Level 2 amounts primarily represent investments in money market funds.
[24]	Primarily short and intermediate maturities which may be sold and do not contain maturity dates.
[25]	Amounts represent publicly-traded equity securities and equity-based mutual funds.
[26]	Amounts in “Other” column primarily represent accrued interest receivables from financial institutions. Level 1 amounts primarily represent investments in money market funds.

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
Income Taxes (Details) - USD ($) $ in Millions	Dec. 31, 2021		Dec. 31, 2020	Dec. 31, 2019
Federal:
Current	$ (27.8)		$ (138.2)	$ (7.4)
Deferred	182.6		146.9	(71.6)
Total Federal	154.8		8.7	(79)
Current	6		(16.7)	4.4
Deferred	(45.3)	[1]	48.5	61.7
Total State and Local	(39.3)		31.8	66.1
Income Tax Expense (Benefit):
Income Tax Expense (Benefit)	115.5		40.5	(12.9)
Reconciliation of Federal Income Taxes and Amount of Income Tax Reported
Net Income	2,488.1		2,196.7	1,919.8
Less: Equity Earnings – Dolet Hills	(91.7)		(91.1)	(72.1)
Income Tax Expense (Benefit)	115.5		40.5	(12.9)
Pretax Income	2,600.2		2,234.3	1,903.9
Income Taxes on Pretax Income at Statutory Rate (21%)	$ 546		$ 469.2	$ 399.8
Federal Statutory Income Tax Rate	21.00%		21.00%	21.00%
Reconciliation of Federal Statutory Rate and Amount of Taxes Reported
Depreciation	$ 25.9		$ 26.5	$ 20.4
Investment Tax Credit Amortization	(22)		(18.8)	(13)
Production Tax Credits	(98.8)		(83.1)	(59.6)
State and Local Income Taxes, Net	39.4		25.1	52.2
Removal Costs	(20)		(18.6)	(22.2)
AFUDC	(30.6)		(32.5)	(37.1)
Increase Decrease in Income Taxes Due to Tax Reserve Adjustments	(55.1)	[2]	0	0
Tax Reform Excess ADIT Reversal	(255.6)		(268.2)	(353.2)
CARES Act Provision	0		(48)	0
Other	(13.7)		(11.1)	(0.2)
Income Tax Expense (Benefit)	$ 115.5		$ 40.5	$ (12.9)
Effective Income Tax Rate	4.40%		1.80%	(0.70%)
Net Deferred Tax Liability and Significant Temporary Differences
Deferred Tax Assets	$ 3,277		$ 3,259.7
Deferred Tax Liabilities	(11,479.5)		(11,500.6)
Property Related Temporary Differences	(7,020.3)		(7,340.5)
Amounts Due from Customers for Future Federal Income Taxes	1,033		1,075.8
Deferred State Income Taxes	(1,116.7)		(1,317.6)
Securitized Assets	(128.8)		(140)
Regulatory Assets	(645.4)		(391.6)
Accrued Nuclear Decommissioning	(743.2)		(626.4)
Net Operating Loss Carryforward	285.7		112.9
Tax Credit Carryforward	439.8		323.6
Operating Lease Liability	114.2		183.7
Investment in Partnership	(392.1)		(362)
All Other, Net	(28.7)		241.2
Net Deferred Tax Liabilities	(8,202.5)		(8,240.9)
Net Income Tax Operating Loss Carryforwards
Net Income Tax Operating Loss Carryforward	(674)
Reconciliation of the Beginning and Ending Amount of Unrecognized Tax Benefits
Balance at January 1,	13.2		24.1	$ 14.6
Increase - Tax Positions Taken During a Prior Period	1.2		0.6	8.8
Decrease - Tax Positions Taken During a Prior Period	(3.2)		(14.5)	(2.1)
Increase - Tax Positions Taken During the Current Year	3.1		3	2.8
Decrease - Tax Positions Taken During the Current Year	0		0	0
Decrease - Settlements with Taxing Authorities	0		0	0
Decrease - Lapse of the Applicable Statute of Limitations	0		0	0
Balance at December 31,	14.3		13.2	24.1
Tax Contingency [Abstract]
Unrecognized Tax Benefits, if Recognized - Amount	14		12	20
Income Taxes (Textuals) [Abstract]
Income Tax Expense (Benefit)	115.5		40.5	(12.9)
Income Taxes Receivable	95
Tax Cuts and Jobs Act, Change in Tax Rate, Deferred Tax Asset, Income Tax Expense	48
Income Tax Expense Re-Measurement	23
Operating Income (Loss)	$ (3,411.3)		(2,987.7)	(2,592.3)
Minimum [Member]
Income Taxes (Textuals) [Abstract]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2036
Maximum [Member]
Income Taxes (Textuals) [Abstract]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2040
AEP Texas Inc. [Member]
Federal:
Current	$ (1.2)		5.2	(31.8)
Deferred	40.5		(15.4)	(24.7)
Total Federal	39.3		(10.2)	(56.5)
Current	3		(0.1)	2.9
Deferred	0.8		(0.9)	0
Total State and Local	3.8		(1)	2.9
Income Tax Expense (Benefit):
Income Tax Expense (Benefit)	43.1		(11.2)	(53.6)
Reconciliation of Federal Income Taxes and Amount of Income Tax Reported
Net Income	289.8		241	178.3
Income Tax Expense (Benefit)	43.1		(11.2)	(53.6)
Pretax Income	332.9		229.8	124.7
Income Taxes on Pretax Income at Statutory Rate (21%)	$ 69.9		$ 48.3	$ 26.2
Federal Statutory Income Tax Rate	21.00%		21.00%	21.00%
Reconciliation of Federal Statutory Rate and Amount of Taxes Reported
State and Local Income Taxes, Net	$ 2.4		$ (0.8)	$ 2.3
AFUDC	(4.5)		(4.1)	(3.2)
Parent Company Loss Benefit	(3.2)		(4.5)	(3.8)
Tax Reform Excess ADIT Reversal	(21.3)		(47.9)	(73.4)
Other	(0.2)		(2.2)	(1.7)
Income Tax Expense (Benefit)	$ 43.1		$ (11.2)	$ (53.6)
Effective Income Tax Rate	12.90%		(4.90%)	(43.00%)
Net Deferred Tax Liability and Significant Temporary Differences
Deferred Tax Assets	$ 173.8		$ 183.6
Deferred Tax Liabilities	(1,262.7)		(1,200.3)
Property Related Temporary Differences	(1,060.2)		(1,039.6)
Amounts Due from Customers for Future Federal Income Taxes	110		114.4
Deferred State Income Taxes	(32.2)		(29.1)
Securitized Transition Assets	(84.4)		(90.2)
Regulatory Assets	(45.1)		(47.4)
Operating Lease Liability	15.8		18
All Other, Net	7.2		57.2
Net Deferred Tax Liabilities	(1,088.9)		(1,016.7)
Income Taxes (Textuals) [Abstract]
Income Tax Expense (Benefit)	43.1		(11.2)	$ (53.6)
Operating Income (Loss)	$ (476)		(369.6)	(232)
AEP Texas Inc. [Member] \| Minimum [Member]
Income Taxes (Textuals) [Abstract]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2036
AEP Texas Inc. [Member] \| Maximum [Member]
Income Taxes (Textuals) [Abstract]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2040
AEP Transmission Co [Member]
Federal:
Current	$ 69.8		22.2	23.7
Deferred	54.1		65.4	71.7
Total Federal	123.9		87.6	95.4
Current	5.8		2.8	2.4
Deferred	14.4		16.3	19.6
Total State and Local	20.2		19.1	22
Income Tax Expense (Benefit):
Income Tax Expense (Benefit)	144.1		106.7	117.4
Reconciliation of Federal Income Taxes and Amount of Income Tax Reported
Net Income	591.7		423.4	439.7
Income Tax Expense (Benefit)	144.1		106.7	117.4
Pretax Income	735.8		530.1	557.1
Income Taxes on Pretax Income at Statutory Rate (21%)	$ 154.5		$ 111.3	$ 117
Federal Statutory Income Tax Rate	21.00%		21.00%	21.00%
Reconciliation of Federal Statutory Rate and Amount of Taxes Reported
State and Local Income Taxes, Net	$ 19.8		$ 15.1	$ 17.4
AFUDC	(14.1)		(15.5)	(17.7)
Parent Company Loss Benefit	(18.3)		(7)	(4.2)
Other	2.2		2.8	4.9
Income Tax Expense (Benefit)	$ 144.1		$ 106.7	$ 117.4
Effective Income Tax Rate	19.60%		20.10%	21.10%
Net Deferred Tax Liability and Significant Temporary Differences
Deferred Tax Assets	$ 158.8		$ 166.5
Deferred Tax Liabilities	(1,121.7)		(1,073.4)
Property Related Temporary Differences	(997)		(937.8)
Amounts Due from Customers for Future Federal Income Taxes	118.2		118.9
Deferred State Income Taxes	(94.5)		(98.3)
Net Operating Loss Carryforward	8.1		13.2
All Other, Net	2.3		(2.9)
Net Deferred Tax Liabilities	(962.9)		(906.9)
Income Taxes (Textuals) [Abstract]
Income Tax Expense (Benefit)	144.1		106.7	$ 117.4
Operating Income (Loss)	$ (809.3)		(581.5)	(567.2)
AEP Transmission Co [Member] \| Minimum [Member]
Income Taxes (Textuals) [Abstract]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2036
AEP Transmission Co [Member] \| Maximum [Member]
Income Taxes (Textuals) [Abstract]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2040
Appalachian Power Co [Member]
Federal:
Current	$ 5		21.4	36.7
Deferred	14.9		(27.1)	(126.1)
Total Federal	19.9		(5.7)	(89.4)
Current	2.2		9.3	12
Deferred	0		0.7	(0.6)
Total State and Local	2.2		10	11.4
Income Tax Expense (Benefit):
Income Tax Expense (Benefit)	22.1		4.3	(78)
Reconciliation of Federal Income Taxes and Amount of Income Tax Reported
Net Income	348.9		369.7	306.3
Income Tax Expense (Benefit)	22.1		4.3	(78)
Pretax Income	371		374	228.3
Income Taxes on Pretax Income at Statutory Rate (21%)	$ 77.9		$ 78.5	$ 47.9
Federal Statutory Income Tax Rate	21.00%		21.00%	21.00%
Reconciliation of Federal Statutory Rate and Amount of Taxes Reported
Depreciation	$ 11.7		$ 12.7	$ 10.8
State and Local Income Taxes, Net	2.1		7.9	9
Removal Costs	(7.3)		(5.7)	(6.4)
AFUDC	(4.6)		(4.5)	(5.2)
Parent Company Loss Benefit	0		(6.2)	(4.1)
Increase Decrease in Income Taxes Due to Tax Reserve Adjustments	4.5	[2]	0	0
Tax Reform Excess ADIT Reversal	(60.5)		(72.3)	(130.4)
Federal Return to Provision	(1.6)		(7.2)	(1)
Other	(0.1)		1.1	1.4
Income Tax Expense (Benefit)	$ 22.1		$ 4.3	$ (78)
Effective Income Tax Rate	6.00%		1.10%	(34.20%)
Net Deferred Tax Liability and Significant Temporary Differences
Deferred Tax Assets	$ 495.1		$ 500.6
Deferred Tax Liabilities	(2,299.8)		(2,250.5)
Property Related Temporary Differences	(1,476.5)		(1,412)
Amounts Due from Customers for Future Federal Income Taxes	182.1		198.3
Deferred State Income Taxes	(288.8)		(336.5)
Securitized Assets	(39.3)		(44.7)
Regulatory Assets	(177)		(114.8)
Operating Lease Liability	14.2		16.7
All Other, Net	(19.4)		(56.9)
Net Deferred Tax Liabilities	(1,804.7)		(1,749.9)
Income Taxes (Textuals) [Abstract]
Income Tax Expense (Benefit)	22.1		4.3	$ (78)
Operating Income (Loss)	$ (549.4)		(556.6)	(397.3)
Appalachian Power Co [Member] \| Minimum [Member]
Income Taxes (Textuals) [Abstract]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2036
Appalachian Power Co [Member] \| Maximum [Member]
Income Taxes (Textuals) [Abstract]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2040
Indiana Michigan Power Co [Member]
Federal:
Current	$ 26.9		11.3	48.1
Deferred	(35.5)		(20.6)	(57.1)
Total Federal	(8.6)		(9.3)	(9)
Current	(0.6)		1.9	(2.4)
Deferred	(1.4)		(0.1)	0.8
Total State and Local	(2)		1.8	(1.6)
Income Tax Expense (Benefit):
Income Tax Expense (Benefit)	(10.6)		(7.5)	(10.6)
Reconciliation of Federal Income Taxes and Amount of Income Tax Reported
Net Income	279.8		284.8	269.4
Income Tax Expense (Benefit)	(10.6)		(7.5)	(10.6)
Pretax Income	269.2		277.3	258.8
Income Taxes on Pretax Income at Statutory Rate (21%)	$ 56.5		$ 58.2	$ 54.3
Federal Statutory Income Tax Rate	21.00%		21.00%	21.00%
Reconciliation of Federal Statutory Rate and Amount of Taxes Reported
Depreciation	$ 3.5		$ 1.6	$ 4
Investment Tax Credit Amortization	(6.4)		(4.5)	(3.6)
State and Local Income Taxes, Net	(1.3)		1.5	(1.2)
Removal Costs	(9.7)		(10.5)	(12.8)
AFUDC	(2.7)		(2.4)	(4.1)
Parent Company Loss Benefit	(2.8)		(6.4)	(3.3)
Tax Reform Excess ADIT Reversal	(46.3)		(46.8)	(42.5)
Other	(1.4)		1.8	(1.4)
Income Tax Expense (Benefit)	$ (10.6)		$ (7.5)	$ (10.6)
Effective Income Tax Rate	(3.90%)		(2.70%)	(4.10%)
Net Deferred Tax Liability and Significant Temporary Differences
Deferred Tax Assets	$ 1,072.2		$ 989.5
Deferred Tax Liabilities	(2,172.4)		(2,053.9)
Property Related Temporary Differences	(286.2)		(409.2)
Amounts Due from Customers for Future Federal Income Taxes	135.5		147.9
Deferred State Income Taxes	(222)		(211.1)
Regulatory Assets	(23.6)		(16.5)
Accrued Nuclear Decommissioning	(743.2)		(626.4)
Operating Lease Liability	13.5		46.6
All Other, Net	25.8		4.3
Net Deferred Tax Liabilities	(1,100.2)		(1,064.4)
Income Taxes (Textuals) [Abstract]
Income Tax Expense (Benefit)	(10.6)		(7.5)	$ (10.6)
Operating Income (Loss)	$ (357.9)		(362.9)	(340.8)
Indiana Michigan Power Co [Member] \| Minimum [Member]
Income Taxes (Textuals) [Abstract]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2036
Indiana Michigan Power Co [Member] \| Maximum [Member]
Income Taxes (Textuals) [Abstract]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2040
Ohio Power Co [Member]
Federal:
Current	$ 6.8		(26.6)	(10)
Deferred	25.2		74	40.6
Total Federal	32		47.4	30.6
Current	(3.1)		(5.4)	1.1
Deferred	5.5		3.2	3.2
Total State and Local	2.4		(2.2)	4.3
Income Tax Expense (Benefit):
Income Tax Expense (Benefit)	34.4		45.2	34.9
Reconciliation of Federal Income Taxes and Amount of Income Tax Reported
Net Income	253.6		271.4	297.1
Income Tax Expense (Benefit)	34.4		45.2	34.9
Pretax Income	288		316.6	332
Income Taxes on Pretax Income at Statutory Rate (21%)	$ 60.5		$ 66.5	$ 69.7
Federal Statutory Income Tax Rate	21.00%		21.00%	21.00%
Reconciliation of Federal Statutory Rate and Amount of Taxes Reported
Depreciation	$ 2.2		$ 3.7	$ (1.4)
State and Local Income Taxes, Net	0		(1.7)	3.4
AFUDC	(2.3)		(2.6)	(3.8)
Increase Decrease in Income Taxes Due to Tax Reserve Adjustments	8.9	[2]	0	0
Tax Reform Excess ADIT Reversal	(32.6)		(27.2)	(27.3)
Federal Return to Provision	(1.2)		6.5	(3.7)
Other	(1.1)		0	(2)
Income Tax Expense (Benefit)	$ 34.4		$ 45.2	$ 34.9
Effective Income Tax Rate	11.90%		14.30%	10.50%
Net Deferred Tax Liability and Significant Temporary Differences
Deferred Tax Assets	$ 204.4		$ 210.8
Deferred Tax Liabilities	(1,205.3)		(1,165.9)
Property Related Temporary Differences	(1,042)		(1,016)
Amounts Due from Customers for Future Federal Income Taxes	117.7		121.1
Deferred State Income Taxes	(58.8)		(40.7)
Regulatory Assets	(39.8)		(53.7)
Operating Lease Liability	17.2		19.4
All Other, Net	4.8		14.8
Net Deferred Tax Liabilities	(1,000.9)		(955.1)
Income Taxes (Textuals) [Abstract]
Income Tax Expense (Benefit)	34.4		45.2	$ 34.9
Operating Income (Loss)	$ (385.2)		(403.7)	(401.2)
Ohio Power Co [Member] \| Minimum [Member]
Income Taxes (Textuals) [Abstract]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2036
Ohio Power Co [Member] \| Maximum [Member]
Income Taxes (Textuals) [Abstract]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2040
Public Service Co Of Oklahoma [Member]
Federal:
Current	$ (109.6)		(11.4)	25.5
Deferred	105.6		8.3	(26)
Total Federal	(4)		(3.1)	(0.5)
Current	0		0.1	0.2
Deferred	8.1		8.2	7.8
Total State and Local	8.1		8.3	8
Income Tax Expense (Benefit):
Income Tax Expense (Benefit)	4.1		5.2	7.5
Reconciliation of Federal Income Taxes and Amount of Income Tax Reported
Net Income	141.1		123	137.6
Income Tax Expense (Benefit)	4.1		5.2	7.5
Pretax Income	145.2		128.2	145.1
Income Taxes on Pretax Income at Statutory Rate (21%)	$ 30.5		$ 26.9	$ 30.5
Federal Statutory Income Tax Rate	21.00%		21.00%	21.00%
Reconciliation of Federal Statutory Rate and Amount of Taxes Reported
Investment Tax Credit Amortization	$ (1.8)		$ (2.1)	$ (0.5)
Production Tax Credits	(6)		0	0
State and Local Income Taxes, Net	6.4		6.5	6.3
Parent Company Loss Benefit	0		(0.2)	(2.1)
Tax Reform Excess ADIT Reversal	(25.4)		(25.5)	(24.5)
Other	0.4		(0.4)	(2.2)
Income Tax Expense (Benefit)	$ 4.1		$ 5.2	$ 7.5
Effective Income Tax Rate	2.80%		4.10%	5.20%
Net Deferred Tax Liability and Significant Temporary Differences
Deferred Tax Assets	$ 170		$ 239.8
Deferred Tax Liabilities	(952.3)		(928.3)
Property Related Temporary Differences	(708.6)		(661.8)
Amounts Due from Customers for Future Federal Income Taxes	111.5		118.5
Deferred State Income Taxes	(83.2)		(107.7)
Regulatory Assets	(228)		(39.1)
Net Operating Loss Carryforward	111.4		12.9
All Other, Net	14.6		(11.3)
Net Deferred Tax Liabilities	(782.3)		(688.5)
Income Taxes (Textuals) [Abstract]
Income Tax Expense (Benefit)	4.1		5.2	$ 7.5
Operating Income (Loss)	$ (192.9)		(175.9)	(199.3)
Public Service Co Of Oklahoma [Member] \| Minimum [Member]
Income Taxes (Textuals) [Abstract]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2036
Public Service Co Of Oklahoma [Member] \| Maximum [Member]
Income Taxes (Textuals) [Abstract]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2040
Southwestern Electric Power Co [Member]
Federal:
Current	$ (16.7)		(13.6)	6.9
Deferred	26.2		19.6	(10)
Total Federal	9.5		6	(3.1)
Current	0.4		(8.2)	0.8
Deferred	(10.5)		11.6	(2.4)
Total State and Local	(10.1)		3.4	(1.6)
Income Tax Expense (Benefit):
Income Tax Expense (Benefit)	(0.6)		9.4	(4.7)
Reconciliation of Federal Income Taxes and Amount of Income Tax Reported
Net Income	242.1		183.7	162.2
Less: Equity Earnings – Dolet Hills	(3.4)		(2.9)	(3)
Income Tax Expense (Benefit)	(0.6)		9.4	(4.7)
Pretax Income	238.1		190.2	154.5
Income Taxes on Pretax Income at Statutory Rate (21%)	$ 50		$ 39.9	$ 32.4
Federal Statutory Income Tax Rate	21.00%		21.00%	21.00%
Reconciliation of Federal Statutory Rate and Amount of Taxes Reported
Depreciation	$ 1.8		$ 1.9	$ 1.9
Depletion	(2.7)		(3.4)	(3.4)
Production Tax Credits	(7.2)		0	0
State and Local Income Taxes, Net	(8)		2.7	(1.3)
Parent Company Loss Benefit	0		(5.6)	(1.6)
Tax Reform Excess ADIT Reversal	(31.1)		(21.9)	(29.9)
Other	(3.4)		(4.2)	(2.8)
Income Tax Expense (Benefit)	$ (0.6)		$ 9.4	$ (4.7)
Effective Income Tax Rate	(0.30%)		4.90%	(3.00%)
Net Deferred Tax Liability and Significant Temporary Differences
Deferred Tax Assets	$ 336.4		$ 338.1
Deferred Tax Liabilities	(1,424)		(1,355.7)
Property Related Temporary Differences	(989.6)		(985.1)
Amounts Due from Customers for Future Federal Income Taxes	154.8		162.7
Deferred State Income Taxes	(234.9)		(214.7)
Regulatory Assets	(101.4)		(26.2)
Net Operating Loss Carryforward	67.4		33.4
All Other, Net	16.1		12.3
Net Deferred Tax Liabilities	(1,087.6)		(1,017.6)
Income Taxes (Textuals) [Abstract]
Income Tax Expense (Benefit)	(0.6)		9.4	$ (4.7)
Operating Income (Loss)	$ (339.5)		(290.5)	(255.7)
Southwestern Electric Power Co [Member] \| Minimum [Member]
Income Taxes (Textuals) [Abstract]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2036
Southwestern Electric Power Co [Member] \| Maximum [Member]
Income Taxes (Textuals) [Abstract]
Tax Credit Carryforward, Expiration Date	Dec. 31, 2040
Arkansas
Net Income Tax Operating Loss Carryforwards
Net Income Tax Operating Loss Carryforward	$ 161.8
Arkansas \| Minimum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2022
Arkansas \| Maximum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2031
Arkansas \| Southwestern Electric Power Co [Member]
Net Income Tax Operating Loss Carryforwards
Net Income Tax Operating Loss Carryforward	$ 160.7
Arkansas \| Southwestern Electric Power Co [Member] \| Minimum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2022
Arkansas \| Southwestern Electric Power Co [Member] \| Maximum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2031
Kentucky
Net Income Tax Operating Loss Carryforwards
Net Income Tax Operating Loss Carryforward	$ 230.4
Kentucky \| Minimum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2030
Kentucky \| Maximum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2037
Louisiana
Net Income Tax Operating Loss Carryforwards
Net Income Tax Operating Loss Carryforward	$ 566.7
Louisiana \| Southwestern Electric Power Co [Member]
Net Income Tax Operating Loss Carryforwards
Net Income Tax Operating Loss Carryforward	554.7
Oklahoma
Net Income Tax Operating Loss Carryforwards
Net Income Tax Operating Loss Carryforward	$ 1,357.1
Oklahoma \| Minimum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2034
Oklahoma \| Maximum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2037
Oklahoma \| AEP Transmission Co [Member]
Net Income Tax Operating Loss Carryforwards
Net Income Tax Operating Loss Carryforward	$ 107.8
Oklahoma \| AEP Transmission Co [Member] \| Minimum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2034
Oklahoma \| AEP Transmission Co [Member] \| Maximum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2037
Oklahoma \| Public Service Co Of Oklahoma [Member]
Net Income Tax Operating Loss Carryforwards
Net Income Tax Operating Loss Carryforward	$ 1,229.8
Oklahoma \| Public Service Co Of Oklahoma [Member] \| Minimum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2034
Oklahoma \| Public Service Co Of Oklahoma [Member] \| Maximum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2037
Tennessee
Net Income Tax Operating Loss Carryforwards
Net Income Tax Operating Loss Carryforward	$ 53
Tennessee \| Minimum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2030
Tennessee \| Maximum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2036
Virginia
Net Income Tax Operating Loss Carryforwards
Net Income Tax Operating Loss Carryforward	$ 20.9
Virginia \| Minimum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2030
Virginia \| Maximum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2037
West Virginia
Net Income Tax Operating Loss Carryforwards
Net Income Tax Operating Loss Carryforward	$ 99.5
West Virginia \| Minimum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2029
West Virginia \| Maximum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2037
West Virginia \| Appalachian Power Co [Member]
Net Income Tax Operating Loss Carryforwards
Net Income Tax Operating Loss Carryforward	$ 62.9
Ohio Municipal
Net Income Tax Operating Loss Carryforwards
Net Income Tax Operating Loss Carryforward	$ 1,027.9
Ohio Municipal \| Minimum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2022
Ohio Municipal \| Maximum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2026
Ohio Municipal \| Ohio Power Co [Member]
Net Income Tax Operating Loss Carryforwards
Net Income Tax Operating Loss Carryforward	$ 76
Ohio Municipal \| Ohio Power Co [Member] \| Minimum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2022
Ohio Municipal \| Ohio Power Co [Member] \| Maximum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2026
Indiana
Net Income Tax Operating Loss Carryforwards
Net Income Tax Operating Loss Carryforward	$ 304.4
Colorado
Net Income Tax Operating Loss Carryforwards
Net Income Tax Operating Loss Carryforward	$ 82.8
Pennsylvania \| Minimum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2030
Pennsylvania \| Maximum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2041
Illinois
Net Income Tax Operating Loss Carryforwards
Net Income Tax Operating Loss Carryforward	$ 55.2
Federal
Tax Credit Carryforward
Tax Credit Carryforward, Amount	439.8
Federal \| AEP Texas Inc. [Member]
Tax Credit Carryforward
Tax Credit Carryforward, Amount	0.3
Federal \| AEP Transmission Co [Member]
Tax Credit Carryforward
Tax Credit Carryforward, Amount	0.1
Federal \| Appalachian Power Co [Member]
Tax Credit Carryforward
Tax Credit Carryforward, Amount	1.3
Federal \| Indiana Michigan Power Co [Member]
Tax Credit Carryforward
Tax Credit Carryforward, Amount	16.9
Federal \| Ohio Power Co [Member]
Tax Credit Carryforward
Tax Credit Carryforward, Amount	0.4
Federal \| Public Service Co Of Oklahoma [Member]
Tax Credit Carryforward
Tax Credit Carryforward, Amount	6.3
Federal \| Southwestern Electric Power Co [Member]
Tax Credit Carryforward
Tax Credit Carryforward, Amount	7.9
State and Local Jurisdiction
Tax Credit Carryforward
Tax Credit Carryforward, Amount	38.8
Income Taxes (Textuals) [Abstract]
Valuation Allowance	25
State and Local Jurisdiction \| AEP Texas Inc. [Member]
Tax Credit Carryforward
Tax Credit Carryforward, Amount	0
State and Local Jurisdiction \| AEP Transmission Co [Member]
Tax Credit Carryforward
Tax Credit Carryforward, Amount	0
State and Local Jurisdiction \| Appalachian Power Co [Member]
Tax Credit Carryforward
Tax Credit Carryforward, Amount	0
State and Local Jurisdiction \| Indiana Michigan Power Co [Member]
Tax Credit Carryforward
Tax Credit Carryforward, Amount	0
State and Local Jurisdiction \| Ohio Power Co [Member]
Tax Credit Carryforward
Tax Credit Carryforward, Amount	0
State and Local Jurisdiction \| Public Service Co Of Oklahoma [Member]
Tax Credit Carryforward
Tax Credit Carryforward, Amount	38.8
State and Local Jurisdiction \| Southwestern Electric Power Co [Member]
Tax Credit Carryforward
Tax Credit Carryforward, Amount	0
MICHIGAN
Net Income Tax Operating Loss Carryforwards
Net Income Tax Operating Loss Carryforward	$ 65.2
MICHIGAN \| Minimum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2029
MICHIGAN \| Maximum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2031
NEW JERSEY
Net Income Tax Operating Loss Carryforwards
Net Income Tax Operating Loss Carryforward	$ 36.5
NEW JERSEY \| Minimum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2036
NEW JERSEY \| Maximum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2041
NEW MEXICO
Net Income Tax Operating Loss Carryforwards
Net Income Tax Operating Loss Carryforward	$ 32.6
NEW MEXICO \| Minimum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2037
NEW MEXICO \| Maximum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2039
PENNSYLVANIA
Net Income Tax Operating Loss Carryforwards
Net Income Tax Operating Loss Carryforward	$ 82.7
COLORADO \| Minimum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2041
COLORADO \| Maximum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2041
ILLINOIS \| Minimum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2031
ILLINOIS \| Maximum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2041
INDIANA \| Minimum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2039
INDIANA \| Maximum [Member]
Net Income Tax Operating Loss Carryforwards
Operating Loss Carryforwards, Expiration Date	Dec. 31, 2041
Dolet Hills Lignite Co, LLC [Member]
Reconciliation of Federal Income Taxes and Amount of Income Tax Reported
Less: Equity Earnings – Dolet Hills	$ (3.4)		(2.9)	(3)
Dolet Hills Lignite Co, LLC [Member] \| Southwestern Electric Power Co [Member]
Reconciliation of Federal Income Taxes and Amount of Income Tax Reported
Less: Equity Earnings – Dolet Hills	$ (3.4)		$ (2.9)	$ (3)

