Ohio Power (OHIPN) 10-Q27 Oct 222022 Q3 Quarterly reportFinancial data

Company Profile

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
Document and Entity Information - shares	Sep. 30, 2022	Oct. 27, 2022
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2022
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 Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		513,863,678
Entity Central Index Key	0000004904
Amendment Flag	false
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--12-31
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 Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding		100
Entity Central Index Key	0001721781
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 Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Central Index Key	0001702494
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 Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding		13,499,500
Entity Central Index Key	0000006879
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 Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding		1,400,000
Entity Central Index Key	0000050172
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 Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding		27,952,473
Entity Central Index Key	0000073986
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 Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding		9,013,000
Entity Central Index Key	0000081027
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 Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding		3,680
Entity Central Index Key	0000092487
The NASDAQ Stock Market LLC \| Common Stock [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 LLC \| Preferred Stock 2
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		3 Months Ended				9 Months Ended
Consolidated Statements of Income - USD ($) $ in Millions		Sep. 30, 2022		Sep. 30, 2021		Sep. 30, 2022		Sep. 30, 2021
Revenues
Revenue from Contracts with Customers		$ 5,526.1		$ 4,623		$ 14,758.4		$ 12,730.6
Sales to AEP Affiliates		0		0		0		0
TOTAL REVENUES		5,526.1		4,623		14,758.4		12,730.6
Expenses
Other Operation		797		735.3		2,079		1,894.6
Maintenance		298.1		277.8		909.6		817
Loss On Expected Sale Of KPCo		194.5		0		263.3		0
Asset Impairments and Other Related Charges		24.9		0		24.9		0
Establishment of Regulatory Asset		(37)		0		(37)		0
Gain on Sale of Mineral Rights		0		0		(116.3)		0
Depreciation and Amortization		821.8		700.3		2,416.8		2,103.9
Taxes Other Than Income Taxes		384.8		360.8		1,118.5		1,061.4
TOTAL EXPENSES		4,596		3,515.6		11,835.8		10,003
OPERATING INCOME (LOSS)		930.1		1,107.4		2,922.6		2,727.6
Other Income (Expense):
Other Income		4.8		(20.6)		(5.6)		34.2
Allowance for Equity Funds Used During Construction		35.6		37		95.2		103.9
Non-Service Cost Components of Net Periodic Benefit Cost		47.2		29.6		141.5		88.9
Interest Expense		(360.7)		(303.7)		(1,001.7)		(895.5)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		657		849.7		2,152		2,059.1
Income Tax Expense (Benefit)		(16.1)		69.8		90.7		185.5
Equity Earnings (Loss) of Unconsolidated Subsidiaries		10.2		17		(139.1)		75.9
Net Income (Loss)		683.3		796.9		1,922.2		1,949.5
Net Income (Loss) Attributable to Noncontrolling Interests		(0.4)		0.9		(0.7)		0.3
Earnings Attributable to Common Shareholders		$ 683.7		$ 796		$ 1,922.9		$ 1,949.2
Earnings Per Share
Weighted Average Number of Basic AEP Common Shares Outstanding		513,730,196		501,233,680		511,162,723		499,418,278
Total Basic Earnings Per Share Attributable to AEP Common Shareholders		$ 1.33		$ 1.59		$ 3.76		$ 3.90
Weighted Average Number of Diluted AEP Common Shares Outstanding		515,315,994		502,606,836		512,714,006		500,600,237
Total Diluted Earnings Per Share Attributable to AEP Common Shareholders		$ 1.33		$ 1.58		$ 3.75		$ 3.89
Common Stock, Dividends Per Share, Declared		$ 0.78		$ 0.74
Cash Flow Hedges, Tax		$ (19.5)		$ 47.8		$ 81.6		$ 97.3
Amortization of Pension and OPEB Deferred Costs, Tax		(0.8)		(0.5)		(4.5)		(1.6)
Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers		3,174.6		2,716.8		8,416.4		7,445.9
Transmission and Distribution Utilities [Member]
Revenues
Revenue from Contracts with Customers		1,525.5		1,195		4,064.5		3,366.9