[1]	Benefit at AEP is primarily due to an out of period adjustment related to Deferred Income Taxes and Income Tax Expense (Benefit). Management concluded the misstatement and subsequent correction was not material to prior or current period financial statements.
[2]	Represents an out of period adjustment related to Deferred Income Taxes and Income Tax Expense (Benefit). Management concluded the misstatement and subsequent correction was not material to prior or current period financial statements.

Leases (Details)

Leases (Details) - USD ($) $ in Millions		12 Months Ended
Leases (Details) - USD ($) $ in Millions		Dec. 31, 2021		Dec. 31, 2020	Dec. 31, 2019
Lease Rental Costs
Operating Lease, Cost		$ 275.3		$ 279.6	$ 286
Finance Lease Right-of-Use Asset Amortization		74.7		61.9	70.8
Interest Expense on Finance Leases		14.4		15.4	16.4
Total Lease Rental Costs	[1]	$ 364.4		$ 356.9	373.2
Supplemental Information Related to Leases
Weighted-Average Remaining Lease Term, Operating Leases		10 years 4 months 20 days		5 years 3 months 18 days
Weighted Average Remaining Lease Term, Finance Leases		2 years 11 months 12 days		5 years 5 months 4 days
Weighted Average Discount Rate, Operating Leases		3.35%		3.44%
Weighted Average Discount Rate, Finance Leases		3.26%		5.68%
Operating Cash Flows Used for Operating Leases		$ 279.9		$ 280.3
Operating Cash Flows Used for Finance Leases		14.3		15.4
Financing Cash Flows Used for Finance Leases		64		61.7	70.7
Non-cash Acquisitions Under Operating Leases		117		161.7
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Generation		23,088.1		23,133.9
Other Property, Plant and Equipment		5,682.9		5,294.6
Total Property, Plant and Equipment		86,806.4		84,313
Accumulated Amortization		20,805.1		20,411.4
Net Property, Plant and Equipment Under Finance Leases		490.2	[2]	284.2
Other Liabilities, Noncurrent		601.3		728
Finance Lease Liability Due Within One Year		1,369.2		1,251.9
Total Obligations Under Finance Leases		500.7	[3]	289.1
Operating Lease Asset and Related Obligations
Operating Lease Assets		578.3		866.4
Operating Lease Noncurrent Liability		492.8		638.4
Operating Lease Liability Due Within One Year		97.6		241.3
Estimated Present Value of Future Minimum Lease Payments on Operating Leases		590.4	[4]	879.7
Finance Lease Liabilities Rolling Future Minimum Lease Payments
Year 1		317.3
Year 2		61
Year 3		64.7
Year 4		35.6
Year 5		20.1
Finance Leases, Later Years		39.2
Finance Leases, Total Future Minimum Lease Payments		537.9
Imputed Interest on Finance Leases		37.2
Total Obligations Under Finance Leases		500.7	[3]	289.1
Operating Lease Liabilities Rolling Future Minimum Lease Payments
Year 1		119.6
Year 2		102.2
Year 3		89.9
Year 4		76.7
Year 5		64
Operating Leases, Later Years		272.4
Operating Leases, Total Future Minimum Lease Payments		724.8
Imputed Interest on Operating Leases		134.4
Estimated Present Value of Future Minimum Lease Payments on Operating Leases		590.4	[4]	879.7
Maximum Potential Loss
Max Potential Loss on Master Lease Agreements		47.4
Leases (Textuals)
Assets Held for Sale		2,919.7		0
Liabilities Held for Sale		1,880.9		0
Liabilities Held for Sale		1,880.9		0
Kentucky Power Co [Member]
Leases (Textuals)
Liabilities Held for Sale		3
Liabilities Held for Sale		3
Kentucky Power Co [Member]
Leases (Textuals)
Assets Held for Sale		3
Kentucky Power Co [Member]
Leases (Textuals)
Liabilities Held for Sale		11
Liabilities Held for Sale		11
Kentucky Power Co [Member]
Leases (Textuals)
Assets Held for Sale		11
Rockport Lease [Member]
Future Minimum Rentals, Sale Leaseback Transactions
2022	[5]	248.7
Total Future Minimum Lease Payments	[5]	248.7
Boat and Barge Leases [Member]
Leases (Textuals)
Maximum Potential Lease Payments, AEPRO Barge and Boat Leases		42
Guarantor Obligations, Current Carrying Value		2
Guarantee Obligations Current Carrying Value Other Liabilities Current		1
Guarantee Obligations Current Carrying Value Other Liabilities Noncurrent		1
Finance Lease Assets [Member]
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Generation		388.8		138.2
Other Property, Plant and Equipment		323.8		322.8
Total Property, Plant and Equipment		712.6		461
Accumulated Amortization		222.4		176.8
Finance Lease Liabilities [Member]
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Other Liabilities, Noncurrent		196.1		231
Finance Lease Liability Due Within One Year		304.6		58.1
Operating Lease Assets [Member]
Operating Lease Asset and Related Obligations
Operating Lease Assets		578.3	[6]	866.4
AEP Texas Inc. [Member]
Lease Rental Costs
Operating Lease, Cost		18.4		17.4	16.5
Finance Lease Right-of-Use Asset Amortization		6.7		6.3	5.1
Interest Expense on Finance Leases		1.4		1.5	1.4
Total Lease Rental Costs	[1]	$ 26.5		$ 25.2	23
Supplemental Information Related to Leases
Weighted-Average Remaining Lease Term, Operating Leases		5 years 10 months 28 days		6 years 6 months 3 days
Weighted Average Remaining Lease Term, Finance Leases		5 years 6 months 3 days		6 years 25 days
Weighted Average Discount Rate, Operating Leases		3.53%		3.60%
Weighted Average Discount Rate, Finance Leases		4.31%		4.39%
Operating Cash Flows Used for Operating Leases		$ 18		$ 17.1
Operating Cash Flows Used for Finance Leases		1.4		1.5
Financing Cash Flows Used for Finance Leases		6.7		6.3	5.1
Non-cash Acquisitions Under Operating Leases		4.4		15.8
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Other Property, Plant and Equipment		961.1		868.4
Total Property, Plant and Equipment		12,279.5		11,342.9
Accumulated Amortization		1,644.1		1,529.3
Net Property, Plant and Equipment Under Finance Leases		30.8		33.1
Other Liabilities, Noncurrent		73.8		57.2
Finance Lease Liability Due Within One Year		78		108.6
Total Obligations Under Finance Leases		30.8		33.1
Operating Lease Asset and Related Obligations
Operating Lease Noncurrent Liability		61.3		71
Operating Lease Liability Due Within One Year		14		14.5
Estimated Present Value of Future Minimum Lease Payments on Operating Leases		75.3		85.5
Finance Lease Liabilities Rolling Future Minimum Lease Payments
Year 1		7.8
Year 2		7.1
Year 3		5.9
Year 4		4.5
Year 5		3.5
Finance Leases, Later Years		5.9
Finance Leases, Total Future Minimum Lease Payments		34.7
Imputed Interest on Finance Leases		3.9
Total Obligations Under Finance Leases		30.8		33.1
Operating Lease Liabilities Rolling Future Minimum Lease Payments
Year 1		16.7
Year 2		15.5
Year 3		14.1
Year 4		11.7
Year 5		9.5
Operating Leases, Later Years		16.9
Operating Leases, Total Future Minimum Lease Payments		84.4
Imputed Interest on Operating Leases		9.1
Estimated Present Value of Future Minimum Lease Payments on Operating Leases		75.3		85.5
Maximum Potential Loss
Max Potential Loss on Master Lease Agreements		11.1
AEP Texas Inc. [Member] \| Finance Lease Assets [Member]
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Generation		0		0
Other Property, Plant and Equipment		50.7		49.7
Total Property, Plant and Equipment		50.7		49.7
Accumulated Amortization		19.9		16.6
AEP Texas Inc. [Member] \| Finance Lease Liabilities [Member]
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Other Liabilities, Noncurrent		24.2		26.8
Finance Lease Liability Due Within One Year		6.6		6.3
AEP Texas Inc. [Member] \| Operating Lease Assets [Member]
Operating Lease Asset and Related Obligations
Operating Lease Assets		73.6		84.1
AEP Transmission Co [Member]
Lease Rental Costs
Operating Lease, Cost		1.7		2.6	2.5
Finance Lease Right-of-Use Asset Amortization		0		0	0.1
Interest Expense on Finance Leases		0		0	0
Total Lease Rental Costs	[1]	$ 1.7		$ 2.6	2.6
Supplemental Information Related to Leases
Weighted-Average Remaining Lease Term, Operating Leases		2 years 11 months 12 days		2 years 3 days
Weighted Average Remaining Lease Term, Finance Leases		0 years		0 years
Weighted Average Discount Rate, Operating Leases		0.90%		1.51%
Weighted Average Discount Rate, Finance Leases		0.00%		0.00%
Operating Cash Flows Used for Operating Leases		$ 1.6		$ 2.6
Operating Cash Flows Used for Finance Leases		0		0
Financing Cash Flows Used for Finance Leases		0		0
Non-cash Acquisitions Under Operating Leases		2.1		1.8
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Other Property, Plant and Equipment		427.4		329.5
Total Property, Plant and Equipment		12,708.5		11,345.6
Accumulated Amortization		772.8		572.8
Net Property, Plant and Equipment Under Finance Leases		0		0
Other Liabilities, Noncurrent		3.2		8
Finance Lease Liability Due Within One Year		3		9.9
Total Obligations Under Finance Leases		0		0
Operating Lease Asset and Related Obligations
Operating Lease Noncurrent Liability		1.3		0.4
Operating Lease Liability Due Within One Year		0.9		1.2
Estimated Present Value of Future Minimum Lease Payments on Operating Leases		2.2		1.6
Finance Lease Liabilities Rolling Future Minimum Lease Payments
Year 1		0
Year 2		0
Year 3		0
Year 4		0
Year 5		0
Finance Leases, Later Years		0
Finance Leases, Total Future Minimum Lease Payments		0
Imputed Interest on Finance Leases		0
Total Obligations Under Finance Leases		0		0
Operating Lease Liabilities Rolling Future Minimum Lease Payments
Year 1		0.9
Year 2		0.7
Year 3		0.4
Year 4		0.2
Year 5		0
Operating Leases, Later Years		0
Operating Leases, Total Future Minimum Lease Payments		2.2
Imputed Interest on Operating Leases		0
Estimated Present Value of Future Minimum Lease Payments on Operating Leases		2.2		1.6
Leases (Textuals)
Assets Held for Sale		167.9		0
Liabilities Held for Sale		27.6		0
Liabilities Held for Sale		27.6		0
AEP Transmission Co [Member] \| Finance Lease Assets [Member]
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Generation		0		0
Other Property, Plant and Equipment		0		0
Total Property, Plant and Equipment		0		0
Accumulated Amortization		0		0
AEP Transmission Co [Member] \| Finance Lease Liabilities [Member]
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Other Liabilities, Noncurrent		0		0
Finance Lease Liability Due Within One Year		0		0
AEP Transmission Co [Member] \| Operating Lease Assets [Member]
Operating Lease Asset and Related Obligations
Operating Lease Assets		2		1.6
Appalachian Power Co [Member]
Lease Rental Costs
Operating Lease, Cost		19.3		19.1	19.5
Finance Lease Right-of-Use Asset Amortization		7.7		7.4	6.7
Interest Expense on Finance Leases		2.4		2.7	2.9
Total Lease Rental Costs	[1]	$ 29.4		$ 29.2	29.1
Supplemental Information Related to Leases
Weighted-Average Remaining Lease Term, Operating Leases		5 years 8 months 4 days		6 years 3 months 7 days
Weighted Average Remaining Lease Term, Finance Leases		4 years 11 months 19 days		5 years 9 months
Weighted Average Discount Rate, Operating Leases		3.42%		3.48%
Weighted Average Discount Rate, Finance Leases		7.16%		7.33%
Operating Cash Flows Used for Operating Leases		$ 19.3		$ 19.2
Operating Cash Flows Used for Finance Leases		2.4		2.7
Financing Cash Flows Used for Finance Leases		7.7		7.4	6.7
Non-cash Acquisitions Under Operating Leases		4.2		16.2
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Generation		6,683.9		6,633.7
Other Property, Plant and Equipment		696.6		627.2
Total Property, Plant and Equipment		16,856.1		16,110.3
Accumulated Amortization		5,051.8		4,716.2
Net Property, Plant and Equipment Under Finance Leases		35.7		41.7
Other Liabilities, Noncurrent		34.6		49.6
Finance Lease Liability Due Within One Year		146.4		169.1
Total Obligations Under Finance Leases		35.7		41.7
Operating Lease Asset and Related Obligations
Operating Lease Assets		66.9		78.8
Operating Lease Noncurrent Liability		52.4		64.4
Operating Lease Liability Due Within One Year		15.1		14.9
Estimated Present Value of Future Minimum Lease Payments on Operating Leases		67.5		79.3
Finance Lease Liabilities Rolling Future Minimum Lease Payments
Year 1		9.8
Year 2		9.1
Year 3		8.3
Year 4		7.2
Year 5		2.7
Finance Leases, Later Years		4.1
Finance Leases, Total Future Minimum Lease Payments		41.2
Imputed Interest on Finance Leases		5.5
Total Obligations Under Finance Leases		35.7		41.7
Operating Lease Liabilities Rolling Future Minimum Lease Payments
Year 1		17.5
Year 2		14.8
Year 3		11.9
Year 4		9.1
Year 5		7.2
Operating Leases, Later Years		14.1
Operating Leases, Total Future Minimum Lease Payments		74.6
Imputed Interest on Operating Leases		7.1
Estimated Present Value of Future Minimum Lease Payments on Operating Leases		67.5		79.3
Maximum Potential Loss
Max Potential Loss on Master Lease Agreements		6.2
Appalachian Power Co [Member] \| Finance Lease Assets [Member]
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Generation		42.8		42.8
Other Property, Plant and Equipment		20.4		20.3
Total Property, Plant and Equipment		63.2		63.1
Accumulated Amortization		27.5		21.4
Appalachian Power Co [Member] \| Finance Lease Liabilities [Member]
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Other Liabilities, Noncurrent		28.1		34.4
Finance Lease Liability Due Within One Year		7.6		7.3
Appalachian Power Co [Member] \| Operating Lease Assets [Member]
Operating Lease Asset and Related Obligations
Operating Lease Assets		66.9		78.8
Indiana Michigan Power Co [Member]
Lease Rental Costs
Operating Lease, Cost		90.2		101.5	93.1
Finance Lease Right-of-Use Asset Amortization		12.9		6.5	5.7
Interest Expense on Finance Leases		3		3.1	2.9
Total Lease Rental Costs	[1]	$ 106.1		$ 111.1	101.7
Supplemental Information Related to Leases
Weighted-Average Remaining Lease Term, Operating Leases		5 years 10 months 13 days		3 years 6 months
Weighted Average Remaining Lease Term, Finance Leases		2 years 1 month 6 days		5 years 9 months 14 days
Weighted Average Discount Rate, Operating Leases		3.46%		3.42%
Weighted Average Discount Rate, Finance Leases		3.02%		8.29%
Operating Cash Flows Used for Operating Leases		$ 92.9		$ 102.2
Operating Cash Flows Used for Finance Leases		2.9		3.1
Financing Cash Flows Used for Finance Leases		6.8		6.5	5.7
Non-cash Acquisitions Under Operating Leases		2.6		18.1
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Generation		5,531.8		5,264.7
Other Property, Plant and Equipment		792.9		686.7
Total Property, Plant and Equipment		11,210.7		10,604.8
Accumulated Amortization		3,899.8		3,552.5
Net Property, Plant and Equipment Under Finance Leases		160.7		41.7
Other Liabilities, Noncurrent		58.3		69.2
Finance Lease Liability Due Within One Year		123.2		105.5
Total Obligations Under Finance Leases		162.2		41.7
Operating Lease Asset and Related Obligations
Operating Lease Assets		63.5		218.1
Operating Lease Noncurrent Liability		48.9		135.9
Operating Lease Liability Due Within One Year		15.5		85.6
Estimated Present Value of Future Minimum Lease Payments on Operating Leases		64.4		221.5
Finance Lease Liabilities Rolling Future Minimum Lease Payments
Year 1		133.7
Year 2		8.6
Year 3		11.6
Year 4		5.9
Year 5		3.5
Finance Leases, Later Years		10.1
Finance Leases, Total Future Minimum Lease Payments		173.4
Imputed Interest on Finance Leases		11.2
Total Obligations Under Finance Leases		162.2		41.7
Operating Lease Liabilities Rolling Future Minimum Lease Payments
Year 1		17.6
Year 2		11.7
Year 3		10.4
Year 4		9.3
Year 5		7.3
Operating Leases, Later Years		15
Operating Leases, Total Future Minimum Lease Payments		71.3
Imputed Interest on Operating Leases		6.9
Estimated Present Value of Future Minimum Lease Payments on Operating Leases		64.4		221.5
Maximum Potential Loss
Max Potential Loss on Master Lease Agreements		4.1
Indiana Michigan Power Co [Member] \| Rockport Lease [Member]
Future Minimum Rentals, Sale Leaseback Transactions
2022		124.4
Total Future Minimum Lease Payments		124.4
Indiana Michigan Power Co [Member] \| Finance Lease Assets [Member]
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Generation		156.8		28.8
Other Property, Plant and Equipment		42.1		40.2
Total Property, Plant and Equipment		198.9		69
Accumulated Amortization		38.2		27.3
Indiana Michigan Power Co [Member] \| Finance Lease Liabilities [Member]
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Other Liabilities, Noncurrent		31.7		35.3
Finance Lease Liability Due Within One Year		130.5		6.4
Indiana Michigan Power Co [Member] \| Operating Lease Assets [Member]
Operating Lease Asset and Related Obligations
Operating Lease Assets		63.5		218.1
Ohio Power Co [Member]
Lease Rental Costs
Operating Lease, Cost		19		17.1	18
Finance Lease Right-of-Use Asset Amortization		4.9		4.7	3.5
Interest Expense on Finance Leases		0.8		0.9	0.7
Total Lease Rental Costs	[1]	$ 24.7		$ 22.7	22.2
Supplemental Information Related to Leases
Weighted-Average Remaining Lease Term, Operating Leases		6 years 8 months 8 days		7 years 5 months 8 days
Weighted Average Remaining Lease Term, Finance Leases		5 years 6 months 14 days		5 years 10 months 24 days
Weighted Average Discount Rate, Operating Leases		3.56%		3.60%
Weighted Average Discount Rate, Finance Leases		4.19%		4.25%
Operating Cash Flows Used for Operating Leases		$ 19		$ 16.9
Operating Cash Flows Used for Finance Leases		0.8		0.9
Financing Cash Flows Used for Finance Leases		4.9		4.7	3.5
Non-cash Acquisitions Under Operating Leases		4.2		18.1
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Other Property, Plant and Equipment		992.9		899.6
Total Property, Plant and Equipment		10,421.3		9,802.1
Accumulated Amortization		2,458.3		2,350
Net Property, Plant and Equipment Under Finance Leases		19.3		21.6
Other Liabilities, Noncurrent		29.2		40
Finance Lease Liability Due Within One Year		118.1		139.6
Total Obligations Under Finance Leases		19.3		21.6
Operating Lease Asset and Related Obligations
Operating Lease Assets		81.2		92
Operating Lease Noncurrent Liability		68.6		79.5
Operating Lease Liability Due Within One Year		13.1		13.1
Estimated Present Value of Future Minimum Lease Payments on Operating Leases		81.7		92.6
Finance Lease Liabilities Rolling Future Minimum Lease Payments
Year 1		5.1
Year 2		4.4
Year 3		3.7
Year 4		2.5
Year 5		2
Finance Leases, Later Years		4
Finance Leases, Total Future Minimum Lease Payments		21.7
Imputed Interest on Finance Leases		2.4
Total Obligations Under Finance Leases		19.3		21.6
Operating Lease Liabilities Rolling Future Minimum Lease Payments
Year 1		16.2
Year 2		15.2
Year 3		13.8
Year 4		12.1
Year 5		11
Operating Leases, Later Years		24.2
Operating Leases, Total Future Minimum Lease Payments		92.5
Imputed Interest on Operating Leases		10.8
Estimated Present Value of Future Minimum Lease Payments on Operating Leases		81.7		92.6
Maximum Potential Loss
Max Potential Loss on Master Lease Agreements		7.5
Ohio Power Co [Member] \| Finance Lease Assets [Member]
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Generation		0		0
Other Property, Plant and Equipment		32.1		31.4
Total Property, Plant and Equipment		32.1		31.4
Accumulated Amortization		12.8		9.8
Ohio Power Co [Member] \| Finance Lease Liabilities [Member]
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Other Liabilities, Noncurrent		14.9		16.9
Finance Lease Liability Due Within One Year		4.4		4.7
Ohio Power Co [Member] \| Operating Lease Assets [Member]
Operating Lease Asset and Related Obligations
Operating Lease Assets		81.2		92
Public Service Co Of Oklahoma [Member]
Lease Rental Costs
Operating Lease, Cost		8.7		7.8	6.8
Finance Lease Right-of-Use Asset Amortization		3.2		3.5	3.1
Interest Expense on Finance Leases		0.6		0.7	0.6
Total Lease Rental Costs	[1]	$ 12.5		$ 12	10.5
Supplemental Information Related to Leases
Weighted-Average Remaining Lease Term, Operating Leases		20 years 10 months 20 days		7 years 10 days
Weighted Average Remaining Lease Term, Finance Leases		6 years 2 months 4 days		6 years 1 month 28 days
Weighted Average Discount Rate, Operating Leases		3.35%		3.39%
Weighted Average Discount Rate, Finance Leases		4.23%		4.35%
Operating Cash Flows Used for Operating Leases		$ 8.7		$ 7.7
Operating Cash Flows Used for Finance Leases		0.6		0.7
Financing Cash Flows Used for Finance Leases		3.2		3.5	3.1
Non-cash Acquisitions Under Operating Leases		33.4		12.3
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Generation		1,802.4		1,480.7
Other Property, Plant and Equipment		437		393.3
Total Property, Plant and Equipment		6,508		5,925.6
Accumulated Amortization		1,705.2		1,605.6
Net Property, Plant and Equipment Under Finance Leases		15.3		15
Other Liabilities, Noncurrent		19.4		20.6
Finance Lease Liability Due Within One Year		62.7		84.2
Total Obligations Under Finance Leases		15.3		15
Operating Lease Asset and Related Obligations
Operating Lease Assets		68.9		42.6
Operating Lease Noncurrent Liability		62.2		36.2
Operating Lease Liability Due Within One Year		6.9		6.5
Estimated Present Value of Future Minimum Lease Payments on Operating Leases		69.1		42.7
Finance Lease Liabilities Rolling Future Minimum Lease Payments
Year 1		3.6
Year 2		3.3
Year 3		2.8
Year 4		2.1
Year 5		1.8
Finance Leases, Later Years		3.9
Finance Leases, Total Future Minimum Lease Payments		17.5
Imputed Interest on Finance Leases		2.2
Total Obligations Under Finance Leases		15.3		15
Operating Lease Liabilities Rolling Future Minimum Lease Payments
Year 1		9.2
Year 2		8.9
Year 3		8.1
Year 4		6.9
Year 5		6
Operating Leases, Later Years		62.6
Operating Leases, Total Future Minimum Lease Payments		101.7
Imputed Interest on Operating Leases		32.6
Estimated Present Value of Future Minimum Lease Payments on Operating Leases		69.1		42.7
Maximum Potential Loss
Max Potential Loss on Master Lease Agreements		4.6
Public Service Co Of Oklahoma [Member] \| Finance Lease Assets [Member]
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Generation		0.6		0.7
Other Property, Plant and Equipment		23.9		23
Total Property, Plant and Equipment		24.5		23.7
Accumulated Amortization		9.2		8.7
Public Service Co Of Oklahoma [Member] \| Finance Lease Liabilities [Member]
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Other Liabilities, Noncurrent		12.3		11.9
Finance Lease Liability Due Within One Year		3		3.1
Public Service Co Of Oklahoma [Member] \| Operating Lease Assets [Member]
Operating Lease Asset and Related Obligations
Operating Lease Assets		68.9		42.6
Southwestern Electric Power Co [Member]
Lease Rental Costs
Operating Lease, Cost		12.1		9.4	8
Finance Lease Right-of-Use Asset Amortization		11		10.9	11
Interest Expense on Finance Leases		2.5		2.2	2.9
Total Lease Rental Costs	[1]	$ 25.6		$ 22.5	21.9
Supplemental Information Related to Leases
Weighted-Average Remaining Lease Term, Operating Leases		20 years 2 months 26 days		7 years 6 months 14 days
Weighted Average Remaining Lease Term, Finance Leases		4 years 6 months 10 days		4 years 11 months 12 days
Weighted Average Discount Rate, Operating Leases		3.34%		3.45%
Weighted Average Discount Rate, Finance Leases		4.68%		4.77%
Operating Cash Flows Used for Operating Leases		$ 11.6		$ 9.4
Operating Cash Flows Used for Finance Leases		2.5		2.2
Financing Cash Flows Used for Finance Leases		10.9		10.9	$ 11
Non-cash Acquisitions Under Operating Leases		42.9		18.4
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Generation		4,734.5		4,681.4
Other Property, Plant and Equipment		764		788.8
Total Property, Plant and Equipment		10,570.4		10,246.7
Accumulated Amortization		3,170.3		3,158.5
Net Property, Plant and Equipment Under Finance Leases		42.2		53.6
Other Liabilities, Noncurrent		63		95.2
Finance Lease Liability Due Within One Year		154.6		173.4
Total Obligations Under Finance Leases		49.7		55.3
Operating Lease Asset and Related Obligations
Operating Lease Noncurrent Liability		77.7		44.1
Operating Lease Liability Due Within One Year		8.1		7.9
Estimated Present Value of Future Minimum Lease Payments on Operating Leases		85.8		52
Finance Lease Liabilities Rolling Future Minimum Lease Payments
Year 1		12.6
Year 2		11.8
Year 3		15.9
Year 4		5.6
Year 5		2.3
Finance Leases, Later Years		6
Finance Leases, Total Future Minimum Lease Payments		54.2
Imputed Interest on Finance Leases		4.5
Total Obligations Under Finance Leases		49.7		55.3
Operating Lease Liabilities Rolling Future Minimum Lease Payments
Year 1		13
Year 2		11.8
Year 3		10
Year 4		8.7
Year 5		7.5
Operating Leases, Later Years		80.4
Operating Leases, Total Future Minimum Lease Payments		131.4
Imputed Interest on Operating Leases		45.6
Estimated Present Value of Future Minimum Lease Payments on Operating Leases		85.8		52
Maximum Potential Loss
Max Potential Loss on Master Lease Agreements		5.2
Southwestern Electric Power Co [Member] \| Finance Lease Assets [Member]
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Generation		34.3		37.7
Other Property, Plant and Equipment		55.7		52.4
Total Property, Plant and Equipment		90		90.1
Accumulated Amortization		47.8		36.5
Southwestern Electric Power Co [Member] \| Finance Lease Liabilities [Member]
Property, Plant and Equipment and Other Related Obligations Under Finance Leases
Other Liabilities, Noncurrent		38.9		44.6
Finance Lease Liability Due Within One Year		10.8		10.7
Southwestern Electric Power Co [Member] \| Operating Lease Assets [Member]
Operating Lease Asset and Related Obligations
Operating Lease Assets		$ 80.1		$ 48.5