Generation and Marketing [Member]
Revenues
Revenue from Contracts with Customers		733.1		617.4		1,997		1,641.6
Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		92.9		93.8		280.5		276.2
TOTAL REVENUES		128.3	[1]	154.8	[2],[3]	429.4	[4],[5]	188.7	[6],[7]
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold		2,111.9		1,441.4		5,177		4,126.1
AEP Texas Inc. [Member]
Revenues
Sales to AEP Affiliates		0.9		0.9		2.6		2.9
TOTAL REVENUES		508.9		432.6		1,404.4		1,195.3
Expenses
Other Operation		163.8		135.3		431.6		367.1
Maintenance		22.7		22		70.1		59.8
Depreciation and Amortization		117.7		87.6		342.7		287.1
Taxes Other Than Income Taxes		45.5		41.6		125.8		117.4
TOTAL EXPENSES		349.7		286.5		970.2		831.4
OPERATING INCOME (LOSS)		159.2		146.1		434.2		363.9
Other Income (Expense):
Interest Income		1.3		0.2		2.7		0.6
Allowance for Equity Funds Used During Construction		5.2		9.2		13.2		16.7
Non-Service Cost Components of Net Periodic Benefit Cost		4.2		2.8		12.5		8.3
Interest Expense		(55.4)		(44.2)		(153.2)		(132.5)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		114.5		114.1		309.4		257
Income Tax Expense (Benefit)		20.9		14.6		56.2		31.6
Net Income (Loss)		93.6		99.5		253.2		225.4
Earnings Per Share
Cash Flow Hedges, Tax		0.1		0.1		0.2		0.2
Amortization of Pension and OPEB Deferred Costs, Tax		0		0		0		0
AEP Texas Inc. [Member] \| Transmission and Distribution Utilities [Member]
Revenues
Revenue from Contracts with Customers		507.7		430.8		1,399.3		1,189.1
AEP Texas Inc. [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		0.3		0.9		2.5		3.3
TOTAL REVENUES		0	[8]	0	[9]	0	[10]	0	[11]
AEP Transmission Co [Member]
Revenues
Revenue from Contracts with Customers								0.3
Sales to AEP Affiliates		340.6		297.7		999.5		882.3
Provision for Refund Affiliated		(9.3)		(0.1)		(65.7)		(17.7)
Provision for Refund-Nonaffiliated		(1.9)		0		(12.2)		(2.3)
TOTAL REVENUES		418.5		377		1,183.3		1,104.2
Expenses
Other Operation		39.6		32.6		94.7		78.1
Maintenance		4.1		5.4		11.2		12.3
Depreciation and Amortization		87.4		76		256.2		219
Taxes Other Than Income Taxes		68.7		61		203		178.9
TOTAL EXPENSES		199.8		175		565.1		488.3
OPERATING INCOME (LOSS)		218.7		202		618.2		615.9
Other Income (Expense):
Interest Income		0.7		0.2		1		0.4
Allowance for Equity Funds Used During Construction		20.3		16		51.2		49.3
Interest Expense		(42.7)		(36.1)		(119.7)		(104.5)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		197		182.1		550.7		561.1
Income Tax Expense (Benefit)		44.3		36.7		124.1		115.4
Net Income (Loss)		152.7		145.4		426.6		445.7
Earnings Per Share
Revenues from Related Parties, Net of Provisions for Refund		331.3		297.6		933.8		864.6
AEP Transmission Co [Member] \| AEPTCo Parent [Member]
Revenues
Revenue from Contracts with Customers		0		0		0		0
Sales to AEP Affiliates		0		0		0		0
TOTAL REVENUES		0		0		0		0
Other Income (Expense):
Net Income (Loss)	[12]	0.1		0.1		0.2		0.2
AEP Transmission Co [Member] \| State Transcos [Member]
Revenues
Revenue from Contracts with Customers								0.3
Sales to AEP Affiliates		331.3		297.6		933.8		864.6
TOTAL REVENUES		418.5		377		1,183.3		1,104.2
Other Income (Expense):
Net Income (Loss)		152.6		145.3		426.4		445.5
AEP Transmission Co [Member] \| Transmission [Member]
Revenues
Revenue from Contracts with Customers		89.1		79.2		261.7		241.6
Earnings Per Share
Revenue from Contract with Customers, Net of Provisions for Refund, Including Assessed Tax		87.2		79.2		249.5		239.3
AEP Transmission Co [Member] \| Transmission [Member] \| State Transcos [Member]
Revenues
Revenue from Contracts with Customers		87.2		79.2		249.5		239.3
AEP Transmission Co [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		0		0.2		0		0.3
TOTAL REVENUES		0	[8]	0	[9]	0	[10]	0	[11]
Appalachian Power Co [Member]
Revenues
Sales to AEP Affiliates		67.6		52.4		187.6		140.6
TOTAL REVENUES		888.9		804		2,569.8		2,298
Expenses
Other Operation		182		173		514		442.1
Maintenance		69.3		69.1		214.6		184.4
Asset Impairments and Other Related Charges		24.9		0		24.9		0
Establishment of Regulatory Asset		(37)		0		(37)		0
Depreciation and Amortization		142.9		135.4		431		406.6
Taxes Other Than Income Taxes		41.5		39.8		121		116.7
TOTAL EXPENSES		741.6		670.5		2,102.7		1,870.1
OPERATING INCOME (LOSS)		147.3		133.5		467.1		427.9
Other Income (Expense):
Interest Income		2.6		0.2		3		0.8
Allowance for Equity Funds Used During Construction		2.2		4.3		6.8		12.1
Non-Service Cost Components of Net Periodic Benefit Cost		7.3		4.7		21.8		14.2
Interest Expense		(61.7)		(52.8)		(171.1)		(160.6)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		97.7		89.9		327.6		294.4
Income Tax Expense (Benefit)		5		3.6		24.5		19.3
Net Income (Loss)		92.7		86.3		303.1		275.1
Earnings Per Share
Cash Flow Hedges, Tax		(0.1)		0		(0.2)		2.3
Amortization of Pension and OPEB Deferred Costs, Tax		(0.3)		(0.2)		(0.9)		(0.8)
Appalachian Power Co [Member] \| Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers		818.4		748.5		2,370.4		2,149.2
Appalachian Power Co [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		2.9		3.1		11.8		8.2
TOTAL REVENUES		0.3	[8]	0	[9]	0.4	[10]	0	[11]
Appalachian Power Co [Member] \| Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold		318		253.2		834.2		720.3
Indiana Michigan Power Co [Member]
Revenues
Sales to AEP Affiliates		2		1.1		11.1		2.6
Other Revenues - Affiliated		13.3		14.7		38.4		41.2
TOTAL REVENUES		715.4		635.7		1,971.6		1,784
Expenses
Purchased Electricity from AEP Affiliates		67.9		63.3		184.6		172.7
Other Operation		162.4		167.5		450.9		482.4
Maintenance		55.9		52		167.7		165.4
Depreciation and Amortization		131.6		110.6		400.2		328.7
Taxes Other Than Income Taxes		22.4		27.8		76.2		83.8
TOTAL EXPENSES		590.8		509.8		1,646.8		1,494.8
OPERATING INCOME (LOSS)		124.6		125.9		324.8		289.2
Other Income (Expense):
Other Income		2.4		2.5		7.4		8.9
Allowance for Equity Funds Used During Construction						7.9		9.7
Non-Service Cost Components of Net Periodic Benefit Cost		6.3		4.1		18.8		12.3
Interest Expense		(31.2)		(30.2)		(92.5)		(86.6)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		102.1		102.3		258.5		223.8
Income Tax Expense (Benefit)		8		(1.8)		7.7		(8.3)
Net Income (Loss)		94.1		104.1		250.8		232.1
Earnings Per Share
Cash Flow Hedges, Tax		0.1		0.1		0.3		0.3
Amortization of Pension and OPEB Deferred Costs, Tax		(0.1)		0		(0.1)		0
Indiana Michigan Power Co [Member] \| Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers		695.7		618.2		1,912.1		1,735.1
Indiana Michigan Power Co [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		4.4		1.7		10		5.1
Sales to AEP Affiliates		15		17		44		46
TOTAL REVENUES		0	[8]	0	[9]	(0.1)	[10]	0	[11]
Indiana Michigan Power Co [Member] \| Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold		150.6		88.6		367.2		261.8
Ohio Power Co [Member]
Revenues
Sales to AEP Affiliates		4		4.3		11.6		21.9
TOTAL REVENUES		1,021.3		767.7		2,674.2		2,196.5
Expenses
Purchased Electricity from AEP Affiliates		0		3.5		9.8		48
Other Operation		267.3		245.1		728.2		622.9
Maintenance		47.8		39.3		136.7		116.4
Depreciation and Amortization		70.7		76.9		216.9		228.6
Taxes Other Than Income Taxes		131		126		379		366.2
TOTAL EXPENSES		916.3		675.5		2,345.6		1,895.7
OPERATING INCOME (LOSS)		105		92.2		328.6		300.8
Other Income (Expense):
Interest Income		0.2		0.2		0.8		0.5
Carrying Costs Income		0		0.1		0.2		1.1
Allowance for Equity Funds Used During Construction		3.9		2		10.3		7.6
Non-Service Cost Components of Net Periodic Benefit Cost		5.6		3.7		16.6		11
Interest Expense		(29.8)		(32.9)		(88.8)		(96.2)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		84.9		65.3		267.7		224.8
Income Tax Expense (Benefit)		13		8.9		38.6		26.2
Equity Earnings (Loss) of Unconsolidated Subsidiaries		0		0		0.8		0
Net Income (Loss)		71.9		56.4		229.9		198.6
Ohio Power Co [Member] \| Transmission and Distribution Utilities [Member]
Revenues
Revenue from Contracts with Customers		1,015.2		761		2,656.6		2,167.8
Ohio Power Co [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		2.1		2.4		6		6.8
TOTAL REVENUES		5.5	[8]	4.9	[9]	18.6	[10]	14.2	[11]
Ohio Power Co [Member] \| Purchased Electricity for Resale [Member]
Expenses
Cost of Goods and Services Sold		399.5		184.7		875		513.6
Public Service Co Of Oklahoma [Member]
Revenues
Sales to AEP Affiliates		0.7		1		2.1		3.1
TOTAL REVENUES		608.2		483.8		1,438.7		1,124.4