[1]	Excludes variable and short-term lease costs, which were immaterial.
[2]	Amount excludes $3 million of Net Property, Plant and Equipment Under Finance Leases classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[3]	Amount excludes $3 million of Obligations Under Finance Leases classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[4]	Amount excludes $11 million of Obligations Under Operating Leases classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[5]	(a) AEP’s future minimum lease payments include equal shares from AEGCo and I&M.
[6]	Amount excludes $11 million of Operating Lease Assets classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.

Financing Activities (Details)

Financing Activities (Details) - USD ($)		1 Months Ended		12 Months Ended
Financing Activities (Details) - USD ($)		Feb. 24, 2022	Jan. 31, 2022	Dec. 31, 2021		Dec. 31, 2020		Dec. 31, 2019
Shares of Company
Beginning Balance, Shares			524,416,175	516,808,354		514,373,631		513,450,036
Issued				7,607,821		2,434,723		923,595
Ending Balance, Shares				524,416,175		516,808,354		514,373,631
Treasury Stock, Shares, Beginning Balance			20,204,160	20,204,160		20,204,160		20,204,160
Treasury Stock, Shares, Ending Balance				20,204,160		20,204,160		20,204,160
Long-term Debt
Senior Unsecured Notes				$ 27,497,300,000		$ 25,116,100,000
Pollution Control Bonds	[1]			1,804,500,000		1,936,700,000
Notes Payable	[2]			211,300,000		239,100,000
Securitization Bonds				603,500,000		716,400,000
Spent Nuclear Fuel Obligation	[3]			281,300,000		281,200,000
Junior Subordinated Notes	[4]			2,373,000,000		1,624,100,000
Other Long-term Debt				683,600,000		1,158,900,000
Total Long-term Debt Outstanding				33,454,500,000	[5],[6],[7]	31,072,500,000		$ 26,725,500,000
Outstanding Long-term Debt
Principal Amount, 2021				2,153,800,000
Principal Amount, 2022	[8]			2,629,900,000
Principal Amount, 2023	[9]			1,462,200,000
Principal Amount, 2024				1,762,400,000
Principal Amount, 2025				1,497,900,000
Principal Amount, After 2025				24,246,700,000
Principal Amount, Total				33,752,900,000
Unamortized Discount, Net and Debt Issuance Costs				(298,400,000)
Total Long-term Debt Outstanding				33,454,500,000	[5],[6],[7]	31,072,500,000		$ 26,725,500,000
Short-term Debt
Securitized Debt for Receivables	[10]			750,000,000		592,000,000
Commercial Paper				1,364,000,000		1,852,300,000
Notes Payable				0		35,000,000
Total Short-term Debt				$ 2,614,000,000		$ 2,479,300,000
Securitized Debt for Receivables	[10],[11]			0.19%		0.85%
Other Short-term Borrowings				$ 500,000,000		$ 0
Comparative Accounts Receivable Information
Effective Interest Rates on Securitization of Accounts Receivable				0.19%		0.85%		2.42%
Net Uncollectible Accounts Receivable Written Off				$ 26,500,000		$ 15,300,000		$ 26,600,000
Customer Accounts Receivable Managed Portfolio
Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts				995,200,000		958,400,000
Total Principal Outstanding				750,000,000		592,000,000
Delinquent Securitized Accounts Receivable				57,900,000		62,300,000
Bad Debt Reserves Related to Securitized Sale of Accounts Receivable				42,800,000		60,000,000
Unbilled Receivables Related to Securitization, Sale of Accounts Receivable				307,100,000		296,800,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Revenue from Contracts with Customers				16,792,000,000		14,918,500,000		15,561,400,000
Financing Activities (Textuals)
Repayments of Long-term Debt				2,989,300,000		1,339,800,000		1,220,800,000
Proceeds from Issuance of Long-term Debt				6,486,300,000		5,626,100,000		4,536,600,000
Forward Equity Purchase Contracts Included in Current and Noncurrent Liabilities as of December 31,				$ 47,800,000		(86,200,000)		(7,600,000)
Maximum Percentage Debt to Capitalization				67.50%
Restricted Net Assets				$ 15,500,000,000
Dividend Restrictions	[12]			2,655,200,000
Retained Earnings Available to Pay Dividends				8,200,000,000
Dividends Paid on Common Stock				(1,519,500,000)		(1,424,900,000)		(1,350,000,000)
Credit Facilities, Total				$ 5,000,000,000
Weighted Average Interest Rate of Commercial Paper Outstanding During Year				0.24%
Maximum Amount of Commercial Paper Outstanding				$ 2,500,000,000
Maximum Value of Shares to be Issued Under ATM Program				$ 1,000,000,000
Maximum Percentage Paid to Selling Agents				2.00%
Issuance of Common Stock, Net				$ 600,500,000		155,000,000		65,300,000
Commitment From Bank Conduits to Finance Receivables (One) [Domain]				125,000,000
Commitment from Bank Conduits to Finance Receivables Two				625,000,000
Total Commitment From Bank Conduits To Finance Receivables				750,000,000
Liabilities Held for Sale				1,880,900,000		0
Kentucky Power Co [Member]
Financing Activities (Textuals)
Disposal Group, Including Discontinued Operation, Liabilities				$ 1,100,000,000
Equity Distribution Agreement
Shares of Company
Issued				5,701,825
Financing Activities (Textuals)
Issuance of Common Stock, Net				$ 484,000,000
2019 Equity Units [Member]
Financing Activities (Textuals)
Equity Units Issued				16,100,000
Per Unit Conversion for Equity Units				$ 50
Net Equity Units Issuance Proceeds				785,000,000
Principal Amounts of Junior Subordinated Debt				$ 1,000
Forward Equity Purchase Contract Date				2022
Forward Equity Purchase Contracts Included in Current and Noncurrent Liabilities as of December 31,								47,300,000
Maximum Shares Issued Under Equity Units Conversion				9,701,860
Corporate unit ownership share of an equity unit				5.00%
2020 Equity Units [Member]
Financing Activities (Textuals)
Equity Units Issued				17,000,000
Per Unit Conversion for Equity Units				$ 50
Net Equity Units Issuance Proceeds				833,000,000
Principal Amounts of Junior Subordinated Debt				$ 1,000
Forward Equity Purchase Contract Date				2023
Equity Units Annual Distribution Rate				6.125%
Forward Equity Contract Payment Rate				4.825%
Forward Equity Purchase Contracts Included in Current and Noncurrent Liabilities as of December 31,				$ 0		$ 110,600,000
Maximum Shares Issued Under Equity Units Conversion				10,205,100
Corporate unit ownership share of an equity unit				5.00%
Minimum [Member] \| 2019 Equity Units [Member]
Financing Activities (Textuals)
AEP Share Price for Equity Unit Conversion				$ 82.98
Shares Per Equity Unit				0.5021
Minimum [Member] \| 2020 Equity Units [Member]
Financing Activities (Textuals)
AEP Share Price for Equity Unit Conversion				$ 83.29
Shares Per Equity Unit				0.5003
Maximum [Member] \| 2019 Equity Units [Member]
Financing Activities (Textuals)
AEP Share Price for Equity Unit Conversion				$ 99.58
Shares Per Equity Unit				0.6026
Maximum [Member] \| 2020 Equity Units [Member]
Financing Activities (Textuals)
AEP Share Price for Equity Unit Conversion				$ 99.95
Shares Per Equity Unit				0.6003
Kentucky Transmission Company
Financing Activities (Textuals)
Liabilities Held for Sale				$ 1,000,000
Commercial Paper [Member]
Short-term Debt
Debt, Weighted Average Interest Rate	[11]			0.34%		0.29%
Loans Payable [Member]
Short-term Debt
Debt, Weighted Average Interest Rate	[11]			0.00%		2.55%
364 Day Term Loan
Short-term Debt
Debt, Weighted Average Interest Rate				0.81%		0.00%
AEP Texas Inc. [Member]
Long-term Debt
Senior Unsecured Notes				$ 4,135,500,000		$ 3,687,600,000
Pollution Control Bonds				439,900,000		439,700,000
Securitization Bonds				404,700,000		492,600,000
Other Long-term Debt				200,700,000		200,500,000
Total Long-term Debt Outstanding				5,180,800,000		4,820,400,000
Outstanding Long-term Debt
Principal Amount, 2021				716,000,000
Principal Amount, 2022				278,500,000
Principal Amount, 2023				96,000,000
Principal Amount, 2024				324,500,000
Principal Amount, 2025				75,000,000
Principal Amount, After 2025				3,732,000,000
Principal Amount, Total				5,222,000,000
Unamortized Discount, Net and Debt Issuance Costs				(41,200,000)
Total Long-term Debt Outstanding				5,180,800,000		4,820,400,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Revenue from Contracts with Customers				1,587,700,000		1,528,000,000		1,551,600,000
Financing Activities (Textuals)
Repayments of Long-term Debt				88,700,000		392,100,000		401,800,000
Proceeds from Issuance of Long-term Debt				$ 444,200,000		652,700,000		$ 1,070,400,000
Maximum Percentage Debt to Capitalization				67.50%
Dividend Restrictions				$ 791,800,000
AEP Texas Inc. [Member] \| Utility [Member]
Money Pool Participants' Money Pool Activity and Authorized Borrowing Limits
Maximum Borrowings from Money Pool				355,500,000		320,400,000
Maximum Loans to Money Pool				104,700,000		313,400,000
Average Borrowings from Money Pool				172,500,000		132,000,000
Average Loans to Money Pool				40,000,000		139,000,000
Net Loans (Borrowings) to/from Money Pool				(26,900,000)		(67,100,000)
Authorized Short Term Borrowing Limit				$ 500,000,000		$ 500,000,000
Maximum and Minimum Interest Rates
Maximum Interest Rate				0.48%		2.70%		3.43%
Minimum Interest Rate				0.02%		0.27%		1.77%
Average Interest Rates for Funds Borrowed from and Loaned to Money Pool
Average Interest Rate For Funds Borrowed				0.33%		1.51%		2.63%
Average Interest Rate For Funds Loaned				0.26%		0.81%		2.03%
AEP Texas Inc. [Member] \| Nonutility [Member]
Maximum Interest Rate For Funds Loaned				0.58%		2.70%		3.02%
Minimum Interest Rate for Funds Loaned				0.21%		0.27%		1.91%
Money Pool Participants' Money Pool Activity and Authorized Borrowing Limits
Maximum Loans to Money Pool				$ 7,100,000		$ 7,500,000
Average Loans to Money Pool				6,900,000		7,100,000
Net Loans (Borrowings) to/from Money Pool				$ 6,900,000		$ 7,100,000
Average Interest Rates for Funds Borrowed from and Loaned to Money Pool
Average Interest Rate For Funds Loaned				0.37%		1.18%		2.56%
AEP Transmission Co [Member]
Long-term Debt
Senior Unsecured Notes				$ 4,343,900,000		$ 3,948,500,000
Total Long-term Debt Outstanding				4,343,900,000		3,948,500,000		$ 3,427,300,000
Outstanding Long-term Debt
Principal Amount, 2021				104,000,000
Principal Amount, 2022				60,000,000
Principal Amount, 2023				95,000,000
Principal Amount, 2024				90,000,000
Principal Amount, 2025				425,000,000
Principal Amount, After 2025				3,616,000,000
Principal Amount, Total				4,390,000,000
Unamortized Discount, Net and Debt Issuance Costs				(46,100,000)
Total Long-term Debt Outstanding				4,343,900,000		3,948,500,000		3,427,300,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Revenue from Contracts with Customers				1,410,900,000		1,232,700,000		1,042,100,000
Financing Activities (Textuals)
Repayments of Long-term Debt				50,000,000		0		85,000,000
Proceeds from Issuance of Long-term Debt				443,700,000		519,500,000		$ 688,000,000
Sub-Limit of Secured Debt				$ 50,000,000
Maximum Percentage of Consolidated Tangible Net Assets				10.00%
Tangible Capital to Tangible Assets				0.011
Maximum Percentage Debt to Capitalization				67.50%
Dividend Restrictions				$ 0
Liabilities Held for Sale				27,600,000		0
AEP Transmission Co [Member] \| Utility [Member]
Money Pool Participants' Money Pool Activity and Authorized Borrowing Limits
Maximum Borrowings from Money Pool				444,900,000		358,400,000
Maximum Loans to Money Pool				117,300,000		259,700,000
Average Borrowings from Money Pool				189,100,000		116,300,000
Average Loans to Money Pool				29,700,000		55,000,000
Net Loans (Borrowings) to/from Money Pool				(108,000,000)	[13]	(155,400,000)
Authorized Short Term Borrowing Limit	[14]			$ 820,000,000		$ 820,000,000
Maximum and Minimum Interest Rates
Maximum Interest Rate				0.48%		2.70%		3.43%
Minimum Interest Rate				0.02%		0.27%		1.77%
Average Interest Rates for Funds Borrowed from and Loaned to Money Pool
Average Interest Rate For Funds Borrowed				0.32%		1.29%		2.64%
Average Interest Rate For Funds Loaned				0.10%		1.99%		2.41%
AEP Transmission Co [Member] \| Direct Borrowing [Member]
Maximum Interest Rate for Funds Borrowed				0.86%		2.70%		3.02%
Minimum Interest Rate For Funds Borrowed				0.25%		0.27%		1.91%
Maximum Interest Rate For Funds Loaned				0.86%		2.70%		3.02%
Minimum Interest Rate for Funds Loaned				0.25%		0.27%		1.91%
Money Pool Participants' Money Pool Activity and Authorized Borrowing Limits
Maximum Borrowings from Money Pool				$ 14,600,000		$ 1,400,000
Maximum Loans to Money Pool				224,200,000		215,300,000
Average Borrowings from Money Pool				1,800,000		1,300,000
Average Loans to Money Pool				118,000,000		132,600,000
Borrowings from Parent				1,500,000		1,200,000
Loans to Parent				12,700,000		109,000,000
Authorized Short Term Borrowing Limit	[15]			$ 50,000,000		$ 50,000,000
Average Interest Rates for Funds Borrowed from and Loaned to Money Pool
Average Interest Rate For Funds Borrowed				0.38%		1.20%		2.55%
Average Interest Rate For Funds Loaned				0.35%		1.13%		2.51%
Appalachian Power Co [Member]
Long-term Debt
Senior Unsecured Notes				$ 4,083,700,000		$ 3,937,200,000
Pollution Control Bonds	[1]			529,500,000		546,300,000
Securitization Bonds				198,800,000		223,800,000
Other Long-term Debt				126,900,000		126,800,000
Total Long-term Debt Outstanding				4,938,900,000		4,834,100,000
Outstanding Long-term Debt
Principal Amount, 2021				480,700,000
Principal Amount, 2022				26,600,000
Principal Amount, 2023				113,500,000
Principal Amount, 2024				443,900,000
Principal Amount, 2025				30,900,000
Principal Amount, After 2025				3,887,400,000
Principal Amount, Total				4,983,000,000
Unamortized Discount, Net and Debt Issuance Costs				(44,100,000)
Total Long-term Debt Outstanding				4,938,900,000		4,834,100,000
Accounts Receivable and Accrued Unbilled Revenue
Accounts Receivable and Accrued Unbilled Revenues				153,100,000		136,000,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Revenue from Contracts with Customers				3,092,900,000		2,809,200,000		$ 2,911,100,000
Proceeds on Sale of Receivables to AEP Credit
Proceeds from Sale of Receivables to AEP Credit				1,324,100,000		1,272,900,000		1,310,300,000
Financing Activities (Textuals)
Repayments of Long-term Debt				393,000,000		140,300,000		180,500,000
Proceeds from Issuance of Long-term Debt				$ 494,000,000		606,900,000		$ 478,200,000
Maximum Percentage Debt to Capitalization				67.50%
Dividend Restrictions				$ 313,400,000
Appalachian Power Co [Member] \| Utility [Member]
Money Pool Participants' Money Pool Activity and Authorized Borrowing Limits
Maximum Borrowings from Money Pool				199,300,000		434,300,000
Maximum Loans to Money Pool				616,900,000		189,000,000
Average Borrowings from Money Pool				87,500,000		242,800,000
Average Loans to Money Pool				118,300,000		76,300,000
Net Loans (Borrowings) to/from Money Pool				(178,500,000)		2,800,000
Authorized Short Term Borrowing Limit				$ 500,000,000		$ 500,000,000
Maximum and Minimum Interest Rates
Maximum Interest Rate				0.48%		2.70%		3.43%
Minimum Interest Rate				0.02%		0.27%		1.77%
Average Interest Rates for Funds Borrowed from and Loaned to Money Pool
Average Interest Rate For Funds Borrowed				0.41%		2.12%		2.45%
Average Interest Rate For Funds Loaned				0.25%		0.85%		2.66%
Indiana Michigan Power Co [Member]
Long-term Debt
Senior Unsecured Notes				$ 2,595,500,000		$ 2,152,200,000
Pollution Control Bonds	[1]			188,700,000		240,500,000
Notes Payable	[2]			122,200,000		146,700,000
Spent Nuclear Fuel Obligation	[3]			281,300,000		281,200,000
Other Long-term Debt				7,300,000		209,300,000
Total Long-term Debt Outstanding				3,195,000,000		3,029,900,000
Outstanding Long-term Debt
Principal Amount, 2021				67,000,000
Principal Amount, 2022				289,800,000
Principal Amount, 2023				16,800,000
Principal Amount, 2024				195,900,000
Principal Amount, 2025				0
Principal Amount, After 2025				2,656,300,000
Principal Amount, Total				3,225,800,000
Unamortized Discount, Net and Debt Issuance Costs				(30,800,000)
Total Long-term Debt Outstanding				3,195,000,000		3,029,900,000
Accounts Receivable and Accrued Unbilled Revenue
Accounts Receivable and Accrued Unbilled Revenues				156,900,000		170,500,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Revenue from Contracts with Customers				2,330,700,000		2,236,000,000		$ 2,308,100,000
Proceeds on Sale of Receivables to AEP Credit
Proceeds from Sale of Receivables to AEP Credit				1,927,000,000		1,891,800,000		1,824,200,000
Financing Activities (Textuals)
Repayments of Long-term Debt				383,500,000		93,200,000		117,100,000
Proceeds from Issuance of Long-term Debt				$ 546,700,000		69,500,000		$ 123,300,000
Maximum Percentage Debt to Capitalization				67.50%
Dividend Restrictions				$ 648,500,000
Indiana Michigan Power Co [Member] \| Utility [Member]
Money Pool Participants' Money Pool Activity and Authorized Borrowing Limits
Maximum Borrowings from Money Pool				166,500,000		218,600,000
Maximum Loans to Money Pool				368,200,000		13,400,000
Average Borrowings from Money Pool				110,400,000		114,500,000
Average Loans to Money Pool				67,700,000		13,300,000
Net Loans (Borrowings) to/from Money Pool				(71,800,000)		(89,700,000)
Authorized Short Term Borrowing Limit				$ 500,000,000		$ 500,000,000
Maximum and Minimum Interest Rates
Maximum Interest Rate				0.48%		2.70%		3.43%
Minimum Interest Rate				0.02%		0.27%		1.77%
Average Interest Rates for Funds Borrowed from and Loaned to Money Pool
Average Interest Rate For Funds Borrowed				0.33%		1.07%		2.34%
Average Interest Rate For Funds Loaned				0.23%		1.18%		2.60%
Ohio Power Co [Member]
Long-term Debt
Senior Unsecured Notes				$ 2,967,800,000		$ 2,429,400,000
Other Long-term Debt				700,000		800,000
Total Long-term Debt Outstanding				2,968,500,000		2,430,200,000
Outstanding Long-term Debt
Principal Amount, 2021				100,000
Principal Amount, 2022				100,000
Principal Amount, 2023				100,000
Principal Amount, 2024				100,000
Principal Amount, 2025				100,000
Principal Amount, After 2025				3,000,200,000
Principal Amount, Total				3,000,700,000
Unamortized Discount, Net and Debt Issuance Costs				(32,200,000)
Total Long-term Debt Outstanding				2,968,500,000		2,430,200,000
Accounts Receivable and Accrued Unbilled Revenue
Accounts Receivable and Accrued Unbilled Revenues				392,700,000		398,800,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Revenue from Contracts with Customers				2,837,500,000		2,665,000,000		$ 2,748,800,000
Proceeds on Sale of Receivables to AEP Credit
Proceeds from Sale of Receivables to AEP Credit				2,458,500,000		2,366,200,000		2,293,600,000
Financing Activities (Textuals)
Repayments of Long-term Debt				500,100,000		100,000		80,300,000
Proceeds from Issuance of Long-term Debt				1,037,100,000		347,000,000		$ 444,300,000
Dividend Restrictions				0
Ohio Power Co [Member] \| Utility [Member]
Money Pool Participants' Money Pool Activity and Authorized Borrowing Limits
Maximum Borrowings from Money Pool				259,200,000		353,900,000
Maximum Loans to Money Pool				622,900,000		32,800,000
Average Borrowings from Money Pool				61,600,000		182,400,000
Average Loans to Money Pool				127,200,000		25,200,000
Net Loans (Borrowings) to/from Money Pool				42,000,000		(259,200,000)
Authorized Short Term Borrowing Limit				$ 500,000,000		$ 500,000,000
Maximum and Minimum Interest Rates
Maximum Interest Rate				0.48%		2.70%		3.43%
Minimum Interest Rate				0.02%		0.27%		1.77%
Average Interest Rates for Funds Borrowed from and Loaned to Money Pool
Average Interest Rate For Funds Borrowed				0.27%		0.99%		2.67%
Average Interest Rate For Funds Loaned				0.14%		2.06%		2.68%
Public Service Co Of Oklahoma [Member]
Shares of Company
Beginning Balance, Shares			10,482,000	10,482,000
Ending Balance, Shares				10,482,000		10,482,000
Long-term Debt
Senior Unsecured Notes				$ 1,785,500,000		$ 1,246,300,000
Other Long-term Debt				128,000,000		127,500,000
Total Long-term Debt Outstanding				1,913,500,000		1,373,800,000
Outstanding Long-term Debt
Principal Amount, 2021				125,500,000
Principal Amount, 2022				500,000
Principal Amount, 2023				600,000
Principal Amount, 2024				125,600,000
Principal Amount, 2025				50,600,000
Principal Amount, After 2025				1,625,300,000
Principal Amount, Total				1,928,100,000
Unamortized Discount, Net and Debt Issuance Costs				(14,600,000)
Total Long-term Debt Outstanding				1,913,500,000		1,373,800,000
Accounts Receivable and Accrued Unbilled Revenue
Accounts Receivable and Accrued Unbilled Revenues				114,500,000		85,000,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Revenue from Contracts with Customers				1,474,300,000		1,263,900,000		$ 1,512,800,000
Proceeds on Sale of Receivables to AEP Credit
Proceeds from Sale of Receivables to AEP Credit				1,406,400,000		1,221,000,000		1,442,500,000
Financing Activities (Textuals)
Repayments of Long-term Debt				750,500,000		13,200,000		250,500,000
Proceeds from Issuance of Long-term Debt				$ 1,290,000,000		0		$ 349,500,000
Maximum Percentage Debt to Capitalization				67.50%
Dividend Restrictions				$ 0
Public Service Co Of Oklahoma [Member] \| Utility [Member]
Money Pool Participants' Money Pool Activity and Authorized Borrowing Limits
Maximum Borrowings from Money Pool				267,700,000		155,400,000
Maximum Loans to Money Pool				747,300,000		57,100,000
Average Borrowings from Money Pool				134,000,000		72,300,000
Average Loans to Money Pool				113,100,000		28,400,000
Net Loans (Borrowings) to/from Money Pool				(72,300,000)		(155,400,000)
Authorized Short Term Borrowing Limit				$ 400,000,000		$ 300,000,000
Maximum and Minimum Interest Rates
Maximum Interest Rate				0.48%		2.70%		3.43%
Minimum Interest Rate				0.02%		0.27%		1.77%
Average Interest Rates for Funds Borrowed from and Loaned to Money Pool
Average Interest Rate For Funds Borrowed				0.34%		0.92%		2.85%
Average Interest Rate For Funds Loaned				0.07%		1.95%		2.27%
Southwestern Electric Power Co [Member]
Long-term Debt
Senior Unsecured Notes				$ 3,295,100,000		$ 2,430,800,000
Notes Payable	[2]			59,100,000		62,400,000
Other Long-term Debt				41,000,000		143,200,000
Total Long-term Debt Outstanding				3,395,200,000		2,636,400,000
Outstanding Long-term Debt
Principal Amount, 2021				6,200,000
Principal Amount, 2022				6,200,000
Principal Amount, 2023				31,200,000
Principal Amount, 2024				6,200,000
Principal Amount, 2025				906,200,000
Principal Amount, After 2025				2,469,300,000
Principal Amount, Total				3,425,300,000
Unamortized Discount, Net and Debt Issuance Costs				(30,100,000)
Total Long-term Debt Outstanding				3,395,200,000		2,636,400,000
Short-term Debt
Notes Payable				0		35,000,000
Accounts Receivable and Accrued Unbilled Revenue
Accounts Receivable and Accrued Unbilled Revenues				153,000,000		158,600,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Revenue from Contracts with Customers				2,126,000,000		1,735,300,000		$ 1,799,200,000
Proceeds on Sale of Receivables to AEP Credit
Proceeds from Sale of Receivables to AEP Credit				1,636,100,000		1,593,800,000		1,618,500,000
Financing Activities (Textuals)
Repayments of Long-term Debt				381,200,000		21,200,000		59,700,000
Proceeds from Issuance of Long-term Debt				$ 1,137,600,000		0		0
Maximum Percentage Debt to Capitalization				67.50%
Dividend Restrictions				$ 577,900,000
Dividends Paid on Common Stock				(4,800,000)		(1,900,000)		$ (3,300,000)
Southwestern Electric Power Co [Member] \| Utility [Member]
Money Pool Participants' Money Pool Activity and Authorized Borrowing Limits
Maximum Borrowings from Money Pool				280,300,000		178,900,000
Maximum Loans to Money Pool				561,900,000		0
Average Borrowings from Money Pool				142,400,000		113,000,000
Average Loans to Money Pool				287,400,000		0
Net Loans (Borrowings) to/from Money Pool				153,800,000		(124,600,000)
Authorized Short Term Borrowing Limit				$ 400,000,000		$ 350,000,000
Maximum and Minimum Interest Rates
Maximum Interest Rate				0.48%		2.70%		3.43%
Minimum Interest Rate				0.02%		0.27%		1.77%
Average Interest Rates for Funds Borrowed from and Loaned to Money Pool
Average Interest Rate For Funds Borrowed				0.26%		1.27%		2.72%
Average Interest Rate For Funds Loaned				0.18%		0.00%		2.22%
Southwestern Electric Power Co [Member] \| Nonutility [Member]
Maximum Interest Rate For Funds Loaned				0.58%		2.70%		3.02%
Minimum Interest Rate for Funds Loaned				0.21%		0.27%		1.91%
Money Pool Participants' Money Pool Activity and Authorized Borrowing Limits
Maximum Loans to Money Pool				$ 2,100,000		$ 2,100,000
Average Loans to Money Pool				2,100,000		2,100,000
Net Loans (Borrowings) to/from Money Pool				$ 2,100,000		$ 2,100,000
Average Interest Rates for Funds Borrowed from and Loaned to Money Pool
Average Interest Rate For Funds Loaned				0.37%		1.18%		2.55%
Southwestern Electric Power Co [Member] \| Loans Payable [Member]
Short-term Debt
Debt, Weighted Average Interest Rate	[11]			0.00%		2.55%
Senior Notes [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low				2021
Maturity Date High				2051
Weighted Average Interest Rate				3.69%
Senior Notes [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				0.61%		0.70%
Senior Notes [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				7.00%		8.13%
Senior Notes [Member] \| AEP Texas Inc. [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low				2022
Maturity Date High				2051
Weighted Average Interest Rate				3.67%
Senior Notes [Member] \| AEP Texas Inc. [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				2.10%		2.10%
Senior Notes [Member] \| AEP Texas Inc. [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				6.76%		6.76%
Senior Notes [Member] \| AEP Transmission Co [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low				2021
Maturity Date High				2051
Weighted Average Interest Rate				3.73%
Senior Notes [Member] \| AEP Transmission Co [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				2.75%		3.10%
Senior Notes [Member] \| AEP Transmission Co [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				5.52%		5.52%
Senior Notes [Member] \| Appalachian Power Co [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low				2021
Maturity Date High				2050
Weighted Average Interest Rate				4.70%
Senior Notes [Member] \| Appalachian Power Co [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				2.70%		3.30%
Senior Notes [Member] \| Appalachian Power Co [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				7.00%		7.00%
Senior Notes [Member] \| Indiana Michigan Power Co [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low				2023
Maturity Date High				2051
Weighted Average Interest Rate				4.19%
Senior Notes [Member] \| Indiana Michigan Power Co [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				3.20%		3.20%
Senior Notes [Member] \| Indiana Michigan Power Co [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				6.05%		6.05%
Senior Notes [Member] \| Ohio Power Co [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low				2021
Maturity Date High				2051
Weighted Average Interest Rate				3.87%
Senior Notes [Member] \| Ohio Power Co [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				1.63%		2.60%
Senior Notes [Member] \| Ohio Power Co [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				6.60%		6.60%
Senior Notes [Member] \| Public Service Co Of Oklahoma [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low				2021
Maturity Date High				2051
Weighted Average Interest Rate				3.74%
Senior Notes [Member] \| Public Service Co Of Oklahoma [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				2.20%		3.05%
Senior Notes [Member] \| Public Service Co Of Oklahoma [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				6.63%		6.63%
Senior Notes [Member] \| Southwestern Electric Power Co [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low				2022
Maturity Date High				2051
Weighted Average Interest Rate				3.57%
Senior Notes [Member] \| Southwestern Electric Power Co [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				1.65%		2.75%
Senior Notes [Member] \| Southwestern Electric Power Co [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				6.20%		6.20%
Pollution Control Bonds [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low	[16]			2021
Maturity Date High	[16]			2036
Weighted Average Interest Rate				2.40%
Pollution Control Bonds [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				0.19%		0.18%
Pollution Control Bonds [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				4.55%		4.63%
Pollution Control Bonds [Member] \| AEP Texas Inc. [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low	[16]			2023
Maturity Date High	[16]			2030
Weighted Average Interest Rate				3.42%
Pollution Control Bonds [Member] \| AEP Texas Inc. [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				0.90%		0.90%
Pollution Control Bonds [Member] \| AEP Texas Inc. [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				4.55%		4.55%
Pollution Control Bonds [Member] \| Appalachian Power Co [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low	[16]			2021
Maturity Date High	[16]			2036
Weighted Average Interest Rate				1.67%
Pollution Control Bonds [Member] \| Appalachian Power Co [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				0.19%		0.19%
Pollution Control Bonds [Member] \| Appalachian Power Co [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				2.75%		4.63%
Pollution Control Bonds [Member] \| Indiana Michigan Power Co [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low	[16]			2021
Maturity Date High	[16]			2025
Weighted Average Interest Rate				2.49%
Pollution Control Bonds [Member] \| Indiana Michigan Power Co [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				0.75%		0.18%
Pollution Control Bonds [Member] \| Indiana Michigan Power Co [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				3.05%		3.05%
Notes Payable, Other Payables [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low				2021
Maturity Date High				2032
Weighted Average Interest Rate				2.41%
Notes Payable, Other Payables [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				0.79%		0.84%
Notes Payable, Other Payables [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				6.37%		6.37%
Notes Payable, Other Payables [Member] \| Indiana Michigan Power Co [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low				2021
Maturity Date High				2025
Weighted Average Interest Rate				0.99%
Notes Payable, Other Payables [Member] \| Indiana Michigan Power Co [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				0.79%		0.84%
Notes Payable, Other Payables [Member] \| Indiana Michigan Power Co [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				1.24%		1.29%
Notes Payable, Other Payables [Member] \| Indiana Michigan Power Co [Member] \| Subsequent Event [Member]
Financing Activities (Textuals)
Repayments of Long-term Debt		$ 8,000,000	$ 8,000,000
Notes Payable, Other Payables [Member] \| Southwestern Electric Power Co [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low				2024
Maturity Date High				2032
Weighted Average Interest Rate				5.34%
Notes Payable, Other Payables [Member] \| Southwestern Electric Power Co [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				4.58%		4.58%
Notes Payable, Other Payables [Member] \| Southwestern Electric Power Co [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				6.37%		6.37%
Securitization Bonds [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low	[17]			2023
Maturity Date High	[17]			2029
Weighted Average Interest Rate				2.84%
Securitization Bonds [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				2.01%		2.01%
Securitization Bonds [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				3.77%		3.77%
Securitization Bonds [Member] \| AEP Texas Inc. [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low	[17]			2024
Maturity Date High	[17]			2029
Weighted Average Interest Rate				2.53%
Securitization Bonds [Member] \| AEP Texas Inc. [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				2.06%		2.06%
Securitization Bonds [Member] \| AEP Texas Inc. [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				2.84%		2.84%
Securitization Bonds [Member] \| AEP Texas Inc. [Member] \| Subsequent Event [Member]
Financing Activities (Textuals)
Repayments of Long-term Debt		11,000,000
Securitization Bonds [Member] \| Appalachian Power Co [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low	[17]			2023
Maturity Date High	[17]			2028
Weighted Average Interest Rate				3.46%
Securitization Bonds [Member] \| Appalachian Power Co [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				2.01%		2.01%
Securitization Bonds [Member] \| Appalachian Power Co [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				3.77%		3.77%
Securitization Bonds [Member] \| Appalachian Power Co [Member] \| Subsequent Event [Member]
Financing Activities (Textuals)
Repayments of Long-term Debt		13,000,000
Junior Subordinated Notes [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low				2023
Maturity Date High				2027
Weighted Average Interest Rate				2.81%
Junior Subordinated Notes [Member] \| 2019 Equity Units [Member]
Financing Activities (Textuals)
Proceeds from Issuance of Debt				$ 805,000,000
Junior Subordinated Notes [Member] \| 2020 Equity Units [Member]
Financing Activities (Textuals)
Proceeds from Issuance of Debt				$ 850,000,000
Junior Subordinated Notes [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				1.30%		1.30%
Junior Subordinated Notes [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				3.88%		3.40%
Other Long Term Debt [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low				2021
Maturity Date High				2059
Weighted Average Interest Rate				1.63%
Other Long Term Debt [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				0.91%		0.81%
Other Long Term Debt [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				13.72%		13.72%
Other Long Term Debt [Member] \| AEP Texas Inc. [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low				2022
Maturity Date High				2059
Weighted Average Interest Rate				1.37%
Other Long Term Debt [Member] \| AEP Texas Inc. [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				1.35%		1.40%
Other Long Term Debt [Member] \| AEP Texas Inc. [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				4.50%		4.50%
Other Long Term Debt [Member] \| Appalachian Power Co [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low				2022
Maturity Date High				2026
Weighted Average Interest Rate				1.42%
Other Long Term Debt [Member] \| Appalachian Power Co [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				1.24%		1.32%
Other Long Term Debt [Member] \| Appalachian Power Co [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				13.72%		13.72%
Other Long Term Debt [Member] \| Indiana Michigan Power Co [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low				2021
Maturity Date High				2025
Weighted Average Interest Rate				6.00%
Other Long Term Debt [Member] \| Indiana Michigan Power Co [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				6.00%		1.28%
Other Long Term Debt [Member] \| Indiana Michigan Power Co [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				6.00%		6.00%
Other Long Term Debt [Member] \| Ohio Power Co [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low				2028
Maturity Date High				2028
Weighted Average Interest Rate				1.15%
Other Long Term Debt [Member] \| Ohio Power Co [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				1.15%		1.15%
Other Long Term Debt [Member] \| Ohio Power Co [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				1.15%		1.15%
Other Long Term Debt [Member] \| Public Service Co Of Oklahoma [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low				2022
Maturity Date High				2027
Weighted Average Interest Rate				1.50%
Other Long Term Debt [Member] \| Public Service Co Of Oklahoma [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				1.47%		1.42%
Other Long Term Debt [Member] \| Public Service Co Of Oklahoma [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				3.00%		3.00%
Other Long Term Debt [Member] \| Public Service Co Of Oklahoma [Member] \| Subsequent Event [Member]
Financing Activities (Textuals)
Proceeds from Issuance of Long-term Debt		$ 500,000,000
Other Long Term Debt [Member] \| Southwestern Electric Power Co [Member]
Long- term Debt by Type of Debt and Maturity
Maturity Date Low				2021
Maturity Date High				2035
Weighted Average Interest Rate				4.68%
Other Long Term Debt [Member] \| Southwestern Electric Power Co [Member] \| Minimum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				4.68%		2.25%
Other Long Term Debt [Member] \| Southwestern Electric Power Co [Member] \| Maximum [Member]
Long- term Debt by Type of Debt and Maturity
Interest Rate				4.68%		4.68%
Junior Subordinated Debt [Member] \| 2019 Equity Units [Member]
Financing Activities (Textuals)
Debt Instrument, Interest Rate, Stated Percentage				3.40%
Junior Subordinated Debt [Member] \| 2020 Equity Units [Member]
Financing Activities (Textuals)
Debt Instrument, Interest Rate, Stated Percentage				1.30%
Junior Subordinated Debt [Member] \| Subsequent Event [Member] \| 2019 Equity Units [Member]
Financing Activities (Textuals)
Debt Instrument, Interest Rate, Stated Percentage		2.031%
Servicing Contracts [Member] \| Appalachian Power Co [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Revenue from Contracts with Customers				$ 4,900,000		$ 5,200,000		$ 7,400,000
Servicing Contracts [Member] \| Indiana Michigan Power Co [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Revenue from Contracts with Customers				7,000,000		7,900,000		11,100,000
Servicing Contracts [Member] \| Ohio Power Co [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Revenue from Contracts with Customers				8,300,000		24,100,000		27,100,000
Servicing Contracts [Member] \| Public Service Co Of Oklahoma [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Revenue from Contracts with Customers				3,400,000		4,800,000		7,800,000
Servicing Contracts [Member] \| Southwestern Electric Power Co [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Revenue from Contracts with Customers				5,400,000		6,700,000		10,200,000
Retained Earnings [Member]
Financing Activities (Textuals)
Forward Equity Purchase Contracts Included in Current and Noncurrent Liabilities as of December 31,				(1,100,000)
Dividends Paid on Common Stock				1,500,000,000		(1,400,000,000)		(1,300,000,000)
Additional Paid-in Capital [Member]
Financing Activities (Textuals)
Forward Equity Purchase Contracts Included in Current and Noncurrent Liabilities as of December 31,				32,600,000		$ (85,800,000)	[18]	$ (9,800,000)	[19]
Additional Paid-in Capital [Member] \| 2019 Equity Units [Member]
Financing Activities (Textuals)
Forward Equity Purchase Contracts Included in Current and Noncurrent Liabilities as of December 31,				62,000,000
Additional Paid-in Capital [Member] \| 2020 Equity Units [Member]
Financing Activities (Textuals)
Forward Equity Purchase Contracts Included in Current and Noncurrent Liabilities as of December 31,				$ 121,000,000