Expenses
Other Operation		116.3		102.3		301		262.7
Maintenance		31.3		21.2		88		68.1
Depreciation and Amortization		59.5		48.9		172.7		149
Taxes Other Than Income Taxes		15.6		12.1		43.6		37.1
TOTAL EXPENSES		516.3		380.4		1,279.5		957.7
OPERATING INCOME (LOSS)		91.9		103.4		159.2		166.7
Other Income (Expense):
Other Income		3		1.8		8.5		4.5
Non-Service Cost Components of Net Periodic Benefit Cost		3.1		2.1		9.4		6.4
Interest Expense		(22.4)		(16.2)		(62.6)		(44.7)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		75.6		91.1		114.5		132.9
Income Tax Expense (Benefit)		(31.3)		(2.1)		(41.2)		(3.7)
Net Income (Loss)		106.9		93.2		155.7		136.6
Earnings Per Share
Cash Flow Hedges, Tax		0		0		0		0
Public Service Co Of Oklahoma [Member] \| Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers		606.5		481.3		1,432.9		1,117.4
Public Service Co Of Oklahoma [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		1		1.5		3.7		3.9
TOTAL REVENUES		0	[8]	0	[9]	0	[10]	0	[11]
Public Service Co Of Oklahoma [Member] \| Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold		293.6		195.9		674.2		440.8
Southwestern Electric Power Co [Member]
Revenues
Sales to AEP Affiliates		18.2		13.5		43.7		32.2
TOTAL REVENUES		717.5		584.1		1,748.9		1,630.3
Expenses
Other Operation		114.1		91.7		308.7		270.6
Maintenance		32.9		33.7		107.8		99.5
Depreciation and Amortization		95.8		74.8		251.8		217.4
Taxes Other Than Income Taxes		34.2		28.9		94.9		89
TOTAL EXPENSES		567.9		443.5		1,432.3		1,329.2
OPERATING INCOME (LOSS)		149.6		140.6		316.6		301.1
Other Income (Expense):
Interest Income		2.7		2.8		13.9		6.9
Allowance for Equity Funds Used During Construction		1		1.4		3.4		5.4
Non-Service Cost Components of Net Periodic Benefit Cost		3.2		2.1		9.4		6.2
Interest Expense		(35.2)		(31.7)		(102)		(92.4)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		121.3		115.2		241.3		227.2
Income Tax Expense (Benefit)		(17.8)		6.3		(21)		19
Equity Earnings (Loss) of Unconsolidated Subsidiaries		0.3		1		1		2.5
Net Income (Loss)		139.4		109.9		263.3		210.7
Net Income (Loss) Attributable to Noncontrolling Interests		0		1		3.1		2.6
Earnings Attributable to Common Shareholders		139.4		108.9		260.2		208.1
Earnings Per Share
Cash Flow Hedges, Tax		0		0.1		0		0.3
Amortization of Pension and OPEB Deferred Costs, Tax		(0.1)		(0.1)		(0.3)		(0.3)
Southwestern Electric Power Co [Member] \| Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers		698.8		570.1		1,703.7		1,596.6
Southwestern Electric Power Co [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		0.5		0.5		1.5		1.5
TOTAL REVENUES		0	[8]	0	[9]	0	[10]	0	[11]
Southwestern Electric Power Co [Member] \| Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold		290.9		214.4		669.1		652.7
Mineral Rights
Expenses
Gain on Sale of Mineral Rights						(116.3)		0
Reconciling Adjustments [Member]
Revenues
Revenue from Contracts with Customers		0		0		0		0
Sales to AEP Affiliates		(425)		(376)		(1,190.5)		(1,112.2)
TOTAL REVENUES		(425)		(376)		(1,190.5)		(1,112.2)
Other Income (Expense):
Net Income (Loss)		0		0		0		0
Reconciling Adjustments [Member] \| Other Revenues [Member]
Revenues
TOTAL REVENUES		(2)	[1]	(3)	[2],[3]	(6.9)	[4],[5]	(8.6)	[6],[7]
Reconciling Adjustments [Member] \| AEP Transmission Co [Member]
Revenues
Revenue from Contracts with Customers		0		0		0		0
Sales to AEP Affiliates		0		0		0		0
TOTAL REVENUES		0		0		0		0
Other Income (Expense):
Net Income (Loss)		$ 0		$ 0		$ 0		$ 0

[1]Amounts include affiliated and nonaffiliated revenues.[2]Amounts include affiliated and nonaffiliated revenues[3]Generation & Marketing includes economic hedge activity.[4]Amounts include affiliated and nonaffiliated revenues.[5]Generation & Marketing includes economic hedge activity.[6]Amounts include affiliated and nonaffiliated revenues.[7]Generation & Marketing includes economic hedge activity.[8]Amounts include affiliated and nonaffiliated revenues.[9]Amounts include affiliated and nonaffiliated revenues.[10]Amounts include affiliated and nonaffiliated revenues.[11]Amounts include affiliated and nonaffiliated revenues.[12]Includes the elimination of AEPTCo Parent’s equity earnings in the State Transcos.