[1]	For certain series of Pollution Control Bonds, interest rates are subject to periodic adjustment. Certain series may be purchased on demand at periodic interest adjustment dates. Letters of credit from banks and insurance policies support certain series. Consequently, these bonds have been classified for maturity purposes as Long-term Debt Due Within One Year - Nonaffiliated on the balance sheets.
[2]	Notes payable represent outstanding promissory notes issued under term loan agreements and credit agreements with a number of banks and other financial institutions. At expiration, all notes then issued and outstanding are due and payable. Interest rates are both fixed and variable. Variable rates generally relate to specified short-term interest rates.
[3]	Spent Nuclear Fuel Obligation consists of a liability along with accrued interest for disposal of SNF. See “Spent Nuclear Fuel Disposal” section of Note 6 for additional information.
[4]	See “Equity Units” section below for additional information.
[5]	2021 amount excludes $1.1 billion of Total Long-term Debt Outstanding classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[6]	Amount excludes $1.1 billion of Total Long-term Debt Outstanding classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information
[7]	The 2021 book value amount excludes Long-term Debt of $1.1 billion classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[8]	Amount includes $850 million of Junior Subordinated Notes. See “Equity Units” section below for additional information.
[9]	Amount includes $805 million of Junior Subordinated Notes. See “Equity Units” section below for additional information.
[10]	Amount of securitized debt for receivables as accounted for under the “Transfers and Servicing” accounting guidance.
[11]	Weighted-average rate.
[12]	Includes the restrictions of consolidated and non-consolidated subsidiaries.
[13]	Amount excludes $1 million of Advances from Affiliates classified as Liabilities Held for Sale on the AEP Transco balance sheet. See “Dispositions of KPCo and KTCo” section of Note 7 for additional information.
[14]	Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions.
[15]	Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions.
[16]	Certain Pollution Control Bonds are subject to redemption earlier than the maturity date.
[17]	Dates represent the scheduled final payment dates for the securitization bonds. The legal maturity date is one to two years later. These bonds have been classified for maturity and repayment purposes based on the scheduled final payment date.
[18]	(c) Includes $(121) million related to a forward equity purchase contract associated with the issuance of Equity Units. See “Equity Units” section of Note 14 for additional information.
[19]	(b) Includes $(62) million related to a forward equity purchase contract associated with the issuance of Equity Units. See “Equity Units” section of Note 14 for additional information.

Stock-Based Compensation (Detai

Stock-Based Compensation (Details) - USD ($) $ / shares in Units, $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Stock Based Compensation (Textuals)
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant		10,000,000
Number of Shares Remaining Available for Issuance Under the AEP Long-Term Incentive Plan		5,976,468
Reduction in Aggregate Common Shares Authorized Per Share Issued Pursuant to Stock Options or Stock Appreciation Rights		0.286
Performance Units and AEP Career Shares Reinvested Dividends Portion For [Member]
Performance Units
Awarded Units	[1]	74,500	73,400	66,400
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology
Weighted Average Grant Date Fair Value		$ 84.48	$ 84.87	$ 88.73
Stock Based Compensation [Member]
Compensation Cost and Actual Tax Benefit Realized for the Tax Deductions from Compensation Cost for Share-based Payment Arrangements
Compensation Cost for Share-based Payment Arrangements	[2]	$ 61.1	$ 53.8	$ 57.9
Actual Tax Benefit Realized		8.7	7.2	8.4
Total Compensation Cost Capitalized		16.9	$ 20.4	$ 20
Stock Based Compensation (Textuals)
Total Unrecognized Compensation Cost Related to Unvested Share-based Compensation Arrangements Granted		$ 73
Weighted-average Period of Unrecognized Compensation Costs (in years)		1 year 4 months 20 days
Stock Unit Accumulation Plan for Non Employee Directors [Member]
Stock Based Compensation (Textuals)
Number of Years After Termination of Board Service Participant Can Elect to Have Stock Units Paid in Cash		10 years
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology
Weighted Average Grant Date Fair Value		$ 84.54	$ 83.80	$ 89.13
Awarded Units		12,600	12,100	10,000
Cash Payments for Non Employee Director Plans		$ 5
Restricted Stock Units (RSUs) [Member]
Total Fair Value and Total Intrinsic Value of Restricted Shares and Restricted Stock Units Vested
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Fair Value		20.5	$ 22.9	$ 16.3
Intrinsic Value of Restricted Shares and Restricted Stock Units Vested	[3]	$ 22	$ 25.2	$ 21.6
Status of Nonvested Restricted Shares and Restricted Stock Units
Nonvested, Shares/Units, Beginning Balance		448,000
Nonvested, Weighted Average Grant Date Fair Value, Beginning of Period		$ 86.56
Shares/Units, Vested		(250,500)
Weighted Average Grant Date Fair Value, Vested		$ 81.92
Shares/Units, Forfeited		(53,200)
Weighted Average Grant Date Fair Value, Shares/Units, Forfeited		$ 85.80
Nonvested, Shares/Units, Ending Balance		424,300	448,000
Nonvested, Weighted Average Grant Date Fair Value, End of Period		$ 84.86	$ 86.56
Stock Based Compensation (Textuals)
Maximum Contractual Term of Outstanding Restricted Stock Units (in months)		40 months
Total Aggregate Intrinsic Value of Nonvested Shares		$ 38
Weighted Average Remaining Contractual Life of Nonvested Shares (in years)		1 year 9 months 7 days
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology
Weighted Average Grant Date Fair Value		$ 80.39	$ 94.38	$ 81.57
Awarded Units		280,000	268,700	304,800
Performance Units [Member]
Performance Units
Awarded Units		565,000	424,800	535,000
Vesting Period (in years)		3 years	3 years	3 years
Certified Performance Scores and Units Earned
Certified Performance Score		102.90%	128.20%	132.70%
Performance Units Earned		537,166	757,858	792,897
Performance Units Manditorily Deferred as AEP Career Shares		14,613	13,614	10,063
Performance Units Voluntarily Deferred into the Incentive Compensation Deferral Program		22,915	26,936	49,392
Share Based Compensation Performance Units to be Settled in Shares	[4]	499,638	717,308	733,442
Cash Payouts
Cash Payouts for Performance Units		$ 0	$ 0	$ 58.3
Equity Payouts for Performance Units		$ 54.7	75.4	0
Stock Based Compensation (Textuals)
Performance Score by HR Committee, Lower Range		0.00%
Performance Score by HR Committee, Higher Range		200.00%
Equity Payouts For Career Share Distributions		$ 4	$ 1.9	$ 6.6
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Term	[5]	2 years 10 months 17 days	2 years 10 months 13 days	2 years 10 months 13 days
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Volatility Rate, Minimum		25.87%	13.67%	14.83%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Volatility Rate, Maximum		39.90%	28.15%	25.57%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Risk Free Interest Rate		0.19%	1.40%	2.49%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Dividend Rate	[6]	0.00%	0.00%	0.00%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Weighted Average Volatility Rate		31.01%	16.39%	17.39%
Weighted Average Grant Date Fair Value		$ 81.02	$ 116.56	$ 83.21
Performance Units and Reinvested Dividends [Member]
Share Based Compensation Performance Units Converted to Shares	[7]	500,000
Performance Units
Awarded Units		53,400
Status of Nonvested Restricted Shares and Restricted Stock Units
Nonvested, Shares/Units, Beginning Balance		938,600
Nonvested, Weighted Average Grant Date Fair Value, Beginning of Period		$ 98.05
Shares/Units, Vested	[7]	(529,000)
Weighted Average Grant Date Fair Value, Vested		$ 83.87
Shares/Units, Forfeited		(104,200)
Weighted Average Grant Date Fair Value, Shares/Units, Forfeited		$ 87.65
Nonvested, Shares/Units, Ending Balance		923,800	938,600
Nonvested, Weighted Average Grant Date Fair Value, End of Period		$ 96.15	$ 98.05
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology
Weighted Average Grant Date Fair Value		$ 84.45

[1]	The vesting period for the reinvested dividends on performance shares is equal to the remaining life of the related performance shares. Dividends on AEP career shares vest immediately when the dividend is awarded but are not settled in AEP common stock until after the participant’s AEP employment ends.
[2]	Compensation cost for share-based payment arrangements is included in Other Operation and Maintenance expenses on the statements of income.
[3]	Intrinsic value is calculated as market price at the vesting date.
[4]	Performance shares settled in AEP common stock in the quarter following the end of the year shown.
[5]	Period from award date to vesting date.
[6]	Equivalent to reinvesting dividends.
[7]	The vested Performance Shares will be converted to 500 thousand shares based on the closing share price on the day before settlement.