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income (Loss) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Net Income (Loss)	$ 683.3	$ 796.9	$ 1,922.2	$ 1,949.5
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	(73.3)	179.7	307.1	365.9
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(3.2)	(2)	(17)	(6.1)
Other Comprehensive Income (Loss), Net of Tax, Total	(76.5)	177.7	290.1	359.8
TOTAL COMPREHENSIVE INCOME (LOSS)	606.8	974.6	2,212.3	2,309.3
Total Comprehensive Income (Loss) Attributable to Noncontrolling Interest	(0.4)	0.9	(0.7)	0.3
TOTAL COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	607.2	973.7	2,213	2,309
Cash Flow Hedges, Tax	(19.5)	47.8	81.6	97.3
Amortization of Pension and OPEB Deferred Costs, Tax	(0.8)	(0.5)	(4.5)	(1.6)
Appalachian Power Co [Member]
Net Income (Loss)	92.7	86.3	303.1	275.1
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	(0.2)	(0.3)	(0.6)	8.5
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(1.1)	(1)	(3.2)	(3.1)
Other Comprehensive Income (Loss), Net of Tax, Total	(1.3)	(1.3)	(3.8)	5.4
TOTAL COMPREHENSIVE INCOME (LOSS)	91.4	85	299.3	280.5
Cash Flow Hedges, Tax	(0.1)	0	(0.2)	2.3
Amortization of Pension and OPEB Deferred Costs, Tax	(0.3)	(0.2)	(0.9)	(0.8)
AEP Texas Inc. [Member]
Net Income (Loss)	93.6	99.5	253.2	225.4
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	0.3	0.3	0.8	0.8
Amortization of Pension and OPEB Deferred Costs, Net of Tax	0	0	0	0.1
Other Comprehensive Income (Loss), Net of Tax, Total	0.3	0.3	0.8	0.9
TOTAL COMPREHENSIVE INCOME (LOSS)	93.9	99.8	254	226.3
Cash Flow Hedges, Tax	0.1	0.1	0.2	0.2
Amortization of Pension and OPEB Deferred Costs, Tax	0	0	0	0
Indiana Michigan Power Co [Member]
Net Income (Loss)	94.1	104.1	250.8	232.1
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	0.4	0.4	1.2	1.3
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(0.1)	0	(0.3)	(0.1)
Other Comprehensive Income (Loss), Net of Tax, Total	0.3	0.4	0.9	1.2
TOTAL COMPREHENSIVE INCOME (LOSS)	94.4	104.5	251.7	233.3
Cash Flow Hedges, Tax	0.1	0.1	0.3	0.3
Amortization of Pension and OPEB Deferred Costs, Tax	(0.1)	0	(0.1)	0
Ohio Power Co [Member]
Net Income (Loss)	71.9	56.4	229.9	198.6
Public Service Co Of Oklahoma [Member]
Net Income (Loss)	106.9	93.2	155.7	136.6
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	0	0	0	(0.1)
TOTAL COMPREHENSIVE INCOME (LOSS)	106.9	93.2	155.7	136.5
Cash Flow Hedges, Tax	0	0	0	0
Southwestern Electric Power Co [Member]
Net Income (Loss)	139.4	109.9	263.3	210.7
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	0	0.3	0	1.1
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(0.4)	(0.4)	(1.2)	(1.2)
Other Comprehensive Income (Loss), Net of Tax, Total	(0.4)	(0.1)	(1.2)	(0.1)
TOTAL COMPREHENSIVE INCOME (LOSS)	139	109.8	262.1	210.6
Total Comprehensive Income (Loss) Attributable to Noncontrolling Interest	0	1	3.1	2.6
TOTAL COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	139	108.8	259	208
Cash Flow Hedges, Tax	0	0.1	0	0.3
Amortization of Pension and OPEB Deferred Costs, Tax	(0.1)	(0.1)	(0.3)	(0.3)
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
OTHER COMPREHENSIVE INCOME
Other Comprehensive Income (Loss), Net of Tax, Total	(3.2)	(2)	(17)	(6.1)
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] \| Appalachian Power Co [Member]
OTHER COMPREHENSIVE INCOME
Other Comprehensive Income (Loss), Net of Tax, Total	(1.1)	(1)	(3.2)	(3.1)
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] \| AEP Texas Inc. [Member]
OTHER COMPREHENSIVE INCOME
Other Comprehensive Income (Loss), Net of Tax, Total	0	0	0	0.1
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] \| Indiana Michigan Power Co [Member]
OTHER COMPREHENSIVE INCOME
Other Comprehensive Income (Loss), Net of Tax, Total	(0.1)	0	(0.3)	(0.1)
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] \| Southwestern Electric Power Co [Member]
OTHER COMPREHENSIVE INCOME
Other Comprehensive Income (Loss), Net of Tax, Total	$ (0.4)	$ (0.4)	$ (1.2)	$ (1.2)

Condensed Consolidated Statemen