Related Party Transactions (Det

Related Party Transactions (Details) $ in Millions		3 Months Ended	12 Months Ended
Related Party Transactions (Details) $ in Millions		Jun. 30, 2019MW	Dec. 31, 2021USD ($)MW		Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Affiliated Revenues and Purchases
Affiliated Revenues			$ 0		$ 0	$ 0
Related Party Transactions (Textuals)
Total Property, Plant and Equipment, Net			66,001.3	[1]	63,901.6
Charitable Contribution to AEP Foundation [Abstract]
Related Party Charitable Contribuions to AEP Foundation						50
Generation and Marketing [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			55.4		104.6	135.8
Related Party Transactions (Textuals)
Total Property, Plant and Equipment, Net			1,864.4		1,744.1
Appalachian Power Co. to AEP Transmission Co [Member]
Joint License Agreement
Joint License Agreement			$ 2.4		0.9	0.2
Indiana Michigan Power Co to Kentucky Power Co [Member]
Related Party Transactions (Textuals)
Percentage of Power Sold under Unit Power Agreement			30.00%
AEP Generating Co to Indiana Michigan Power Co [Member]
Cook Coal Terminal
Coal Transloading Services			$ 11		12	13
Railcar Maintenance			$ 0.3		0.9	1.3
AEP Generating Co to Kentucky Power Co [Member]
Related Party Transactions (Textuals)
Percentage of Power Sold under Unit Power Agreement			30.00%
AEP Generating Co to Public Service Co of Oklahoma [Member]
Cook Coal Terminal
Railcar Maintenance			$ 0.4		0.7	0.8
AEP Generating Co To Southwestern Electric Power Co [Member]
Cook Coal Terminal
Railcar Maintenance			2.8		3	4
AEP Energy Partners, Inc. to AEP Texas Inc. [Member]
Oklaunion PPA between AEP Texas and AEPEP
Oklaunion Purchase Power Agreement			0		88	157
Indiana Michigan Power Co to AEP Transmission Co [Member]
Joint License Agreement
Joint License Agreement			4.8		3	1.5
Kentucky Power Co to AEP Transmission Co [Member]
Joint License Agreement
Joint License Agreement			0.5		0.4	0.3
Ohio Power Co to AEP Transmission Co [Member]
Joint License Agreement
Joint License Agreement			4.6		4.5	2.2
Public Service Co of Oklahoma to AEP Transmission Co [Member]
Joint License Agreement
Joint License Agreement			0.4		0.4	0.3
Wheeling Power Co to AEP Transmission Co [Member]
Joint License Agreement
Joint License Agreement			$ 0.2		0.2	0.1
AEP Wind Holdings LLC [Member]
Sempra Renewables LLC PPAs [Abstract]
WindGenerationMWs \| MW		724
AEP Wind Holdings LLC [Member] \| Generation and Marketing [Member]
Sempra Renewables LLC PPAs [Abstract]
WindGenerationMWs \| MW			724
AEP Generating Co [Member]
Barging, Urea Transloading and Other Services
Expenses from Barging, Urea Transloading and Other Services			$ 7.6		10.6	14.9
AEP Generation Resources [Member]
Central Machine Shop
Billings for Services from Central Machine Shop Facility			0.4		2.9	0.8
AEP Transmission Co [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			1,153.9		896.3	806.7
Sales and Purchases of Property
Related Party Sales of Property			1.4		0.2	0
Related Party Purchases of Property			16.7		6	10.2
Related Party Transactions (Textuals)
Total Property, Plant and Equipment, Net			11,935.7	[1]	10,772.8
Charitable Contribution to AEP Foundation [Abstract]
Related Party Charitable Contribuions to AEP Foundation						6.5
AEP Transmission Co [Member] \| Direct Sales to East Affiliates [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			0		0	0
AEP Transmission Co [Member] \| Auction Sales to OPCo [Member]
Affiliated Revenues and Purchases
Affiliated Revenues					0	0
AEP Transmission Co [Member] \| Direct Sales to AEPEP [Member]
Affiliated Revenues and Purchases
Affiliated Revenues					0	0
AEP Transmission Co [Member] \| Transmission Revenues [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			1,136.1		885	795.5
AEP Transmission Co [Member] \| Other Revenues [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			17.8		11.3	11.2
Appalachian Power Co [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			197.9		174.7	205.3
Transmission Service Charges
PJM Net Transmission Service Charges			302		243.2	222.3
Barging, Urea Transloading and Other Services
Expenses from Barging, Urea Transloading and Other Services			40.1		43.7	38.9
Sales and Purchases of Property
Related Party Sales of Property			6.2		5.7	5.5
Related Party Purchases of Property			1		1.3	6
Related Party Transactions (Textuals)
Total Property, Plant and Equipment, Net			11,804.3		11,394.1
Charitable Contribution to AEP Foundation [Abstract]
Related Party Charitable Contribuions to AEP Foundation						8.9
Appalachian Power Co [Member] \| Direct Sales to East Affiliates [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			128.6		112.5	128.6
Appalachian Power Co [Member] \| Auction Sales to OPCo [Member]
Affiliated Revenues and Purchases
Affiliated Revenues	[2]				5.3	11.4
Appalachian Power Co [Member] \| Direct Sales to AEPEP [Member]
Affiliated Revenues and Purchases
Affiliated Revenues					0	0
Appalachian Power Co [Member] \| Transmission Revenues [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			60.3		49.1	58.5
Appalachian Power Co [Member] \| Other Revenues [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			9		7.8	6.8
Indiana Michigan Power Co [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			3.8		10.5	10.5
Cost of Purchased Power from Affiliate			217.9		172.8	214.9
Transmission Service Charges
PJM Net Transmission Service Charges			186.7		145.9	143.5
Central Machine Shop
Billings for Services from Central Machine Shop Facility			2.4		3.2	2.3
Sales and Purchases of Property
Related Party Sales of Property			7		1.5	7.5
Related Party Purchases of Property			0.6		3.4	0.9
Related Party Transactions (Textuals)
Total Property, Plant and Equipment, Net			7,310.9		7,052.3
Charitable Contribution to AEP Foundation [Abstract]
Related Party Charitable Contribuions to AEP Foundation						9
Indiana Michigan Power Co [Member] \| Auction Purchases From AEPEP [Member]
Affiliated Revenues and Purchases
Cost of Purchased Power from Affiliate	[2]		0		0	0
Indiana Michigan Power Co [Member] \| Auction Purchases From AEP Energy [Member]
Affiliated Revenues and Purchases
Cost of Purchased Power from Affiliate	[2]		0		0	0
Indiana Michigan Power Co [Member] \| Auction Purchases from AEPSC [Member]
Affiliated Revenues and Purchases
Cost of Purchased Power from Affiliate	[2]				0	0
Indiana Michigan Power Co [Member] \| Direct Purchases from AEGCo [Member]
Affiliated Revenues and Purchases
Cost of Purchased Power from Affiliate			217.9		172.8	214.9
Indiana Michigan Power Co [Member] \| Direct Sales to East Affiliates [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			0		0	0
Indiana Michigan Power Co [Member] \| Auction Sales to OPCo [Member]
Affiliated Revenues and Purchases
Affiliated Revenues	[2]				3.1	6.7
Indiana Michigan Power Co [Member] \| Direct Sales to AEPEP [Member]
Affiliated Revenues and Purchases
Affiliated Revenues					0	0
Indiana Michigan Power Co [Member] \| Transmission Revenues [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			(2.5)		2.9	0.7
Indiana Michigan Power Co [Member] \| Other Revenues [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			6.3		4.5	3.1
Indiana Michigan Power Co [Member] \| AEP Wind Holdings LLC [Member] \| Generation and Marketing [Member]
Affiliated Revenues and Purchases
Cost of Purchased Power from Affiliate			10		11	9
Kentucky Power Co [Member]
Barging, Urea Transloading and Other Services
Expenses from Barging, Urea Transloading and Other Services			3.1		3.2	4.8
Central Machine Shop
Billings for Services from Central Machine Shop Facility			1		0.9	1.4
Ohio Power Co [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			24.8		41.5	27.3
Cost of Purchased Power from Affiliate			51.9		119.7	156
Transmission Service Charges
PJM Net Transmission Service Charges			508.9		417.4	373.4
Central Machine Shop
Billings for Services from Central Machine Shop Facility			0.4		0	0
Sales and Purchases of Property
Related Party Sales of Property			9.2		7	7
Related Party Purchases of Property			1.4		1.2	3
Related Party Transactions (Textuals)
Total Property, Plant and Equipment, Net			7,963		7,452.1
Charitable Contribution to AEP Foundation [Abstract]
Related Party Charitable Contribuions to AEP Foundation						5.4
Ohio Power Co [Member] \| Auction Purchases From AEPEP [Member]
Affiliated Revenues and Purchases
Cost of Purchased Power from Affiliate	[2]		26.6		51	64.6
Ohio Power Co [Member] \| Auction Purchases From AEP Energy [Member]
Affiliated Revenues and Purchases
Cost of Purchased Power from Affiliate	[2]		25.3		58.7	69.9
Ohio Power Co [Member] \| Auction Purchases from AEPSC [Member]
Affiliated Revenues and Purchases
Cost of Purchased Power from Affiliate	[2]				10	21.5
Ohio Power Co [Member] \| Direct Purchases from AEGCo [Member]
Affiliated Revenues and Purchases
Cost of Purchased Power from Affiliate			0		0	0
Ohio Power Co [Member] \| Direct Sales to East Affiliates [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			0		0	0
Ohio Power Co [Member] \| Auction Sales to OPCo [Member]
Affiliated Revenues and Purchases
Affiliated Revenues					0	0
Ohio Power Co [Member] \| Direct Sales to AEPEP [Member]
Affiliated Revenues and Purchases
Affiliated Revenues					0	0
Ohio Power Co [Member] \| Transmission Revenues [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			(1.1)		16.6	7.7
Ohio Power Co [Member] \| Other Revenues [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			25.9		24.9	19.6
Ohio Power Co [Member] \| AEP Wind Holdings LLC [Member] \| Generation and Marketing [Member]
Affiliated Revenues and Purchases
Cost of Purchased Power from Affiliate			20		23	17
Public Service Co Of Oklahoma [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			4.2		5.2	6.1
Transmission Service Charges
SPP Net Transmission Service Charges			94.7		69.7	46.9
Central Machine Shop
Billings for Services from Central Machine Shop Facility			0.7		0.9	1.1
Sales and Purchases of Property
Related Party Sales of Property			0.5		1.1	0.8
Related Party Purchases of Property			0.3		0.4	0.5
Related Party Transactions (Textuals)
Total Property, Plant and Equipment, Net			4,802.8		4,320
Charitable Contribution to AEP Foundation [Abstract]
Related Party Charitable Contribuions to AEP Foundation						3.4
Public Service Co Of Oklahoma [Member] \| OKTCo Radial Asset Transfer [Member] \| Net Book Value of Radial Assets [Member]
Related Party Transactions (Textuals)
Total Property, Plant and Equipment, Net					60
Public Service Co Of Oklahoma [Member] \| Direct Sales to East Affiliates [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			0		0	0
Public Service Co Of Oklahoma [Member] \| Auction Sales to OPCo [Member]
Affiliated Revenues and Purchases
Affiliated Revenues					0	0
Public Service Co Of Oklahoma [Member] \| Direct Sales to AEPEP [Member]
Affiliated Revenues and Purchases
Affiliated Revenues					0	0
Public Service Co Of Oklahoma [Member] \| Transmission Revenues [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			0		0	1.3
Public Service Co Of Oklahoma [Member] \| Other Revenues [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			4.2		5.2	4.8
Southwestern Electric Power Co [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			41.4		41	36.9
Revenue from Related Parties, Net			41		39	4.9
Transmission Service Charges
SPP Net Transmission Service Charges			56.2		31.3	20.1
Central Machine Shop
Billings for Services from Central Machine Shop Facility			2.7		0.5	1.1
Sales and Purchases of Property
Related Party Sales of Property			0.4		0.8	0.2
Related Party Purchases of Property			0.3		2.8	0.7
Related Party Transactions (Textuals)
Total Property, Plant and Equipment, Net			7,400.1		7,088.2
Charitable Contribution to AEP Foundation [Abstract]
Related Party Charitable Contribuions to AEP Foundation						5.5
Southwestern Electric Power Co [Member] \| Direct Sales to East Affiliates [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			0		0	0
Southwestern Electric Power Co [Member] \| Auction Sales to OPCo [Member]
Affiliated Revenues and Purchases
Affiliated Revenues					0	0
Southwestern Electric Power Co [Member] \| Direct Sales to AEPEP [Member]
Affiliated Revenues and Purchases
Affiliated Revenues					0	(0.1)
Southwestern Electric Power Co [Member] \| Transmission Revenues [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			39.6		37.4	3.6
Southwestern Electric Power Co [Member] \| Other Revenues [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			1.4		1.6	1.4
Southwestern Electric Power Co [Member] \| AEP Wind Holdings LLC [Member] \| Generation and Marketing [Member]
Affiliated Revenues and Purchases
Cost of Purchased Power from Affiliate			14		14	10
Wheeling Power Co [Member] [Domain]
Barging, Urea Transloading and Other Services
Expenses from Barging, Urea Transloading and Other Services			3.2		3.3	4.8
AEP Texas Inc. [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			3.9		90.8	160.5
ERCOT Transmission Service Charges
Billings from ETT for ERCOT Wholesale Transmission Services			28		28	27
Sales and Purchases of Property
Related Party Sales of Property			0.4		0.9	0.9
Related Party Purchases of Property			$ 0.4		1.5	0.3
Related Party Transactions (Textuals)
Jointly Owned Utility Plant, Proportionate Ownership Share			54.69%
Total Property, Plant and Equipment, Net			$ 10,635.4		9,813.6
Charitable Contribution to AEP Foundation [Abstract]
Related Party Charitable Contribuions to AEP Foundation						6.2
AEP Texas Inc. [Member] \| Direct Sales to East Affiliates [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			0		0	0
AEP Texas Inc. [Member] \| Auction Sales to OPCo [Member]
Affiliated Revenues and Purchases
Affiliated Revenues					0	0
AEP Texas Inc. [Member] \| Direct Sales to AEPEP [Member]
Affiliated Revenues and Purchases
Affiliated Revenues					87.5	157.2
AEP Texas Inc. [Member] \| Transmission Revenues [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			0		0	0
AEP Texas Inc. [Member] \| Other Revenues [Member]
Affiliated Revenues and Purchases
Affiliated Revenues			$ 3.9		$ 3.3	$ 3.3

[1]	Amount excludes $2.3 billion and $165 million for AEP and AEPTCo, respectively, of Property, Plant and Equipment - Net classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[2]	Refer to the Ohio Auctions section below for further information regarding these amounts.