Condensed Consolidated Statements of Changes in Equity - USD ($)	Total	Generation And Marketing [Member]	Appalachian Power Co [Member]	AEP Texas Inc. [Member]	AEP Transmission 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] Appalachian Power Co [Member]	Additional Paid-in Capital [Member] AEP Texas Inc. [Member]	Additional Paid-in Capital [Member] AEP Transmission 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] Appalachian Power Co [Member]	Retained Earnings [Member] AEP Texas Inc. [Member]	Retained Earnings [Member] AEP Transmission 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] Appalachian Power Co [Member]	Accumulated Other Comprehensive Income [Member] AEP Texas Inc. [Member]	Accumulated Other Comprehensive Income [Member] Indiana Michigan 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]	Dry Lake Solar Project	Dry Lake Solar Project Noncontrolling Interests [Member]	Dry Lake Solar Project Noncontrolling Interests [Member] Generation And Marketing [Member]
Beginning Balance at Dec. 31, 2020					$ 4,712,900,000														$ 2,765,600,000									$ 1,947,300,000
Beginning Balance at Dec. 31, 2020	$ 20,774,500,000		$ 4,344,300,000	$ 3,206,000,000		$ 2,749,200,000	$ 2,692,700,000	$ 1,545,600,000	$ 2,627,700,000	$ 3,359,300,000	$ 260,400,000	$ 56,600,000	$ 321,200,000	$ 157,200,000	$ 100,000	$ 6,588,900,000	$ 1,828,700,000	$ 1,457,900,000		$ 980,900,000	$ 838,800,000	$ 414,000,000	$ 812,200,000	$ 10,687,800,000		$ 2,248,000,000	$ 1,757,000,000		$ 1,718,700,000	$ 1,532,700,000	$ 974,300,000	$ 1,811,900,000	$ (85,100,000)	$ 7,200,000	$ (8,900,000)	$ (7,000,000)	$ 100,000	$ 1,900,000	$ 223,600,000	$ 1,600,000
Beginning Balance, Shares at Dec. 31, 2020										516,800,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of Common Stock, Value	184,600,000									$ 17,100,000						167,500,000
Issuance of Common Stock, Shares										2,700,000
Common Stock Dividends	(372,000,000)																							(369,500,000)	[1]
Common Stock Dividends			(12,500,000)			(25,000,000)	(21,900,000)																			(12,500,000)			(25,000,000)	(21,900,000)
Common Stock Dividends									(1,000,000)																														(2,500,000)	(1,000,000)
Other Changes in Equity	(19,100,000)															(21,900,000)								(600,000)															3,400,000
Capital Contribution from Member					124,000,000			425,000,000	100,000,000										124,000,000			425,000,000	100,000,000
Acquisition																																									$ 18,900,000	$ 18,900,000
Net Income (Loss)																								575,000,000								62,400,000
Net Income (Loss) Attributable to Noncontrolling Interests																																							3,800,000	1,000,000
Net Income (Loss)	578,800,000		122,500,000	46,100,000	151,700,000	70,800,000	68,200,000	(2,700,000)	63,400,000																	122,500,000	46,100,000	151,700,000	70,800,000	68,200,000	(2,700,000)
Other Comprehensive Income (Loss)	54,300,000		7,900,000	300,000		500,000		(100,000)																									54,300,000	7,900,000	300,000	500,000	(100,000)
Ending Balance at Mar. 31, 2021					4,988,600,000														2,889,600,000									2,099,000,000
Ending Balance at Mar. 31, 2021	21,220,000,000		4,462,200,000	3,252,400,000		2,795,500,000	2,739,000,000	1,967,800,000	2,790,100,000	$ 3,376,400,000	260,400,000	56,600,000	321,200,000	157,200,000	100,000	6,734,500,000	1,828,700,000	1,457,900,000		980,900,000	838,800,000	839,000,000	912,200,000	10,892,700,000		2,358,000,000	1,803,100,000		1,764,500,000	1,579,000,000	971,600,000	1,874,300,000	(30,800,000)	15,100,000	(8,600,000)	(6,500,000)	0	1,900,000	247,200,000	1,600,000
Ending Balance, Shares at Mar. 31, 2021										519,500,000
Beginning Balance at Dec. 31, 2020					4,712,900,000														2,765,600,000									1,947,300,000
Beginning Balance at Dec. 31, 2020	20,774,500,000		4,344,300,000	3,206,000,000		2,749,200,000	2,692,700,000	1,545,600,000	2,627,700,000	$ 3,359,300,000	260,400,000	56,600,000	321,200,000	157,200,000	100,000	6,588,900,000	1,828,700,000	1,457,900,000		980,900,000	838,800,000	414,000,000	812,200,000	10,687,800,000		2,248,000,000	1,757,000,000		1,718,700,000	1,532,700,000	974,300,000	1,811,900,000	(85,100,000)	7,200,000	(8,900,000)	(7,000,000)	100,000	1,900,000	223,600,000	1,600,000
Beginning Balance, Shares at Dec. 31, 2020										516,800,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Dividends Paid on Common Stock			(37,500,000)		(112,500,000)	(175,000,000)	(71,900,000)	(20,000,000)	0
Net Income (Loss)	1,949,200,000								208,100,000
Net Income (Loss) Attributable to Noncontrolling Interests	300,000								2,600,000
Net Income (Loss)	1,949,500,000	$ 184,200,000	275,100,000	225,400,000	445,700,000	232,100,000	198,600,000	136,600,000	210,700,000
Other Comprehensive Income (Loss)	359,800,000		5,400,000	900,000		1,200,000			(100,000)
Ending Balance at Sep. 30, 2021					5,230,100,000														2,949,600,000									2,280,500,000
Ending Balance at Sep. 30, 2021	22,527,200,000		4,587,300,000	3,432,300,000		2,807,500,000	2,819,400,000	2,287,100,000	3,114,500,000	$ 3,404,500,000	260,400,000	56,600,000	321,200,000	157,200,000	100,000	7,075,900,000	1,828,700,000	1,457,900,000		980,900,000	838,800,000	1,039,000,000	1,092,200,000	11,523,000,000		2,485,600,000	1,982,400,000		1,775,800,000	1,659,400,000	1,090,900,000	2,020,000,000	274,700,000	12,600,000	(8,000,000)	(5,800,000)	0	1,800,000	249,100,000	400,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contributions from Parent			0	0	184,000,000	0	0	625,000,000	280,000,000
Ending Balance, Shares at Sep. 30, 2021										523,800,000
Beginning Balance at Mar. 31, 2021					4,988,600,000														2,889,600,000									2,099,000,000
Beginning Balance at Mar. 31, 2021	21,220,000,000		4,462,200,000	3,252,400,000		2,795,500,000	2,739,000,000	1,967,800,000	2,790,100,000	$ 3,376,400,000	260,400,000	56,600,000	321,200,000	157,200,000	100,000	6,734,500,000	1,828,700,000	1,457,900,000		980,900,000	838,800,000	839,000,000	912,200,000	10,892,700,000		2,358,000,000	1,803,100,000		1,764,500,000	1,579,000,000	971,600,000	1,874,300,000	(30,800,000)	15,100,000	(8,600,000)	(6,500,000)	0	1,900,000	247,200,000	1,600,000
Beginning Balance, Shares at Mar. 31, 2021										519,500,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of Common Stock, Value	72,300,000									$ 6,300,000						66,000,000
Issuance of Common Stock, Shares										900,000
Common Stock Dividends	(374,500,000)							(10,000,000)																(371,800,000)	[1]						(10,000,000)
Common Stock Dividends			(12,500,000)			(75,000,000)	(21,900,000)																			(12,500,000)			(75,000,000)	(21,900,000)
Common Stock Dividends									(600,000)																														(2,700,000)	(600,000)
Other Changes in Equity	10,500,000															(200,000)								(400,000)															11,100,000
Capital Contribution from Member					60,000,000			200,000,000	75,000,000										60,000,000			200,000,000	75,000,000
Net Income (Loss)																								578,200,000								36,800,000
Net Income (Loss) Attributable to Noncontrolling Interests																																							(4,400,000)	600,000
Net Income (Loss)	573,800,000		66,300,000	79,800,000	148,600,000	57,200,000	74,000,000	46,100,000	37,400,000																	66,300,000	79,800,000	148,600,000	57,200,000	74,000,000	46,100,000
Other Comprehensive Income (Loss)	127,800,000		(1,200,000)	300,000		300,000																											127,800,000	(1,200,000)	300,000	300,000
Ending Balance at Jun. 30, 2021					5,197,200,000														2,949,600,000									2,247,600,000
Ending Balance at Jun. 30, 2021	$ 21,629,900,000		4,514,800,000	3,332,500,000		2,778,000,000	2,791,100,000	2,203,900,000	2,901,900,000	$ 3,382,700,000	260,400,000	56,600,000	321,200,000	157,200,000	100,000	6,800,300,000	1,828,700,000	1,457,900,000		980,900,000	838,800,000	1,039,000,000	987,200,000	11,098,700,000		2,411,800,000	1,882,900,000		1,746,700,000	1,631,100,000	1,007,700,000	1,911,100,000	97,000,000	13,900,000	(8,300,000)	(6,200,000)	0	1,900,000	251,200,000	1,600,000
Ending Balance, Shares at Jun. 30, 2021										520,400,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Dividends Per Share, Declared	$ 0.74
Issuance of Common Stock, Value	$ 291,100,000									$ 21,800,000						269,300,000
Issuance of Common Stock, Shares										3,400,000
Common Stock Dividends	(376,200,000)							(10,000,000)																(371,700,000)	[1]						(10,000,000)
Common Stock Dividends			(12,500,000)			(75,000,000)	(28,100,000)																			(12,500,000)			(75,000,000)	(28,100,000)
Common Stock Dividends									(2,200,000)																														(4,500,000)	(2,200,000)
Other Changes in Equity	7,800,000															6,300,000																							1,500,000
Capital Contribution from Member									105,000,000														105,000,000
Dividends Paid on Common Stock					(112,500,000)																							(112,500,000)