Variable Interest Entities (Det

Variable Interest Entities (Details) $ in Millions		12 Months Ended
Variable Interest Entities (Details) $ in Millions		Dec. 31, 2021USD ($)MW		Dec. 31, 2020USD ($)		Dec. 31, 2019USD ($)MW	Dec. 31, 2018USD ($)
ASSETS
Current Assets		$ 7,809.2		$ 4,351.5
Net Property, Plant and Equipment		66,001.3	[1]	63,901.6
Other Noncurrent Assets		13,858.2		12,504.1
Total Assets		87,668.7	[2]	80,757.2		$ 75,892.3
LIABILITIES AND EQUITY
Current Liabilities		12,426.7		9,926.7
Noncurrent Liabilities		52,518.5		50,010.8
Equity		22,680.2		20,774.5		19,913.2	$ 19,059.4
Total Liabilities and Equity		87,668.7		80,757.2
Variable Interest Entities (Textuals)
Securitization Bonds		603.5		716.4
Securitized Assets		552.8		657
Equity Method Investments		1,447.5		1,406.3		1,356.6
Equity Method Investment Income		(91.7)		(91.1)		(72.1)
Generation and Marketing [Member]
ASSETS
Net Property, Plant and Equipment		1,864.4		1,744.1
Total Assets		4,263.6		3,585.9		3,123.8
Variable Interest Entities (Textuals)
Equity Method Investments		487.8		467		459.5
Equity Method Investment Income		10.6		(3.2)		3.8
Unregulated Operation [Member]
ASSETS
Net Property, Plant and Equipment		1,991.8		1,927
Protected Cell Of Energy Insurance Services, Inc. [Member]
Variable Interest Entities (Textuals)
Insurance Premium Expense to Protected Cell		30		31		$ 34
Protected Cell Of Energy Insurance Services, Inc. [Member] \| Variable Interest Entities [Member]
ASSETS
Current Assets		217.3		198.1
Net Property, Plant and Equipment		0		0
Other Noncurrent Assets		0		0
Total Assets		217.3		198.1
LIABILITIES AND EQUITY
Current Liabilities		37.5		43.1
Noncurrent Liabilities		82.3		62.5
Equity		97.5		92.5
Total Liabilities and Equity		$ 217.3		198.1
Transource Energy [Member]
Variable Interest Entities (Textuals)
Debt-to-Total Capitalization Maximum		67.50%
Transource Energy [Member] \| Variable Interest Entities [Member]
ASSETS
Current Assets		$ 38.8		22.2
Net Property, Plant and Equipment		475.4		458.7
Other Noncurrent Assets		3		3.7
Total Assets		517.2		484.6
LIABILITIES AND EQUITY
Current Liabilities		12.5		32.6
Noncurrent Liabilities		216.9		185
Equity		287.8		267
Total Liabilities and Equity		517.2		484.6
Apple Blossom and Black Oak [Member]
Variable Interest Entities (Textuals)
Noncontrolling Interest in Variable Interest Entity		108		119
HLBV Income for Noncontrolling Interests		7		6
Apple Blossom and Black Oak [Member] \| Variable Interest Entities [Member]
ASSETS
Current Assets		9.9		9.6
Net Property, Plant and Equipment		217.3		223.1
Other Noncurrent Assets		11.3		12.1
Total Assets		238.5		244.8
LIABILITIES AND EQUITY
Current Liabilities		6.6		5.3
Noncurrent Liabilities		5.2		4.9
Equity		226.7		234.6
Total Liabilities and Equity		238.5		244.8
Santa Rita East [Member]
Variable Interest Entities (Textuals)
Noncontrolling Interest in Variable Interest Entity		$ 59		61
Percentage of an Asset Acquired		85.00%
Production Tax Credits		$ 25		$ 23
Santa Rita East [Member] \| Generation and Marketing [Member]
Variable Interest Entities (Textuals)
Percentage of an Asset Acquired		85.00%		10.00%		75.00%
WindGenerationMWs \| MW		302				227
Santa Rita East [Member] \| Variable Interest Entities [Member]
ASSETS
Current Assets		$ 7.6		$ 6
Net Property, Plant and Equipment		437.6		453.1
Other Noncurrent Assets		0		0
Total Assets		445.2		459.1
LIABILITIES AND EQUITY
Current Liabilities		5.8		3.5
Noncurrent Liabilities		7		6.7
Equity		432.4		448.9
Total Liabilities and Equity		$ 445.2		459.1
Santa Rita East [Member] \| Initial Interest Acquired [Member]
Variable Interest Entities (Textuals)
Percentage of an Asset Acquired		75.00%
Santa Rita East [Member] \| Additional 10 Percent [Member]
Variable Interest Entities (Textuals)
Percentage of an Asset Acquired		10.00%
AEP Credit, Inc.
Variable Interest Entities (Textuals)
Minimum Percentage of Equity AEP Provides		5.00%
Percentage Of Short Term Borrowing Needs In Excess Of Third Party Financings		25.00%
AEP Credit, Inc. \| Variable Interest Entities [Member]
ASSETS
Current Assets		$ 996.6		960.4
Net Property, Plant and Equipment		0		0
Other Noncurrent Assets		10.4		12.9
Total Assets		1,007		973.3
LIABILITIES AND EQUITY
Current Liabilities		953.1		827.2
Noncurrent Liabilities		0.9		0.8
Equity		53		145.3
Total Liabilities and Equity		1,007		973.3
Dolet Hills Lignite Co, LLC [Member]
Variable Interest Entities (Textuals)
Equity Method Investment Income		$ (3.4)		(2.9)		$ (3)
Ohio Valley Electric Corporation [Member]
Variable Interest Entities (Textuals)
AEP's Ownership In OVEC		43.47%
Approximate OVEC Generating Capacity (MWs) \| MW		2,400
Intercompany Power Agreement End Date		2040
Outstanding Indebtedness		$ 1,100		1,300
Dry Lake Solar Project [Member]
Variable Interest Entities (Textuals)
Noncontrolling Interest in Variable Interest Entity		$ 35
Percentage of an Asset Acquired		75.00%
Investment Tax Credits		$ 33
Dry Lake Solar Project [Member] \| Generation and Marketing [Member]
Variable Interest Entities (Textuals)
Solar Generation MWs \| MW		100
Dry Lake Solar Project [Member] \| Variable Interest Entities [Member]
ASSETS
Current Assets		$ 4
Net Property, Plant and Equipment		146.1
Other Noncurrent Assets		0.3
Total Assets		150.4
LIABILITIES AND EQUITY
Current Liabilities		0.9
Noncurrent Liabilities		0.6
Equity		148.9
Total Liabilities and Equity		150.4
Capital Contribution From Parent [Member] \| Ohio Valley Electric Corporation [Member]
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures
As Reported on the Balance Sheet		4.4		4.4
Maximum Exposure		4.4		4.4
Retained Earnings [Member]
LIABILITIES AND EQUITY
Equity		11,667.1		10,687.8		9,900.9	9,325.3
AEP's Ratio of OVEC Debt [Member] \| Ohio Valley Electric Corporation [Member]
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures
As Reported on the Balance Sheet		0		0
Maximum Exposure	[3]	492		555
Total Investment [Member] \| Ohio Valley Electric Corporation [Member]
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures
As Reported on the Balance Sheet		4.4		4.4
Maximum Exposure		$ 496.4		559.4
Long-term PPA MWs [Member] \| Santa Rita East [Member]
Variable Interest Entities (Textuals)
WindGenerationMWs \| MW		260
Sold at Wholesale MWs [Member] \| Santa Rita East [Member]
Variable Interest Entities (Textuals)
WindGenerationMWs \| MW		42
Great Plains Energy Inc. [Member] \| Transource Energy [Member]
Variable Interest Entities (Textuals)
Equity and Voting Ownership Percentage		13.50%
Cleco Power, LLC [Member]
Variable Interest Entities (Textuals)
Percentage of VIE Sales of Lignite Produced		50.00%
AEP Transmission Co [Member]
ASSETS
Current Assets		$ 331.3		235.8
Net Property, Plant and Equipment		11,935.7	[1]	10,772.8
Other Noncurrent Assets		257.4		237.4
Total Assets		12,524.4	[4]	11,246		9,890.8
LIABILITIES AND EQUITY
Current Liabilities		1,296.9		1,137.5
Noncurrent Liabilities		5,851.4		5,395.6
Total Liabilities and Equity		12,524.4		11,246
AEP Transmission Co [Member] \| Unregulated Operation [Member]
ASSETS
Net Property, Plant and Equipment		0.3		0.7
AEP Transmission Co [Member] \| Billings from AEP Service Corporation [Member]
Variable Interest Entities (Textuals)
Billings from VIE		267.1		270.3		242.3
AEP Transmission Co [Member] \| Carrying Amount in AEP Service Corporation's Accounts Payable [Member]
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures
As Reported on the Balance Sheet		23.3		45.9
Maximum Exposure		23.3		45.9
Appalachian Power Co [Member]
ASSETS
Current Assets		925.3		674.1
Net Property, Plant and Equipment		11,804.3		11,394.1
Other Noncurrent Assets		1,359.3		1,247
Total Assets		14,088.9		13,315.2
LIABILITIES AND EQUITY
Current Liabilities		1,415.9		1,217.7
Noncurrent Liabilities		8,025.1		7,753.2
Equity		4,647.9		4,344.3		4,172.4	4,006.1
Total Liabilities and Equity		14,088.9		13,315.2
Variable Interest Entities (Textuals)
Securitization Bonds		198.8		223.8
Securitized Assets		185.1		210.1
Amount Of Power Purchased From OVEC		104.3		94.4		104.5
Appalachian Power Co [Member] \| Unregulated Operation [Member]
ASSETS
Net Property, Plant and Equipment		23.3		24
Appalachian Power Co [Member] \| Appalachian Consumer Rate Relief Funding [Member]
Variable Interest Entities (Textuals)
Securitized Assets		185		210
Appalachian Power Co [Member] \| Appalachian Consumer Rate Relief Funding [Member] \| Variable Interest Entities [Member]
ASSETS
Current Assets		16		16.8
Net Property, Plant and Equipment		0		0
Other Noncurrent Assets		187.8	[5]	212.7	[6]
Total Assets		203.8		229.5
LIABILITIES AND EQUITY
Current Liabilities		29		28.7
Noncurrent Liabilities		172.9		198.9
Equity		1.9		1.9
Total Liabilities and Equity		$ 203.8		229.5
Appalachian Power Co [Member] \| Ohio Valley Electric Corporation [Member]
Variable Interest Entities (Textuals)
Power Participation Ratio		15.69%
Outstanding Indebtedness		$ 177		200
Appalachian Power Co [Member] \| Billings from AEP Service Corporation [Member]
Variable Interest Entities (Textuals)
Billings from VIE		313.3		294.9		308.3
Appalachian Power Co [Member] \| Carrying Amount in AEP Service Corporation's Accounts Payable [Member]
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures
As Reported on the Balance Sheet		44.1		42.8
Maximum Exposure		44.1		42.8
Appalachian Power Co [Member] \| Retained Earnings [Member]
LIABILITIES AND EQUITY
Equity		2,534.4		2,248		2,078.3	1,922
Appalachian Power Co [Member] \| Other Noncurrent Assets [Member] \| Appalachian Consumer Rate Relief Funding [Member]
Variable Interest Entities (Textuals)
Intercompany Item Eliminated in Consolidation		2		3
Appalachian Power Co [Member] \| Current Liabilities [Member] \| Appalachian Consumer Rate Relief Funding [Member]
Variable Interest Entities (Textuals)
Securitization Bonds		26		25
Appalachian Power Co [Member] \| Noncurrent Liabilities [Member] \| Appalachian Consumer Rate Relief Funding [Member]
Variable Interest Entities (Textuals)
Securitization Bonds		173		199
Indiana Michigan Power Co [Member]
ASSETS
Current Assets		439.4		418.8
Net Property, Plant and Equipment		7,310.9		7,052.3
Other Noncurrent Assets		4,657.9		4,167.2
Total Assets		12,408.2		11,638.3
LIABILITIES AND EQUITY
Current Liabilities		894		1,104.5
Noncurrent Liabilities		8,729.5		7,784.6
Equity		2,784.7		2,749.2		2,544.4	2,352.8
Total Liabilities and Equity		12,408.2		11,638.3
Variable Interest Entities (Textuals)
Amount Of Power Purchased From OVEC		52.2		47.2		52.3
Indiana Michigan Power Co [Member] \| Unregulated Operation [Member]
ASSETS
Net Property, Plant and Equipment		23.3		28.2
Indiana Michigan Power Co [Member] \| DCC Fuel [Member]
Variable Interest Entities (Textuals)
Payments Made by I&M to DCC Fuel		91		94		95
Indiana Michigan Power Co [Member] \| DCC Fuel [Member] \| Variable Interest Entities [Member]
ASSETS
Current Assets		65.2		76.1
Net Property, Plant and Equipment		118.6		138.9
Other Noncurrent Assets		57.2		70.9
Total Assets		241		285.9
LIABILITIES AND EQUITY
Current Liabilities		65.1		76
Noncurrent Liabilities		175.9		209.9
Equity		0		0
Total Liabilities and Equity		$ 241		285.9
Indiana Michigan Power Co [Member] \| Ohio Valley Electric Corporation [Member]
Variable Interest Entities (Textuals)
Power Participation Ratio		7.85%
Outstanding Indebtedness		$ 89		100
Indiana Michigan Power Co [Member] \| Billings from AEP Service Corporation [Member]
Variable Interest Entities (Textuals)
Billings from VIE		200.9		210.2		184.8
Indiana Michigan Power Co [Member] \| Carrying Amount in AEP Service Corporation's Accounts Payable [Member]
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures
As Reported on the Balance Sheet		21.8		27.1
Maximum Exposure		21.8		27.1
Indiana Michigan Power Co [Member] \| Billings from AEP Generating Company [Member]
Variable Interest Entities (Textuals)
Billings from VIE		218		173		215
Indiana Michigan Power Co [Member] \| Carrying Amount in AEP Generating Company's Accounts Payable [Member]
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures
As Reported on the Balance Sheet		$ 18		9
Indiana Michigan Power Co [Member] \| Rockport Generating Plant (Unit No. 1) [Member]
Variable Interest Entities (Textuals)
Jointly Owned Utility Plant, Proportionate Ownership Share		50.00%
Indiana Michigan Power Co [Member] \| Retained Earnings [Member]
LIABILITIES AND EQUITY
Equity		$ 1,748.5		1,718.7		1,518.5	1,329.1
Ohio Power Co [Member]
ASSETS
Current Assets		327.5		256.3
Net Property, Plant and Equipment		7,963		7,452.1
Other Noncurrent Assets		975.3		1,002
Total Assets		9,265.8		8,710.4
LIABILITIES AND EQUITY
Current Liabilities		1,245.7		1,906.2
Noncurrent Liabilities		5,173.8		4,111.5
Equity		2,846.3		2,692.7		2,508.5	2,297.4
Total Liabilities and Equity		9,265.8		8,710.4
Variable Interest Entities (Textuals)
Amount Of Power Purchased From OVEC		133		120.8		132.7
Ohio Power Co [Member] \| Unregulated Operation [Member]
ASSETS
Net Property, Plant and Equipment		$ 9.8		9.9
Ohio Power Co [Member] \| Ohio Valley Electric Corporation [Member]
Variable Interest Entities (Textuals)
AEP's Ownership In OVEC		4.30%
Power Participation Ratio		19.93%
Outstanding Indebtedness		$ 226		255
Ohio Power Co [Member] \| Billings from AEP Service Corporation [Member]
Variable Interest Entities (Textuals)
Billings from VIE		234.9		232.8		230.4
Ohio Power Co [Member] \| Carrying Amount in AEP Service Corporation's Accounts Payable [Member]
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures
As Reported on the Balance Sheet		25.5		33.9
Maximum Exposure		25.5		33.9
Ohio Power Co [Member] \| Retained Earnings [Member]
LIABILITIES AND EQUITY
Equity		1,686.3		1,532.7		1,348.5	1,136.4
Public Service Co Of Oklahoma [Member]
ASSETS
Current Assets		386.8		181.3
Net Property, Plant and Equipment		4,802.8		4,320
Other Noncurrent Assets		1,209.4		489.4
Total Assets		6,399		4,990.7
LIABILITIES AND EQUITY
Current Liabilities		562.7		478.6
Noncurrent Liabilities		3,544.7		2,966.5
Equity		2,291.6		1,545.6		1,373.3	1,248
Total Liabilities and Equity		$ 6,399		4,990.7
Variable Interest Entities (Textuals)
Percentage of an Asset Acquired		45.50%
Public Service Co Of Oklahoma [Member] \| Unregulated Operation [Member]
ASSETS
Net Property, Plant and Equipment		$ 5.3		6.9
Public Service Co Of Oklahoma [Member] \| Billings from AEP Service Corporation [Member]
Variable Interest Entities (Textuals)
Billings from VIE		123.7		113.2		125.7
Public Service Co Of Oklahoma [Member] \| Carrying Amount in AEP Service Corporation's Accounts Payable [Member]
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures
As Reported on the Balance Sheet		13.7		15.7
Maximum Exposure		13.7		15.7
Public Service Co Of Oklahoma [Member] \| Retained Earnings [Member]
LIABILITIES AND EQUITY
Equity		1,095.4		974.3		851	724.7
Southwestern Electric Power Co [Member]
ASSETS
Current Assets		668.5		428
Net Property, Plant and Equipment		7,400.1		7,088.2
Other Noncurrent Assets		1,257.1		637.9
Total Assets		9,325.7		8,154.1
LIABILITIES AND EQUITY
Current Liabilities		538.7		763.6
Noncurrent Liabilities		5,637.2		4,762.8
Equity		3,149.8		2,627.7		2,441.1	2,315.6
Total Liabilities and Equity		$ 9,325.7		8,154.1
Variable Interest Entities (Textuals)
Percentage of an Asset Acquired		54.50%
Equity Method Investment Income		$ (3.4)		(2.9)		(3)
Southwestern Electric Power Co [Member] \| Unregulated Operation [Member]
ASSETS
Net Property, Plant and Equipment		53.9		97.8
Southwestern Electric Power Co [Member] \| Sabine Mining Co [Member]
Variable Interest Entities (Textuals)
Billings from VIE		162		131		110
Guarantees Of Mine Reclamation Amount		155
Estimated Final Cost Mine Reclamation		104
Amount Collected, Rider Mine Close Other Assets Noncurrent		10
Amount Collected Through Rider For Final Mine Closure And Reclamation Costs		85
Amount Collected, Rider Mine Close ARO Noncurrent		94
Southwestern Electric Power Co [Member] \| Sabine Mining Co [Member] \| Variable Interest Entities [Member]
ASSETS
Current Assets		77.2		88
Net Property, Plant and Equipment		51.8		97.3
Other Noncurrent Assets		104.1		99.3
Total Assets		233.1		284.6
LIABILITIES AND EQUITY
Current Liabilities		18.9		57.7
Noncurrent Liabilities		214.3		225.3
Equity		(0.1)		1.6
Total Liabilities and Equity		233.1		284.6
Southwestern Electric Power Co [Member] \| Dolet Hills Lignite Co, LLC [Member]
Variable Interest Entities (Textuals)
Billings from VIE		$ 47		142		55
Percentage of VIE Sales of Lignite Produced		50.00%
Percentage of DHLCs Debt Guaranteed by Each SWEPCo and CLECO		50.00%
Percentage of Management Fee Received by SWEPCo from DHLC		100.00%
Equity Method Investment Income		$ (3.4)		(2.9)		(3)
Southwestern Electric Power Co [Member] \| Billings from AEP Service Corporation [Member]
Variable Interest Entities (Textuals)
Billings from VIE		168.6		161.8		169.5
Southwestern Electric Power Co [Member] \| Carrying Amount in AEP Service Corporation's Accounts Payable [Member]
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures
As Reported on the Balance Sheet		20.5		22
Maximum Exposure		20.5		22
Southwestern Electric Power Co [Member] \| Capital Contribution From Parent [Member] \| Dolet Hills Lignite Co, LLC [Member]
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures
As Reported on the Balance Sheet		7.6		7.6
Maximum Exposure		7.6		7.6
Southwestern Electric Power Co [Member] \| Retained Earnings [Member]
LIABILITIES AND EQUITY
Equity		2,050.9		1,811.9		1,629.5	1,508.4
Southwestern Electric Power Co [Member] \| Retained Earnings [Member] \| Dolet Hills Lignite Co, LLC [Member]
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures
As Reported on the Balance Sheet		23.8		20.4
Maximum Exposure		23.8		20.4
Southwestern Electric Power Co [Member] \| SWEPCo's Share of Obligations [Member] \| Dolet Hills Lignite Co, LLC [Member]
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures
As Reported on the Balance Sheet		0		0
Maximum Exposure		50.3		98.5
Southwestern Electric Power Co [Member] \| Total Investment [Member] \| Dolet Hills Lignite Co, LLC [Member]
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures
As Reported on the Balance Sheet		31.4		28
Maximum Exposure		$ 81.7		126.5
AEP Generating Co [Member] \| Rockport Generating Plant (Unit No. 1) [Member]
Variable Interest Entities (Textuals)
Jointly Owned Utility Plant, Proportionate Ownership Share		50.00%
AEP Generating Co [Member] \| Rockport Generating Plant (Unit No. 2) [Member]
Variable Interest Entities (Textuals)
Percentage Interest in Lease		50.00%
Transource Energy [Member]
Variable Interest Entities (Textuals)
Equity and Voting Ownership Percentage		86.50%
AEP Texas Inc. [Member]
ASSETS
Current Assets		$ 347.2		310.9
Net Property, Plant and Equipment		10,635.4		9,813.6
Other Noncurrent Assets		854.1		905.7
Total Assets		11,836.7		11,030.2
LIABILITIES AND EQUITY
Current Liabilities		1,311.7		676.8
Noncurrent Liabilities		6,930.8		7,147.4
Equity		3,594.2		3,206		2,961.1	2,580.5
Total Liabilities and Equity		11,836.7		11,030.2
Variable Interest Entities (Textuals)
Securitization Bonds		404.7		492.6
Securitized Assets		$ 367.6		446.8
Jointly Owned Utility Plant, Proportionate Ownership Share		54.69%
AEP Texas Inc. [Member] \| Unregulated Operation [Member]
ASSETS
Net Property, Plant and Equipment		$ 1.2		1.2
AEP Texas Inc. [Member] \| AEP Texas Central Transition Funding Co [Member]
Variable Interest Entities (Textuals)
Securitized Assets		184		242
AEP Texas Inc. [Member] \| AEP Texas Central Transition Funding Co [Member] \| Variable Interest Entities [Member]
ASSETS
Current Assets		24.9		61.2
Net Property, Plant and Equipment		0		0
Other Noncurrent Assets		208.3	[7]	273.9	[8]
Total Assets		233.2		335.1
LIABILITIES AND EQUITY
Current Liabilities		71.2		69.8
Noncurrent Liabilities		157.8		246.5
Equity		4.2		18.8
Total Liabilities and Equity		233.2		335.1
AEP Texas Inc. [Member] \| Restoration Funding [Member]
Variable Interest Entities (Textuals)
Securitized Assets		183		205
AEP Texas Inc. [Member] \| Restoration Funding [Member] \| Variable Interest Entities [Member]
ASSETS
Current Assets		24.3		23.3
Net Property, Plant and Equipment		0		0
Other Noncurrent Assets		192.6	[9]	214.9	[10]
Total Assets		216.9		238.2
LIABILITIES AND EQUITY
Current Liabilities		36.1		33.9
Noncurrent Liabilities		179.6		203.1
Equity		1.2		1.2
Total Liabilities and Equity		216.9		238.2
AEP Texas Inc. [Member] \| Billings from AEP Service Corporation [Member]
Variable Interest Entities (Textuals)
Billings from VIE		206.9		199.4		206.6
AEP Texas Inc. [Member] \| Carrying Amount in AEP Service Corporation's Accounts Payable [Member]
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures
As Reported on the Balance Sheet		22.2		30.5
Maximum Exposure		22.2		30.5
AEP Texas Inc. [Member] \| Retained Earnings [Member]
LIABILITIES AND EQUITY
Equity		2,046.8		1,757		1,516	$ 1,337.7
AEP Texas Inc. [Member] \| Other Noncurrent Assets [Member] \| AEP Texas Central Transition Funding Co [Member]
Variable Interest Entities (Textuals)
Intercompany Item Eliminated in Consolidation		24		32
AEP Texas Inc. [Member] \| Other Noncurrent Assets [Member] \| Restoration Funding [Member]
Variable Interest Entities (Textuals)
Intercompany Item Eliminated in Consolidation		8		9
AEP Texas Inc. [Member] \| Current Liabilities [Member] \| AEP Texas Central Transition Funding Co [Member]
Variable Interest Entities (Textuals)
Securitization Bonds		68		66
AEP Texas Inc. [Member] \| Current Liabilities [Member] \| Restoration Funding [Member]
Variable Interest Entities (Textuals)
Securitization Bonds		23		23
AEP Texas Inc. [Member] \| Noncurrent Liabilities [Member] \| AEP Texas Central Transition Funding Co [Member]
Variable Interest Entities (Textuals)
Securitization Bonds		141		209
AEP Texas Inc. [Member] \| Noncurrent Liabilities [Member] \| Restoration Funding [Member]
Variable Interest Entities (Textuals)
Securitization Bonds		$ 173		195
Parent Company [Member] \| Ohio Valley Electric Corporation [Member]
Variable Interest Entities (Textuals)
AEP's Ownership In OVEC		39.17%
Joint Venture Wind Farms [Member]
Variable Interest Entities (Textuals)
Equity Method Investment, Ownership Percentage		50.00%
Production Tax Credits		$ 33		36
Equity Method Investments		399		376
Equity Method Investment Income		$ (12)		2
Berkshire Hathaway [Member]
Variable Interest Entities (Textuals)
Equity Method Investment, Ownership Percentage		50.00%
AEP Transmission Holdco [Member]
Variable Interest Entities (Textuals)
Equity Method Investment, Ownership Percentage		50.00%
BP Wind Energy [Member]
Variable Interest Entities (Textuals)
Equity Method Investment, Ownership Percentage		50.00%
ETT [Member]
Variable Interest Entities (Textuals)
Equity Method Investments		$ 733		732
Equity Method Investment Income		$ (66)		$ (68)		$ (66)

[1]	Amount excludes $2.3 billion and $165 million for AEP and AEPTCo, respectively, of Property, Plant and Equipment - Net classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[2]	Amount includes Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[3]	Based on the Registrants’ power participation ratios APCo, I&M and OPCo’s share of OVEC debt was $177 million, $89 million and $226 million as of December 31, 2021 and $200 million, $100 million and $255 million as of December 31, 2020, respectively.
[4]	Amount includes Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[5]	Includes an intercompany item eliminated in consolidation of $2 million.
[6]	Includes an intercompany item eliminated in consolidation of $3 million.
[7]	Includes an intercompany item eliminated in consolidation of $24 million.
[8]	Includes an intercompany item eliminated in consolidation of $32 million.
[9]	Includes an intercompany item eliminated in consolidation of $8 million.
[10]	Includes an intercompany item eliminated in consolidation of $9 million.

Property, Plant and Equipment_3

Property, Plant and Equipment (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021		Dec. 31, 2020		Dec. 31, 2019
Depreciation, Depletion and Amortization
Property, Plant and Equipment, Generation		$ 23,088.1		$ 23,133.9
Property, Plant and Equipment, Transmission		29,911.1		27,886.7
Property, Plant and Equipment, Distribution		24,440		23,972.1
Property, Plant and Equipment, Other		5,682.9		5,294.6
Property, Plant and Equipment, Construction Work in Progress		3,684.3		4,025.7
Accumulated Depreciation		20,805.1		20,411.4
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		66,001.3	[1]	63,901.6
Assets Held for Sale		2,919.7		0
Asset Retirement Obligations (ARO)
Beginning Balance	[3],[4],[5],[6]	2,516.7	[2]	2,418.9
Accretion Expense	[3],[4],[5],[6]	105	[2]	102.4
Liabilities Incurred	[3],[4],[5],[6]	22.8	[2]	0.3
Liabilities Settled	[3],[4],[5],[6]	(41.4)	[2]	(188)
Revisions in Cash Flow Estimates	[3],[4],[5],[6],[7]	138.6	[2]	183.1
Ending Balance	[3],[4],[5],[6]	2,741.7	[2]	2,516.7	[2]	$ 2,418.9
Asset Retirement Obligations (ARO) Liability for Nuclear Decommissioning of the Cook Plant		1,930		1,800
Liabilities Held for Sale		1,880.9		0
Allowance for Funds Used During Construction (AFUDC) and Interest Capitalization
Allowance for Equity Funds Used During Construction		139.7		148.1		168.4
Allowance for Borrowed Funds Used During Construction		53.8		66		88.7
Jointly-owned Electric Facilities
Utility Plant in Service		2,589.4		2,916.7
Construction Work in Progress		16.5		14.1
Accumulated Depreciation		947.4		1,109.7
Asset Impairments and Other Related Charges		11.6		0		156.4
Kentucky Power Co [Member]
Depreciation, Depletion and Amortization
Assets Held for Sale		2,300
Kentucky Power Co [Member]
Asset Retirement Obligations (ARO)
Liabilities Held for Sale		18
AEP Texas Inc. [Member]
Depreciation, Depletion and Amortization
Property, Plant and Equipment, Transmission		5,849.9		5,279.6
Property, Plant and Equipment, Distribution		4,917.2		4,580.8
Property, Plant and Equipment, Other		961.1		868.4
Property, Plant and Equipment, Construction Work in Progress		551.3		614.1
Accumulated Depreciation		1,644.1		1,529.3
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		10,635.4		9,813.6
Asset Retirement Obligations (ARO)
Beginning Balance	[4],[5]	4.6		29.1
Accretion Expense	[4],[5]	0.2		0.8
Liabilities Incurred	[4],[5]	0		0
Liabilities Settled	[4],[5]	(0.4)		(8.5)
Revisions in Cash Flow Estimates	[4],[5],[7]	0		(16.8)
Ending Balance	[4],[5]	4.4		4.6		29.1
Allowance for Funds Used During Construction (AFUDC) and Interest Capitalization
Allowance for Equity Funds Used During Construction		21.5		19.4		15.2
Allowance for Borrowed Funds Used During Construction		$ 10.5		12.5		20
Jointly-owned Electric Facilities
Percent of Ownership		54.69%
Asset Impairments and Other Related Charges		$ 0		0		32.5
AEP Transmission Co [Member]
Depreciation, Depletion and Amortization
Property, Plant and Equipment, Transmission		10,886.3		9,593.5
Property, Plant and Equipment, Other		427.4		329.5
Property, Plant and Equipment, Construction Work in Progress		1,394.8		1,422.6
Accumulated Depreciation		772.8		572.8
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		11,935.7	[1]	10,772.8
Assets Held for Sale		167.9		0
Asset Retirement Obligations (ARO)
Liabilities Held for Sale		27.6		0
Allowance for Funds Used During Construction (AFUDC) and Interest Capitalization
Allowance for Equity Funds Used During Construction		67.2		74		84.3
Allowance for Borrowed Funds Used During Construction		21		25.5		32.2
AEP Transmission Co [Member] \| Kentucky Transmission Company
Depreciation, Depletion and Amortization
Assets Held for Sale		165
Appalachian Power Co [Member]
Depreciation, Depletion and Amortization
Property, Plant and Equipment, Generation		6,683.9		6,633.7
Property, Plant and Equipment, Transmission		4,322.4		3,900.5
Property, Plant and Equipment, Distribution		4,683.3		4,464.3
Property, Plant and Equipment, Other		696.6		627.2
Property, Plant and Equipment, Construction Work in Progress		469.9		484.6
Accumulated Depreciation		5,051.8		4,716.2
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		11,804.3		11,394.1
Asset Retirement Obligations (ARO)
Beginning Balance	[4],[5]	313.1		111.1
Accretion Expense	[4],[5]	13.7		8.9
Liabilities Incurred	[4],[5]	0		0
Liabilities Settled	[4],[5]	(6.9)		(7.8)
Revisions in Cash Flow Estimates	[4],[5],[7]	84.7		200.9
Ending Balance	[4],[5]	404.6		313.1		111.1
Allowance for Funds Used During Construction (AFUDC) and Interest Capitalization
Allowance for Equity Funds Used During Construction		15.6		14.6		16.6
Allowance for Borrowed Funds Used During Construction		7.5		7.9		9.3
Jointly-owned Electric Facilities
Asset Impairments and Other Related Charges		0		0		92.9
Indiana Michigan Power Co [Member]
Depreciation, Depletion and Amortization
Property, Plant and Equipment, Generation		5,531.8		5,264.7
Property, Plant and Equipment, Transmission		1,783.1		1,696.4
Property, Plant and Equipment, Distribution		2,800.1		2,594.6
Property, Plant and Equipment, Other		792.9		686.7
Property, Plant and Equipment, Construction Work in Progress		302.8		362.4
Accumulated Depreciation		3,899.8		3,552.5
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		7,310.9		7,052.3
Asset Retirement Obligations (ARO)
Beginning Balance	[4],[5],[6]	1,813.8		1,748.6
Accretion Expense	[4],[5],[6]	72.9		70.2
Liabilities Incurred	[4],[5],[6]	0.3		0.1
Liabilities Settled	[4],[5],[6]	(0.1)		(0.2)
Revisions in Cash Flow Estimates	[4],[5],[6],[7]	59.4		(4.9)
Ending Balance	[4],[5],[6]	1,946.3		1,813.8		1,748.6
Asset Retirement Obligations (ARO) Liability for Nuclear Decommissioning of the Cook Plant		1,930		1,800
Fair Value of Legally Restricted Assets		3,540		2,980
Allowance for Funds Used During Construction (AFUDC) and Interest Capitalization
Allowance for Equity Funds Used During Construction		12.8		11.5		19.4
Allowance for Borrowed Funds Used During Construction		5.1		5.7		8.9
Ohio Power Co [Member]
Depreciation, Depletion and Amortization
Property, Plant and Equipment, Transmission		2,992.8		2,831.9
Property, Plant and Equipment, Distribution		6,070.6		5,708.3
Property, Plant and Equipment, Other		992.9		899.6
Property, Plant and Equipment, Construction Work in Progress		365		362.3
Accumulated Depreciation		2,458.3		2,350
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		7,963		7,452.1
Asset Retirement Obligations (ARO)
Beginning Balance	[4]	1.9		1.8
Accretion Expense	[4]	0.1		0.1
Liabilities Incurred	[4]	0		0
Liabilities Settled	[4]	(0.1)		0
Revisions in Cash Flow Estimates	[4],[7]	0		0
Ending Balance	[4]	1.9		1.9		1.8
Allowance for Funds Used During Construction (AFUDC) and Interest Capitalization
Allowance for Equity Funds Used During Construction		10.8		12.5		18.2
Allowance for Borrowed Funds Used During Construction		4.7		6.2		6.7
Public Service Co Of Oklahoma [Member]
Depreciation, Depletion and Amortization
Property, Plant and Equipment, Generation		1,802.4		1,480.7
Property, Plant and Equipment, Transmission		1,107.7		1,069.9
Property, Plant and Equipment, Distribution		3,004.9		2,853
Property, Plant and Equipment, Other		437		393.3
Property, Plant and Equipment, Construction Work in Progress		156		128.7
Accumulated Depreciation		1,705.2		1,605.6
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		4,802.8		4,320
Asset Retirement Obligations (ARO)
Beginning Balance	[4],[5]	47.4		52.2
Accretion Expense	[4],[5]	3.3		3.1
Liabilities Incurred	[4],[5]	7.6		0
Liabilities Settled	[4],[5]	(0.7)		(3.1)
Revisions in Cash Flow Estimates	[4],[5],[7]	0		(4.8)
Ending Balance	[4],[5]	57.6		47.4		52.2
Allowance for Funds Used During Construction (AFUDC) and Interest Capitalization
Allowance for Equity Funds Used During Construction		2.4		4		2.7
Allowance for Borrowed Funds Used During Construction		0.7		2		1.9
Southwestern Electric Power Co [Member]
Depreciation, Depletion and Amortization
Property, Plant and Equipment, Generation		4,734.5		4,681.4
Property, Plant and Equipment, Transmission		2,316.9		2,165.7
Property, Plant and Equipment, Distribution		2,514.3		2,382.5
Property, Plant and Equipment, Other		764		788.8
Property, Plant and Equipment, Construction Work in Progress		240.7		228.3
Accumulated Depreciation		3,170.3		3,158.5
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		7,400.1		7,088.2
Asset Retirement Obligations (ARO)
Beginning Balance	[3],[4],[5]	222.1		212.2
Accretion Expense	[3],[4],[5]	9.8		10.7
Liabilities Incurred	[3],[4],[5]	9.2		0
Liabilities Settled	[3],[4],[5]	(20.9)		(10.9)
Revisions in Cash Flow Estimates	[3],[4],[5],[7]	2.5		10.1
Ending Balance	[3],[4],[5]	222.7		222.1		212.2
Allowance for Funds Used During Construction (AFUDC) and Interest Capitalization
Allowance for Equity Funds Used During Construction		7		7.7		6.8
Allowance for Borrowed Funds Used During Construction		3		3.9		4
Jointly-owned Electric Facilities
Utility Plant in Service		2,965.6		2,916.7
Construction Work in Progress		16.5		14.1
Accumulated Depreciation		952.8		1,109.7
Asset Impairments and Other Related Charges		11.6		$ 0		$ 0
Southwestern Electric Power Co [Member] \| Ash Pond [Member]
Asset Retirement Obligations (ARO)
Revisions in Cash Flow Estimates		$ (18)
Dolet Hills Generating Station (Unit No. 1) [Member] \| Public Utilities, Inventory, Lignite [Member]
Jointly-owned Electric Facilities
Percent of Ownership	[8]	40.20%		40.20%
Utility Plant in Service	[8]	$ 0		$ 342.4
Construction Work in Progress	[8]	0		4.6
Accumulated Depreciation	[8]	$ 0		$ 295.4
Dolet Hills Generating Station (Unit No. 1) [Member] \| Southwestern Electric Power Co [Member] \| Public Utilities, Inventory, Lignite [Member]
Jointly-owned Electric Facilities
Percent of Ownership	[8]	40.20%		40.20%
Utility Plant in Service	[8]	$ 0		$ 342.4
Construction Work in Progress	[8]	0		4.6
Accumulated Depreciation	[8]	$ 0		$ 295.4
Flint Creek Generating Station (Unit No. 1) [Member] \| Coal [Member]
Jointly-owned Electric Facilities
Percent of Ownership	[9]	50.00%		50.00%
Utility Plant in Service	[9]	$ 377.6		$ 377.2
Construction Work in Progress	[9]	6.3		3
Accumulated Depreciation	[9]	$ 133.5		$ 116
Flint Creek Generating Station (Unit No. 1) [Member] \| Southwestern Electric Power Co [Member] \| Coal [Member]
Jointly-owned Electric Facilities
Percent of Ownership	[9]	50.00%		50.00%
Utility Plant in Service	[9]	$ 377.6		$ 377.2
Construction Work in Progress	[9]	6.3		3
Accumulated Depreciation	[9]	$ 133.5		$ 116
Pirkey Generating Station (Unit No. 1) [Member] \| Public Utilities, Inventory, Lignite [Member]
Jointly-owned Electric Facilities
Percent of Ownership	[9]	85.90%		85.90%
Utility Plant in Service	[9]	$ 613.8		$ 602.8
Construction Work in Progress	[9]	0		3.7
Accumulated Depreciation	[9]	$ 528.3		$ 441
Pirkey Generating Station (Unit No. 1) [Member] \| Southwestern Electric Power Co [Member] \| Public Utilities, Inventory, Lignite [Member]
Jointly-owned Electric Facilities
Percent of Ownership	[9]	85.90%		85.90%
Utility Plant in Service	[9]	$ 613.8		$ 602.8
Construction Work in Progress	[9]	0		3.7
Accumulated Depreciation	[9]	$ 528.3		$ 441
Turk Generating Plant [Member] \| Coal [Member]
Jointly-owned Electric Facilities
Percent of Ownership	[9]	73.30%		73.30%
Utility Plant in Service	[9]	$ 1,598		$ 1,594.3
Construction Work in Progress	[9]	10.2		2.8
Accumulated Depreciation	[9]	$ 285.6		$ 257.3
Turk Generating Plant [Member] \| Southwestern Electric Power Co [Member] \| Coal [Member]
Jointly-owned Electric Facilities
Percent of Ownership	[9]	73.30%		73.30%
Utility Plant in Service	[9]	$ 1,598		$ 1,594.3
Construction Work in Progress	[9]	10.2		2.8
Accumulated Depreciation	[9]	$ 285.6		$ 257.3
Rockport Generating Plant (Unit No. 1) [Member] \| Indiana Michigan Power Co [Member]
Jointly-owned Electric Facilities
Percent of Ownership		50.00%
Rockport Generating Plant (Unit No. 1) [Member] \| Indiana Michigan Power Co [Member] \| Coal [Member]
Jointly-owned Electric Facilities
Percent of Ownership	[10],[11],[12]	50.00%		50.00%
Utility Plant in Service	[10],[11],[12]	$ 1,247.2		$ 1,228.5
Construction Work in Progress	[10],[11],[12]	13.9		19.6
Accumulated Depreciation	[10],[11],[12]	$ 794.5		677.3
Rockport Generating Plant (Unit No. 1) [Member] \| AEP Generating Co [Member]
Jointly-owned Electric Facilities
Percent of Ownership		50.00%
Rockport Generating Plant (Unit No. 2) [Member] \| AEP Generating Co [Member]
Jointly-owned Electric Facilities
Percentage Interest in Lease		50.00%
NCWF [Member] \| Public Service Co Of Oklahoma [Member]
Jointly-owned Electric Facilities
Percent of Ownership		45.50%
NCWF [Member] \| Public Service Co Of Oklahoma [Member] \| Wind [Member]
Jointly-owned Electric Facilities
Percent of Ownership	[13],[14]	45.50%
Utility Plant in Service	[13],[14]	$ 313.7
Construction Work in Progress	[13],[14]	0
Accumulated Depreciation	[13],[14]	$ 4.2
NCWF [Member] \| Southwestern Electric Power Co [Member]
Jointly-owned Electric Facilities
Percent of Ownership		54.50%
NCWF [Member] \| Southwestern Electric Power Co [Member] \| Wind [Member]
Jointly-owned Electric Facilities
Percent of Ownership	[13],[14]	54.50%
Utility Plant in Service	[13],[14]	$ 376.2
Construction Work in Progress	[13],[14]	0
Accumulated Depreciation	[13],[14]	5.4
Regulated Operation [Member]
Depreciation, Depletion and Amortization
Property, Plant and Equipment, Generation	[15]	21,196.8		21,587.8
Property, Plant and Equipment, Transmission		29,866		27,841.5
Property, Plant and Equipment, Distribution		24,440		23,972.1
Property, Plant and Equipment, Other		5,249.8		4,852.4
Property, Plant and Equipment, Construction Work in Progress	[15]	3,632.4		3,815
Accumulated Depreciation		20,375.5		20,094.2
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		$ 64,009.5		$ 61,974.6
Regulated Operation [Member] \| Maximum [Member]
Depreciation, Depletion and Amortization
Depreciable Life Ranges - Generation		132 years		132 years		132 years
Depreciable Life Ranges - Transmission		75 years		75 years		81 years
Depreciable Life Ranges - Distribution		80 years		78 years		78 years
Depreciable Life Ranges - Other		75 years		75 years		75 years
Regulated Operation [Member] \| Minimum [Member]
Depreciation, Depletion and Amortization
Depreciable Life Ranges - Generation		20 years		20 years		20 years
Depreciable Life Ranges - Transmission		15 years		15 years		15 years
Depreciable Life Ranges - Distribution		7 years		7 years		7 years
Depreciable Life Ranges - Other		5 years		5 years		5 years
Regulated Operation [Member] \| Generation [Member] \| Maximum [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		7.80%		6.30%		5.50%
Regulated Operation [Member] \| Generation [Member] \| Minimum [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		2.70%		2.70%		2.50%
Regulated Operation [Member] \| Transmission [Member] \| Maximum [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		2.60%		2.60%		2.60%
Regulated Operation [Member] \| Transmission [Member] \| Minimum [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		2.00%		2.00%		1.80%
Regulated Operation [Member] \| Distribution [Member] \| Maximum [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		3.60%		3.70%		3.70%
Regulated Operation [Member] \| Distribution [Member] \| Minimum [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		2.80%		2.70%		2.70%
Regulated Operation [Member] \| Other Property Class [Member] \| Maximum [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		12.50%		11.30%		9.50%
Regulated Operation [Member] \| Other Property Class [Member] \| Minimum [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		3.00%		2.80%		2.60%
Regulated Operation [Member] \| AEP Texas Inc. [Member]
Depreciation, Depletion and Amortization
Property, Plant and Equipment, Generation		$ 0		$ 0
Property, Plant and Equipment, Transmission		5,849.9		5,279.6
Property, Plant and Equipment, Distribution		4,917.2		4,580.8
Property, Plant and Equipment, Other		958.7		866
Property, Plant and Equipment, Construction Work in Progress		551.3		614.1
Accumulated Depreciation		1,642.9		1,528.1
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		$ 10,634.2		$ 9,812.4
Regulated Operation [Member] \| AEP Texas Inc. [Member] \| Maximum [Member]
Depreciation, Depletion and Amortization
Depreciable Life Ranges - Transmission		75 years		75 years		81 years
Depreciable Life Ranges - Distribution		70 years		70 years		70 years
Depreciable Life Ranges - Other		50 years		50 years		50 years
Regulated Operation [Member] \| AEP Texas Inc. [Member] \| Minimum [Member]
Depreciation, Depletion and Amortization
Depreciable Life Ranges - Transmission		50 years		50 years		45 years
Depreciable Life Ranges - Distribution		7 years		7 years		7 years
Depreciable Life Ranges - Other		5 years		5 years		5 years
Regulated Operation [Member] \| AEP Texas Inc. [Member] \| Transmission [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		2.20%		2.00%		1.80%
Regulated Operation [Member] \| AEP Texas Inc. [Member] \| Distribution [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		2.90%		3.10%		3.50%
Regulated Operation [Member] \| AEP Texas Inc. [Member] \| Other Property Class [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		5.80%		6.10%		6.30%
Regulated Operation [Member] \| AEP Transmission Co [Member]
Depreciation, Depletion and Amortization
Property, Plant and Equipment, Generation		$ 0		$ 0
Property, Plant and Equipment, Transmission		10,886.3		9,593.5
Property, Plant and Equipment, Distribution		0		0
Property, Plant and Equipment, Other		427.2		328.8
Property, Plant and Equipment, Construction Work in Progress		1,394.8		1,422.6
Accumulated Depreciation		772.9		572.8
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		$ 11,935.4		$ 10,772.1
Regulated Operation [Member] \| AEP Transmission Co [Member] \| Maximum [Member]
Depreciation, Depletion and Amortization
Depreciable Life Ranges - Transmission		75 years		75 years		75 years
Depreciable Life Ranges - Other		56 years		64 years		64 years
Regulated Operation [Member] \| AEP Transmission Co [Member] \| Minimum [Member]
Depreciation, Depletion and Amortization
Depreciable Life Ranges - Transmission		24 years		24 years		24 years
Depreciable Life Ranges - Other		5 years		5 years		5 years
Regulated Operation [Member] \| AEP Transmission Co [Member] \| Transmission [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		2.50%		2.40%		2.00%
Regulated Operation [Member] \| AEP Transmission Co [Member] \| Other Property Class [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		6.70%		6.30%		5.80%
Regulated Operation [Member] \| Appalachian Power Co [Member]
Depreciation, Depletion and Amortization
Property, Plant and Equipment, Generation		$ 6,683.9		$ 6,633.7
Property, Plant and Equipment, Transmission		4,322.4		3,900.5
Property, Plant and Equipment, Distribution		4,683.3		4,464.3
Property, Plant and Equipment, Other		668.9		598
Property, Plant and Equipment, Construction Work in Progress		469.9		484.6
Accumulated Depreciation		5,047.4		4,711
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		$ 11,781		$ 11,370.1
Regulated Operation [Member] \| Appalachian Power Co [Member] \| Maximum [Member]
Depreciation, Depletion and Amortization
Depreciable Life Ranges - Generation		118 years		118 years		118 years
Depreciable Life Ranges - Transmission		75 years		75 years		71 years
Depreciable Life Ranges - Distribution		57 years		57 years		57 years
Depreciable Life Ranges - Other		55 years		55 years		55 years
Regulated Operation [Member] \| Appalachian Power Co [Member] \| Minimum [Member]
Depreciation, Depletion and Amortization
Depreciable Life Ranges - Generation		35 years		35 years		35 years
Depreciable Life Ranges - Transmission		15 years		15 years		15 years
Depreciable Life Ranges - Distribution		12 years		12 years		12 years
Depreciable Life Ranges - Other		5 years		5 years		5 years
Regulated Operation [Member] \| Appalachian Power Co [Member] \| Generation [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		3.60%		3.30%		3.20%
Regulated Operation [Member] \| Appalachian Power Co [Member] \| Transmission [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		2.10%		2.20%		1.80%
Regulated Operation [Member] \| Appalachian Power Co [Member] \| Distribution [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		3.50%		3.70%		3.70%
Regulated Operation [Member] \| Appalachian Power Co [Member] \| Other Property Class [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		8.50%		7.80%		7.20%
Regulated Operation [Member] \| Indiana Michigan Power Co [Member]
Depreciation, Depletion and Amortization
Property, Plant and Equipment, Generation		$ 5,531.8		$ 5,264.7
Property, Plant and Equipment, Transmission		1,783.1		1,696.4
Property, Plant and Equipment, Distribution		2,800.1		2,594.6
Property, Plant and Equipment, Other		755.1		644.6
Property, Plant and Equipment, Construction Work in Progress		302.8		362.4
Accumulated Depreciation		3,885.3		3,538.6
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		$ 7,287.6		$ 7,024.1
Regulated Operation [Member] \| Indiana Michigan Power Co [Member] \| Maximum [Member]
Depreciation, Depletion and Amortization
Depreciable Life Ranges - Generation		132 years		132 years		132 years
Depreciable Life Ranges - Transmission		70 years		70 years		73 years
Depreciable Life Ranges - Distribution		71 years		71 years		75 years
Depreciable Life Ranges - Other		51 years		51 years		50 years
Regulated Operation [Member] \| Indiana Michigan Power Co [Member] \| Minimum [Member]
Depreciation, Depletion and Amortization
Depreciable Life Ranges - Generation		20 years		20 years		20 years
Depreciable Life Ranges - Transmission		45 years		45 years		50 years
Depreciable Life Ranges - Distribution		14 years		14 years		9 years
Depreciable Life Ranges - Other		5 years		5 years		5 years
Regulated Operation [Member] \| Indiana Michigan Power Co [Member] \| Generation [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		4.70%		4.60%		4.00%
Regulated Operation [Member] \| Indiana Michigan Power Co [Member] \| Transmission [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		2.40%		2.30%		1.90%
Regulated Operation [Member] \| Indiana Michigan Power Co [Member] \| Distribution [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		3.40%		3.40%		3.40%
Regulated Operation [Member] \| Indiana Michigan Power Co [Member] \| Other Property Class [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		9.00%		10.20%		9.40%
Regulated Operation [Member] \| Ohio Power Co [Member]
Depreciation, Depletion and Amortization
Property, Plant and Equipment, Generation		$ 0		$ 0
Property, Plant and Equipment, Transmission		2,992.8		2,831.9
Property, Plant and Equipment, Distribution		6,070.6		5,708.3
Property, Plant and Equipment, Other		982.2		888.5
Property, Plant and Equipment, Construction Work in Progress		365		362.3
Accumulated Depreciation		2,457.4		2,348.8
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		$ 7,953.2		$ 7,442.2
Regulated Operation [Member] \| Ohio Power Co [Member] \| Maximum [Member]
Depreciation, Depletion and Amortization
Depreciable Life Ranges - Transmission		60 years		60 years		60 years
Depreciable Life Ranges - Distribution		70 years		65 years		65 years
Depreciable Life Ranges - Other		50 years		50 years		50 years
Regulated Operation [Member] \| Ohio Power Co [Member] \| Minimum [Member]
Depreciation, Depletion and Amortization
Depreciable Life Ranges - Transmission		39 years		39 years		39 years
Depreciable Life Ranges - Distribution		11 years		14 years		14 years
Depreciable Life Ranges - Other		5 years		5 years		5 years
Regulated Operation [Member] \| Ohio Power Co [Member] \| Transmission [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		2.30%		2.30%		2.30%
Regulated Operation [Member] \| Ohio Power Co [Member] \| Distribution [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		2.90%		3.10%		3.10%
Regulated Operation [Member] \| Ohio Power Co [Member] \| Other Property Class [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		6.10%		5.00%		4.90%
Regulated Operation [Member] \| Public Service Co Of Oklahoma [Member]
Depreciation, Depletion and Amortization
Property, Plant and Equipment, Generation		$ 1,802.4		$ 1,480.7
Property, Plant and Equipment, Transmission		1,107.7		1,069.9
Property, Plant and Equipment, Distribution		3,004.9		2,853
Property, Plant and Equipment, Other		433.5		388.1
Property, Plant and Equipment, Construction Work in Progress		156		128.7
Accumulated Depreciation		1,707		1,607.3
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		$ 4,797.5		$ 4,313.1
Regulated Operation [Member] \| Public Service Co Of Oklahoma [Member] \| Maximum [Member]
Depreciation, Depletion and Amortization
Depreciable Life Ranges - Generation		75 years		75 years		75 years
Depreciable Life Ranges - Transmission		75 years		75 years		75 years
Depreciable Life Ranges - Distribution		78 years		78 years		78 years
Depreciable Life Ranges - Other		56 years		64 years		64 years
Regulated Operation [Member] \| Public Service Co Of Oklahoma [Member] \| Minimum [Member]
Depreciation, Depletion and Amortization
Depreciable Life Ranges - Generation		30 years		35 years		35 years
Depreciable Life Ranges - Transmission		42 years		45 years		45 years
Depreciable Life Ranges - Distribution		15 years		15 years		15 years
Depreciable Life Ranges - Other		5 years		5 years		5 years
Regulated Operation [Member] \| Public Service Co Of Oklahoma [Member] \| Generation [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		2.80%		3.10%		2.90%
Regulated Operation [Member] \| Public Service Co Of Oklahoma [Member] \| Transmission [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		2.40%		2.20%		2.40%
Regulated Operation [Member] \| Public Service Co Of Oklahoma [Member] \| Distribution [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		2.90%		2.90%		2.90%
Regulated Operation [Member] \| Public Service Co Of Oklahoma [Member] \| Other Property Class [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		6.10%		5.70%		5.60%
Regulated Operation [Member] \| Southwestern Electric Power Co [Member]
Depreciation, Depletion and Amortization
Property, Plant and Equipment, Generation	[15]	$ 4,734.5		$ 4,681.4
Property, Plant and Equipment, Transmission		2,316.9		2,165.7
Property, Plant and Equipment, Distribution		2,514.3		2,382.5
Property, Plant and Equipment, Other		542		564.5
Property, Plant and Equipment, Construction Work in Progress	[15]	240.7		228.3
Accumulated Depreciation		3,002.2		3,032
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		$ 7,346.2		$ 6,990.4
Regulated Operation [Member] \| Southwestern Electric Power Co [Member] \| Maximum [Member]
Depreciation, Depletion and Amortization
Depreciable Life Ranges - Generation		65 years		65 years		70 years
Depreciable Life Ranges - Transmission		74 years		73 years		73 years
Depreciable Life Ranges - Distribution		80 years		67 years		70 years
Depreciable Life Ranges - Other		58 years		52 years		55 years
Regulated Operation [Member] \| Southwestern Electric Power Co [Member] \| Minimum [Member]
Depreciation, Depletion and Amortization
Depreciable Life Ranges - Generation		30 years		35 years		40 years
Depreciable Life Ranges - Transmission		49 years		47 years		50 years
Depreciable Life Ranges - Distribution		15 years		15 years		25 years
Depreciable Life Ranges - Other		5 years		5 years		5 years
Regulated Operation [Member] \| Southwestern Electric Power Co [Member] \| Generation [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		2.70%		2.70%		2.50%
Regulated Operation [Member] \| Southwestern Electric Power Co [Member] \| Transmission [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		2.40%		2.30%		2.40%
Regulated Operation [Member] \| Southwestern Electric Power Co [Member] \| Distribution [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		2.80%		2.70%		2.70%
Regulated Operation [Member] \| Southwestern Electric Power Co [Member] \| Other Property Class [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		8.60%		8.50%		7.60%
Unregulated Operation [Member]
Depreciation, Depletion and Amortization
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		$ 1,991.8		$ 1,927
Depreciable Life Ranges - Distribution						40 years
Unregulated Operation [Member] \| Maximum [Member]
Depreciation, Depletion and Amortization
Depreciable Life Ranges - Generation		59 years		59 years		59 years
Depreciable Life Ranges - Transmission		40 years		40 years		40 years
Depreciable Life Ranges - Other		35 years	[16]	50 years		50 years
Unregulated Operation [Member] \| Minimum [Member]
Depreciation, Depletion and Amortization
Depreciable Life Ranges - Generation		10 years		15 years		15 years
Depreciable Life Ranges - Transmission		30 years		30 years		30 years
Depreciable Life Ranges - Other		5 years	[16]	5 years		5 years
Unregulated Operation [Member] \| Generation [Member] \| Maximum [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		10.40%		4.00%		21.20%
Unregulated Operation [Member] \| Generation [Member] \| Minimum [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		3.80%		3.60%		3.20%
Unregulated Operation [Member] \| Transmission [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		2.60%		2.50%		2.50%
Unregulated Operation [Member] \| Distribution [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate						2.30%
Unregulated Operation [Member] \| Other Property Class [Member]
Depreciation, Depletion and Amortization
Annual Composite Depreciation Rate		16.50%		16.10%		17.60%
Unregulated Operation [Member] \| AEP Texas Inc. [Member]
Depreciation, Depletion and Amortization
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		$ 1.2		$ 1.2
Unregulated Operation [Member] \| AEP Transmission Co [Member]
Depreciation, Depletion and Amortization
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		0.3		0.7
Unregulated Operation [Member] \| Appalachian Power Co [Member]
Depreciation, Depletion and Amortization
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		23.3		24
Unregulated Operation [Member] \| Indiana Michigan Power Co [Member]
Depreciation, Depletion and Amortization
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		23.3		28.2
Unregulated Operation [Member] \| Ohio Power Co [Member]
Depreciation, Depletion and Amortization
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		9.8		9.9
Unregulated Operation [Member] \| Public Service Co Of Oklahoma [Member]
Depreciation, Depletion and Amortization
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		5.3		6.9
Unregulated Operation [Member] \| Southwestern Electric Power Co [Member]
Depreciation, Depletion and Amortization
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		53.9		97.8
Oklaunion Generating Station [Member] \| AEP Texas Inc. [Member]
Asset Retirement Obligations (ARO)
Revisions in Cash Flow Estimates		(17)
Oklaunion Generating Station [Member] \| Public Service Co Of Oklahoma [Member]
Asset Retirement Obligations (ARO)
Revisions in Cash Flow Estimates		(5)
Dolet Hills Power Station [Member] \| Southwestern Electric Power Co [Member]
Asset Retirement Obligations (ARO)
Revisions in Cash Flow Estimates		21
Jointly-owned Electric Facilities
Asset Impairments and Other Related Charges		12
Glen Lyn Station [Member] \| Appalachian Power Co [Member]
Asset Retirement Obligations (ARO)
Revisions in Cash Flow Estimates		79		199
Cook Nuclear Plant [Member] \| Indiana Michigan Power Co [Member]
Asset Retirement Obligations (ARO)
Revisions in Cash Flow Estimates		58
Generation and Marketing [Member]
Depreciation, Depletion and Amortization
Accumulated Depreciation		241		166.1
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		1,864.4		$ 1,744.1
Jointly-owned Electric Facilities
Asset Impairments and Other Related Charges		0				$ 31
Generation and Marketing [Member] \| Conesville Generating Station [Member]
Asset Retirement Obligations (ARO)
Liabilities Settled		$ (106)

[1]	Amount excludes $2.3 billion and $165 million for AEP and AEPTCo, respectively, of Property, Plant and Equipment - Net classified as Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[2]	Includes $18 million of ARO classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 7 for additional information.
[3]	Includes ARO related to Sabine and DHLC.
[4]	Includes ARO related to asbestos removal.
[5]	Includes ARO related to ash disposal facilities.
[6]	Includes ARO related to nuclear decommissioning costs for the Cook Plant of $1.93 billion and $1.80 billion as of December 31, 2021 and 2020, respectively.
[7]	Unless discussed above, primarily related to ash ponds, landfills and mine reclamation, generally due to changes in estimated closure area, volumes and/or unit costs.
[8]	Operated by CLECO, a nonaffiliated company. The Dolet Hills Power Station was retired in December 2021.
[9]	Operated by SWEPCo.
[10]	AEGCo owns 50% of Unit 1 with I&M and 50% of capital additions for Unit 2.
[11]	Amounts include I&M’s 50% ownership of both Unit 1 and capital additions for Unit 2. Unit 2 is subject to a finance lease with a nonaffiliated company. See the “Rockport Lease” section of Note 13 for additional information.
[12]	Operated by I&M.
[13]	Operated by PSO.
[14]	PSO and SWEPCo own undivided interests of 45.5% and 54.5% of the NCWF, respectively. Sundance was placed into service in April 2021. Maverick was placed into service in September 2021. See the “Acquisitions” section of Note 7 for additional information.
[15]	AEP and SWEPCo’s regulated generation and regulated CWIP include amounts related to SWEPCo’s Arkansas jurisdictional share of the Turk Plant.
[16]	In 2020 management announced plans to retire the Pirkey Plant in 2023 and the related depreciable lives have been adjusted accordingly. See Note 5 - Effects of Regulation for additional information.

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021		Dec. 31, 2020		Dec. 31, 2019
Disaggregation of Revenue
Revenue from Contracts with Customers		$ 16,792		$ 14,918.5		$ 15,561.4
Revenue, Performance Obligation
Fixed Performance Obligations		1,647.6
Revenues		16,792		14,918.5		15,561.4
Revenue Textuals
Revenue from Related Parties		0		0		0
Redemption of Noncontrolling Interest		0		(100.2)		0
2022 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		1,231.9
2023-2024 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		160.8
2025-2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		157.9
After 2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		97
Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		12,157.6		11,364		11,851.9
Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		6,090.8		5,693.7		5,713.6
Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		3,289.7		3,064.8		3,308.2
Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,562.6		2,407.4		2,607.2
Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		214.5		198.1		222.9
Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		4,014.5		3,209.7		3,444.2
Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,080.5		720.2		1,062.4
Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,178.3	[1]	1,051.8	[2]	979.4	[3]
Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		83.3	[4]	59.3	[5]	57.3	[6]
Retail, Trading and Marketing Revenue [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,672.4	[7]	1,378.4	[8]	1,345.1	[9]
Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		350.9	[4]	289.6	[5]	316.7	[6]
Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		16,523		14,863.3		15,612.8
Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		269		55.2		(51.4)
Alternative [Member]
Revenue, Performance Obligation
Revenues		41.4	[4]	(6.3)	[5]	(113.1)	[6]
Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		367.4		305.6		274.9
Revenue, Performance Obligation
Revenues		227.6	[4],[10]	61.5	[5],[11]	61.7	[6],[12]
AEP Texas Inc. [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,587.7		1,528		1,551.6
Revenue, Performance Obligation
Fixed Performance Obligations		531
Revenues		1,593.8		1,618.9		1,709.3
Current Assets
Affiliated Companies - Contracts with Customers		7.9		5.1
Revenue Textuals
Revenue from Related Parties		3.9		90.8		160.5
AEP Texas Inc. [Member] \| Short-term Contract with Customer [Member]
Current Assets
Affiliated Companies - Contracts with Customers		0.4		0.2
AEP Texas Inc. [Member] \| 2022 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		531
AEP Texas Inc. [Member] \| 2023-2024 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
AEP Texas Inc. [Member] \| 2025-2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
AEP Texas Inc. [Member] \| After 2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
AEP Texas Inc. [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,049		1,079.9		1,142.3
AEP Texas Inc. [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		550.3		563.6		571.5
AEP Texas Inc. [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		358.5		366.7		411.5
AEP Texas Inc. [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		108.9		120.1		129.4
AEP Texas Inc. [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		31.3		29.5		29.9
AEP Texas Inc. [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		497.5		399.9		379.2
AEP Texas Inc. [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[13]	0	[14]	0	[15]
AEP Texas Inc. [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		497.5	[16]	399.9	[17]	379.2	[18]
AEP Texas Inc. [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		41.2	[19]	48.2	[20]	30.1	[21]
AEP Texas Inc. [Member] \| Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		6.1		90.9		157.7
AEP Texas Inc. [Member] \| Alternative [Member]
Revenue, Performance Obligation
Revenues		6.1	[22]	3.4	[23]	0.6	[24]
AEP Texas Inc. [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		3.5		3.2		2.9
Revenue, Performance Obligation
Revenues		0	[22]	87.5	[23]	157.1	[24]
AEP Transmission Co [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,410.9		1,232.7		1,042.1
Revenue, Performance Obligation
Fixed Performance Obligations		1,510.3
Revenues		1,469.3		1,145.7		1,021.4
Current Assets
Affiliated Companies - Contracts with Customers		96.1		81.2
Revenue Textuals
Revenue from Related Parties		1,153.9		896.3		806.7
AEP Transmission Co [Member] \| Short-term Contract with Customer [Member]
Current Assets
Affiliated Companies - Contracts with Customers		95.5		81
AEP Transmission Co [Member] \| 2022 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		1,510.3
AEP Transmission Co [Member] \| 2023-2024 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
AEP Transmission Co [Member] \| 2025-2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
AEP Transmission Co [Member] \| After 2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
AEP Transmission Co [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
AEP Transmission Co [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
AEP Transmission Co [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
AEP Transmission Co [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
AEP Transmission Co [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
AEP Transmission Co [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,393.9		1,210.3		1,025.5
AEP Transmission Co [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[13]	0	[14]	0	[15]
AEP Transmission Co [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,393.9	[16]	1,210.3	[17]	1,025.5	[18]
Revenue Textuals
Revenue from Related Parties		1,100		952		782
AEP Transmission Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		17	[19]	22.4	[20]	16.6	[21]
AEP Transmission Co [Member] \| Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		58.4		(87)		(20.7)
AEP Transmission Co [Member] \| Alternative [Member]
Revenue, Performance Obligation
Revenues		58.4	[22]	(87)	[23]	(20.7)	[24]
AEP Transmission Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0.3		0.6		0.1
Revenue, Performance Obligation
Revenues		0	[22]	0	[23]	0	[24]
Appalachian Power Co [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		3,092.9		2,809.2		2,911.1
Revenue, Performance Obligation
Fixed Performance Obligations		268.5
Revenues		3,105.2		2,796.2		2,924.7
Current Assets
Affiliated Companies - Contracts with Customers		129.9		64.3
Revenue Textuals
Revenue from Related Parties		197.9		174.7		205.3
Appalachian Power Co [Member] \| Short-term Contract with Customer [Member]
Current Assets
Affiliated Companies - Contracts with Customers		117.8		52.7
Appalachian Power Co [Member] \| 2022 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		201.5
Appalachian Power Co [Member] \| 2023-2024 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		32.2
Appalachian Power Co [Member] \| 2025-2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		23.2
Appalachian Power Co [Member] \| After 2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		11.6
Appalachian Power Co [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,591		2,388.7		2,494.2
Appalachian Power Co [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,379.6		1,250.6		1,266.9
Appalachian Power Co [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		556.3		517		559.9
Appalachian Power Co [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		584.3		553.5		592.2
Appalachian Power Co [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		70.8		67.6		75.2
Appalachian Power Co [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		431.5		361		355.1
Appalachian Power Co [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		302.7	[13]	230.2	[14]	251.5	[15]
Revenue Textuals
Revenue from Related Parties		129		112		129
Appalachian Power Co [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		128.8	[16]	130.8	[17]	103.6	[18]
Appalachian Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		70.4	[19]	59.5	[20]	61.8	[21]
Appalachian Power Co [Member] \| Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		12.3		(13)		13.6
Appalachian Power Co [Member] \| Alternative [Member]
Revenue, Performance Obligation
Revenues		12.3	[22]	(13)	[23]	13.6	[24]
Appalachian Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		11.8		10.6		11.2
Revenue, Performance Obligation
Revenues		0	[22]	0	[23]	0	[24]
Indiana Michigan Power Co [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,330.7		2,236		2,308.1
Revenue, Performance Obligation
Fixed Performance Obligations		59.8
Revenues		2,326.7		2,241.8		2,306.7
Current Assets
Affiliated Companies - Contracts with Customers		78.2		51.3
Revenue Textuals
Revenue from Related Parties		3.8		10.5		10.5
Indiana Michigan Power Co [Member] \| Short-term Contract with Customer [Member]
Current Assets
Affiliated Companies - Contracts with Customers		61.2		34.8
Indiana Michigan Power Co [Member] \| 2022 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		37.7
Indiana Michigan Power Co [Member] \| 2023-2024 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		8.8
Indiana Michigan Power Co [Member] \| 2025-2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		8.8
Indiana Michigan Power Co [Member] \| After 2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		4.5
Indiana Michigan Power Co [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,874.8		1,847.4		1,782.2
Indiana Michigan Power Co [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		805.4		794.1		730
Indiana Michigan Power Co [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		507.2		499.3		494.2
Indiana Michigan Power Co [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		557		547.4		550.7
Indiana Michigan Power Co [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		5.2		6.6		7.3
Indiana Michigan Power Co [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		351.8		303.6		427.5
Indiana Michigan Power Co [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		318.1	[13]	274.6	[14]	402.4	[15]
Indiana Michigan Power Co [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		33.7	[16]	29	[17]	25.1	[18]
Indiana Michigan Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		104.1	[19]	85	[20]	98.4	[21]
Indiana Michigan Power Co [Member] \| Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		(4)		5.8		(1.4)
Indiana Michigan Power Co [Member] \| Alternative [Member]
Revenue, Performance Obligation
Revenues		(4)	[22]	5.8	[23]	(1.4)	[24]
Indiana Michigan Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		7.7		5.2		10.7
Revenue, Performance Obligation
Revenues		0	[22]	0	[23]	0	[24]
Revenue Textuals
Revenue from Related Parties		60		69		73
Ohio Power Co [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,837.5		2,665		2,748.8
Revenue, Performance Obligation
Fixed Performance Obligations		78.3
Revenues		2,899.1		2,749.1		2,797.6
Current Assets
Affiliated Companies - Contracts with Customers		71.8		65.1
Revenue Textuals
Revenue from Related Parties		24.8		41.5		27.3
Ohio Power Co [Member] \| Short-term Contract with Customer [Member]
Current Assets
Affiliated Companies - Contracts with Customers		51.7		45.9
Ohio Power Co [Member] \| 2022 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		78.3
Ohio Power Co [Member] \| 2023-2024 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
Ohio Power Co [Member] \| 2025-2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
Ohio Power Co [Member] \| After 2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
Ohio Power Co [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,609.5		2,488.5		2,553.5
Ohio Power Co [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,587.9		1,523.4		1,502
Ohio Power Co [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		722.7		682		738.5
Ohio Power Co [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		286.3		270		299.9
Ohio Power Co [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		12.6		13.1		13.1
Ohio Power Co [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		74.9		67		56
Ohio Power Co [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[13]	0	[14]	0	[15]
Ohio Power Co [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		74.9	[16]	67	[17]	56	[18]
Ohio Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		153.1	[19]	109.5	[20]	139.3	[21]
Ohio Power Co [Member] \| Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		61.6		84.1		48.8
Ohio Power Co [Member] \| Alternative [Member]
Revenue, Performance Obligation
Revenues		42.6	[22]	66.6	[23]	31.7	[24]
Ohio Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		10.6		9		10.8
Revenue, Performance Obligation
Revenues		19	[22]	17.5	[23]	17.1	[24]
Public Service Co Of Oklahoma [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,474.3		1,263.9		1,512.8
Revenue, Performance Obligation
Fixed Performance Obligations		13.1
Revenues		1,474.4		1,266.1		1,481.8
Current Assets
Affiliated Companies - Contracts with Customers		35		15.6
Revenue Textuals
Revenue from Related Parties		4.2		5.2		6.1
Public Service Co Of Oklahoma [Member] \| Short-term Contract with Customer [Member]
Current Assets
Affiliated Companies - Contracts with Customers		18.8		7.8
Public Service Co Of Oklahoma [Member] \| 2022 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		13.1
Public Service Co Of Oklahoma [Member] \| 2023-2024 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
Public Service Co Of Oklahoma [Member] \| 2025-2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
Public Service Co Of Oklahoma [Member] \| After 2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
Public Service Co Of Oklahoma [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,382.6		1,186.6		1,423.8
Public Service Co Of Oklahoma [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		651.9		579.4		650.2
Public Service Co Of Oklahoma [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		378.9		320.1		388.5
Public Service Co Of Oklahoma [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		274.1		221.1		303.5
Public Service Co Of Oklahoma [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		77.7		66		81.6
Public Service Co Of Oklahoma [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		60.4		42.6		67
Public Service Co Of Oklahoma [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		22.9	[13]	15.1	[14]	39.5	[15]
Public Service Co Of Oklahoma [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		37.5	[16]	27.5	[17]	27.5	[18]
Public Service Co Of Oklahoma [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		31.3	[19]	34.7	[20]	22	[21]
Public Service Co Of Oklahoma [Member] \| Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		0.1		2.2		(31)
Public Service Co Of Oklahoma [Member] \| Alternative [Member]
Revenue, Performance Obligation
Revenues		0.1	[22]	2.2	[23]	(31)	[24]
Public Service Co Of Oklahoma [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		4.9		14.8		6.1
Revenue, Performance Obligation
Revenues		0	[22]	0	[23]	0	[24]
Southwestern Electric Power Co [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,126		1,735.3		1,799.2
Revenue, Performance Obligation
Fixed Performance Obligations		43
Revenues		2,131.8		1,738.5		1,750.9
Current Assets
Affiliated Companies - Contracts with Customers		38.3		25.1
Revenue Textuals
Revenue from Related Parties		41.4		41		36.9
Southwestern Electric Power Co [Member] \| Short-term Contract with Customer [Member]
Current Assets
Affiliated Companies - Contracts with Customers		24.7		11.2
Southwestern Electric Power Co [Member] \| 2022 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		43
Southwestern Electric Power Co [Member] \| 2023-2024 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
Southwestern Electric Power Co [Member] \| 2025-2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
Southwestern Electric Power Co [Member] \| After 2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
Southwestern Electric Power Co [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,593.2		1,435.4		1,471.7
Southwestern Electric Power Co [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		709.5		630.8		638.6
Southwestern Electric Power Co [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		529.3		466.7		485.4
Southwestern Electric Power Co [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		344.4		328.8		338.7
Southwestern Electric Power Co [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		10		9.1		9
Southwestern Electric Power Co [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		509.3		273.2		301.4
Southwestern Electric Power Co [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		386.6	[13]	162	[14]	194.7	[15]
Southwestern Electric Power Co [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		122.7	[16]	111.2	[17]	106.7	[18]
Southwestern Electric Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		23.5	[19]	26.7	[20]	26.1	[21]
Southwestern Electric Power Co [Member] \| Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		5.8		3.2		(48.3)
Southwestern Electric Power Co [Member] \| Alternative [Member]
Revenue, Performance Obligation
Revenues		5.8	[22]	3.2	[23]	(48.3)	[24]
Southwestern Electric Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1.9		2.9		1.4
Revenue, Performance Obligation
Revenues		0	[22]	0	[23]	0	[24]
Consolidation Eliminations [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
Revenue, Performance Obligation
Revenues		(1,461.5)		(1,328)		(1,314.8)
Revenue Textuals
Revenue from Related Parties		(1,461.5)		(1,328)		(1,314.8)
Consolidation Eliminations [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(0.8)		(0.7)		(0.9)
Consolidation Eliminations [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
Consolidation Eliminations [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
Consolidation Eliminations [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(0.8)		(0.7)		(0.9)
Consolidation Eliminations [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
Consolidation Eliminations [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(1,261.2)		(1,111.3)		(960.6)
Consolidation Eliminations [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
Consolidation Eliminations [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(1,206)	[1]	(1,006.7)	[2]	(825)	[3]
Consolidation Eliminations [Member] \| Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(3.6)	[4]	(1.6)	[5]	0	[6]
Consolidation Eliminations [Member] \| Retail, Trading and Marketing Revenue [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(51.6)	[7]	(103)	[8]	(135.6)	[9]
Consolidation Eliminations [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(115.2)	[4]	(148.6)	[5]	(147.1)	[6]
Consolidation Eliminations [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(1,377.2)		(1,260.6)		(1,108.6)
Consolidation Eliminations [Member] \| Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		(84.3)		(67.4)		(206.2)
Consolidation Eliminations [Member] \| Alternative [Member]
Revenue, Performance Obligation
Revenues		(73.6)	[4]	7.5	[5]	(66.9)	[6]
Consolidation Eliminations [Member] \| Other Revenues [Member]
Revenue, Performance Obligation
Revenues		(10.7)	[4],[10]	(74.9)	[5],[11]	(139.3)	[6],[12]
Consolidation Eliminations [Member] \| AEP Transmission Co [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
Revenue, Performance Obligation
Revenues		0		0		0
Revenue Textuals
Revenue from Related Parties		0		0		0
Consolidation Eliminations [Member] \| AEP Transmission Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
Vertically Integrated Utilities [Member]
Revenue, Performance Obligation
Revenues		9,998.5		8,879.4		9,367.1
Revenue Textuals
Revenue from Related Parties		146.3		126.2		121.4
Vertically Integrated Utilities [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		8,499.9		7,796.6		8,157.1
Vertically Integrated Utilities [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		3,952.6		3,606.8		3,643.7
Vertically Integrated Utilities [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,208.5		2,016.2		2,155.3
Vertically Integrated Utilities [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,168.2		2,018		2,179
Vertically Integrated Utilities [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		170.6		155.6		179.1
Vertically Integrated Utilities [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,298.1		922.8		1,099.7
Vertically Integrated Utilities [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		942.6		588.3		807.6
Vertically Integrated Utilities [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		355.5	[1]	334.5	[2]	292.1	[3]
Vertically Integrated Utilities [Member] \| Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[4]	0	[5]	0	[6]
Vertically Integrated Utilities [Member] \| Retail, Trading and Marketing Revenue [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[7]	0	[8]	0	[9]
Vertically Integrated Utilities [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		187.5	[4]	163.2	[5]	168.2	[6]
Vertically Integrated Utilities [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		9,985.5		8,882.6		9,425
Vertically Integrated Utilities [Member] \| Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		13		(3.2)		(57.9)
Vertically Integrated Utilities [Member] \| Alternative [Member]
Revenue, Performance Obligation
Revenues		13.5	[4]	(3.2)	[5]	(57.9)	[6]
Vertically Integrated Utilities [Member] \| Other Revenues [Member]
Revenue, Performance Obligation
Revenues		(0.5)	[4],[10]	0	[5],[11]	0	[6],[12]
Transmission And Distribution Utilities [Member]
Revenue, Performance Obligation
Revenues		4,492.9		4,345.9		4,482.5
Revenue Textuals
Revenue from Related Parties		28.8		107.2		163.5
Transmission And Distribution Utilities [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		3,658.5		3,568.1		3,695.7
Transmission And Distribution Utilities [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,138.2		2,086.9		2,069.9
Transmission And Distribution Utilities [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,081.2		1,048.6		1,152.9
Transmission And Distribution Utilities [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		395.2		390.1		429.1
Transmission And Distribution Utilities [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		43.9		42.5		43.8
Transmission And Distribution Utilities [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		572.4		467		435.1
Transmission And Distribution Utilities [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
Transmission And Distribution Utilities [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		572.4	[1]	467	[2]	435.1	[3]
Transmission And Distribution Utilities [Member] \| Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[4]	0	[5]	0	[6]
Transmission And Distribution Utilities [Member] \| Retail, Trading and Marketing Revenue [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[7]	0	[8]	0	[9]
Transmission And Distribution Utilities [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		194.2	[4]	157.8	[5]	169.4	[6]
Transmission And Distribution Utilities [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		4,425.1		4,192.9		4,300.2
Transmission And Distribution Utilities [Member] \| Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		67.8		153		182.3
Transmission And Distribution Utilities [Member] \| Alternative [Member]
Revenue, Performance Obligation
Revenues		48.8	[4]	70	[5]	32.3	[6]
Transmission And Distribution Utilities [Member] \| Other Revenues [Member]
Revenue, Performance Obligation
Revenues		19	[4],[10]	83	[5],[11]	150	[6],[12]
AEP Transmission Holdco [Member]
Revenue, Performance Obligation
Revenues		1,526.2		1,198.8		1,073.2
AEP Transmission Holdco [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
AEP Transmission Holdco [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
AEP Transmission Holdco [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
AEP Transmission Holdco [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
AEP Transmission Holdco [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
AEP Transmission Holdco [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,456.4		1,257		1,077.2
AEP Transmission Holdco [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
AEP Transmission Holdco [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,456.4	[1]	1,257	[2]	1,077.2	[3]
Revenue Textuals
Revenue from Related Parties		1,100		965		794
AEP Transmission Holdco [Member] \| Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[4]	0	[5]	0	[6]
AEP Transmission Holdco [Member] \| Retail, Trading and Marketing Revenue [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[7]	0	[8]	0	[9]
AEP Transmission Holdco [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		17.1	[4]	22.4	[5]	16.6	[6]
AEP Transmission Holdco [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,473.5		1,279.4		1,093.8
AEP Transmission Holdco [Member] \| Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		52.7		(80.6)		(20.6)
AEP Transmission Holdco [Member] \| Alternative [Member]
Revenue, Performance Obligation
Revenues		52.7	[4]	(80.6)	[5]	(20.6)	[6]
AEP Transmission Holdco [Member] \| Other Revenues [Member]
Revenue, Performance Obligation
Revenues		0	[4],[10]	0	[5],[11]	0	[6],[12]
Generation and Marketing [Member]
Revenue, Performance Obligation
Revenues		2,163.7		1,725.6		1,857.6
Revenue Textuals
Revenue from Related Parties		55.4		104.6		135.8
Generation and Marketing [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
Generation and Marketing [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
Generation and Marketing [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
Generation and Marketing [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
Generation and Marketing [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
Generation and Marketing [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,947.4		1,679.7		1,792.8
Generation and Marketing [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		137.9		131.9		254.8
Generation and Marketing [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[1]	0	[2]	0	[3]
Generation and Marketing [Member] \| Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		86.9	[4]	60.9	[5]	57.3	[6]
Generation and Marketing [Member] \| Retail, Trading and Marketing Revenue [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,722.6	[7]	1,486.9	[8]	1,480.7	[9]
Revenue Textuals
Revenue from Related Parties		52		103		136
Generation and Marketing [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		7.2	[4]	2.3	[5]	4.9	[6]
Generation and Marketing [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,954.6		1,682		1,797.7
Generation and Marketing [Member] \| Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		209.1		43.6		59.9
Generation and Marketing [Member] \| Alternative [Member]
Revenue, Performance Obligation
Revenues		0	[4]	0	[5]	0	[6]
Generation and Marketing [Member] \| Other Revenues [Member]
Revenue, Performance Obligation
Revenues		209.1	[4],[10]	43.6	[5],[11]	59.9	[6],[12]
Other Segments [Member]
Revenue, Performance Obligation
Revenues	[25]	72.2		96.8		95.8
Revenue Textuals
Revenue from Related Parties	[25]	55.9		88.6		81.1
Other Segments [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
Other Segments [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
Other Segments [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
Other Segments [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
Other Segments [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
Other Segments [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1.4		(5.5)		0
Other Segments [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0
Other Segments [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[1]	0	[2]	0	[3]
Other Segments [Member] \| Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[4]	0	[5]	0	[6]
Other Segments [Member] \| Retail, Trading and Marketing Revenue [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1.4	[7]	(5.5)	[8]	0	[9]
Other Segments [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		60.1	[4]	92.5	[5]	104.7	[6]
Other Segments [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		61.5		87		104.7
Other Segments [Member] \| Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		10.7		9.8		(8.9)
Other Segments [Member] \| Alternative [Member]
Revenue, Performance Obligation
Revenues		0	[4]	0	[5]	0	[6]
Other Segments [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers	[25]	16.3		8.2		14.7
Revenue, Performance Obligation
Revenues		$ 10.7	[4],[10]	$ 9.8	[5],[11]	$ (8.9)	[6],[12]

[1]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $1.1 billion. The remaining affiliated amounts were immaterial.
[2]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $965 million. The remaining affiliated amounts were immaterial.
[3]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $794 million. The remaining affiliated amounts were immaterial.
[4]	Amounts include affiliated and nonaffiliated revenues.
[5]	Amounts include affiliated and nonaffiliated revenues.
[6]	Amounts include affiliated and nonaffiliated revenues.
[7]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $52 million. The remaining affiliated amounts were immaterial.
[8]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $103 million. The remaining affiliated amounts were immaterial.
[9]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $136 million. The remaining affiliated amounts were immaterial.
[10]	Generation & Marketing includes economic hedge activity.
[11]	Generation & Marketing includes economic hedge activity.
[12]	Generation & Marketing includes economic hedge activity.
[13]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $129 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial.
[14]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $112 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial.
[15]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $129 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial.
[16]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $1.1 billion. The remaining affiliated amounts were immaterial.
[17]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $952 million. The remaining affiliated amounts were immaterial.
[18]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $782 million. The remaining affiliated amounts were immaterial.
[19]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $60 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial.
[20]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $69 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial.
[21]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $73 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial.
[22]	Amounts include affiliated and nonaffiliated revenues.
[23]	Amounts include affiliated and nonaffiliated revenues.
[24]	Amounts include affiliated and nonaffiliated revenues.
[25]	Corporate and Other primarily includes the purchasing of receivables from certain AEP utility subsidiaries. This segment also includes Parent’s guarantee revenue received from affiliates, investment income, interest income, interest expense and other nonallocated costs.

Goodwill (Details)

Goodwill (Details) - USD ($) $ in Millions	12 Months Ended
Goodwill (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Changes in Carrying Amount of Goodwill
Goodwill	$ 52.5	$ 52.5	$ 52.5
Impairment Losses	0	0
Corporate and Other [Member]
Changes in Carrying Amount of Goodwill
Goodwill	37.1	37.1	37.1
Impairment Losses	0	0
Generation and Marketing [Member]
Changes in Carrying Amount of Goodwill
Goodwill	15.4	15.4	$ 15.4
Impairment Losses	$ 0	$ 0