Net Income (Loss)	796,000,000								108,900,000															796,000,000								108,900,000
Net Income (Loss) Attributable to Noncontrolling Interests	900,000								1,000,000																														900,000	1,000,000
Net Income (Loss)	796,900,000	99,500,000	86,300,000	99,500,000	145,400,000	104,100,000	56,400,000	93,200,000	109,900,000																	86,300,000	99,500,000	145,400,000	104,100,000	56,400,000	93,200,000
Other Comprehensive Income (Loss)	177,700,000		(1,300,000)	300,000		400,000			(100,000)																								177,700,000	(1,300,000)	300,000	400,000		(100,000)
Ending Balance at Sep. 30, 2021					5,230,100,000														2,949,600,000									2,280,500,000
Ending Balance at Sep. 30, 2021	$ 22,527,200,000		4,587,300,000	3,432,300,000		2,807,500,000	2,819,400,000	2,287,100,000	3,114,500,000	$ 3,404,500,000	260,400,000	56,600,000	321,200,000	157,200,000	100,000	7,075,900,000	1,828,700,000	1,457,900,000		980,900,000	838,800,000	1,039,000,000	1,092,200,000	11,523,000,000		2,485,600,000	1,982,400,000		1,775,800,000	1,659,400,000	1,090,900,000	2,020,000,000	274,700,000	12,600,000	(8,000,000)	(5,800,000)	0	1,800,000	249,100,000	400,000
Ending Balance, Shares at Sep. 30, 2021										523,800,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Dividends Per Share, Declared	$ 0.74
Beginning Balance at Dec. 31, 2021					5,376,100,000														2,949,600,000									2,426,500,000
Beginning Balance at Dec. 31, 2021	$ 22,680,200,000		4,647,900,000	3,594,200,000		2,784,700,000	2,846,300,000	$ 2,291,600,000	3,149,800,000	$ 3,408,700,000	260,400,000	56,600,000	321,200,000	157,200,000	100,000	7,172,600,000	1,828,700,000	1,553,900,000		980,900,000	838,800,000	1,039,000,000	1,092,200,000	11,667,100,000		2,534,400,000	2,046,800,000		1,748,500,000	1,686,300,000	1,095,400,000	2,050,900,000	184,800,000	24,400,000	(6,500,000)	(1,300,000)	0	6,700,000	247,000,000	(100,000)
Beginning Balance, Shares at Dec. 31, 2021	524,416,175							10,482,000		524,400,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of Common Stock, Value	$ 809,500,000									$ 2,400,000						807,100,000
Issuance of Common Stock, Shares										400,000
Common Stock Dividends	(398,800,000)																							(395,200,000)	[2]
Common Stock Dividends			(18,800,000)			(25,000,000)	(15,000,000)																			(18,800,000)			(25,000,000)	(15,000,000)
Common Stock Dividends									(800,000)																														(3,600,000)	(800,000)
Other Changes in Equity	(16,700,000)															(15,200,000)								(1,500,000)
Capital Contribution from Member									350,000,000														350,000,000
Dividends Paid on Common Stock					(40,000,000)																							(40,000,000)
Net Income (Loss)																								714,700,000								44,100,000
Net Income (Loss) Attributable to Noncontrolling Interests																																							3,400,000	1,000,000
Net Income (Loss)	718,100,000		120,200,000	69,600,000	155,400,000	89,500,000	83,200,000	$ 5,800,000	45,100,000																	120,200,000	69,600,000	155,400,000	89,500,000	83,200,000	5,800,000
Other Comprehensive Income (Loss)	245,800,000		(1,300,000)	300,000		300,000			(300,000)																								245,800,000	(1,300,000)	300,000	300,000		(300,000)
Ending Balance at Mar. 31, 2022					5,491,500,000														2,949,600,000									2,541,900,000
Ending Balance at Mar. 31, 2022	24,038,100,000		4,748,000,000	3,664,100,000		2,849,500,000	2,914,500,000	2,297,400,000	3,543,800,000	$ 3,411,100,000	260,400,000	56,600,000	321,200,000	157,200,000	100,000	7,964,500,000	1,828,700,000	1,553,900,000		980,900,000	838,800,000	1,039,000,000	1,442,200,000	11,985,100,000		2,635,800,000	2,116,400,000		1,813,000,000	1,754,500,000	1,101,200,000	2,095,000,000	430,600,000	23,100,000	(6,200,000)	(1,000,000)	0	6,400,000	246,800,000	100,000
Ending Balance, Shares at Mar. 31, 2022										524,800,000
Beginning Balance at Dec. 31, 2021					5,376,100,000														2,949,600,000									2,426,500,000
Beginning Balance at Dec. 31, 2021	$ 22,680,200,000		4,647,900,000	3,594,200,000		2,784,700,000	2,846,300,000	$ 2,291,600,000	3,149,800,000	$ 3,408,700,000	260,400,000	56,600,000	321,200,000	157,200,000	100,000	7,172,600,000	1,828,700,000	1,553,900,000		980,900,000	838,800,000	1,039,000,000	1,092,200,000	11,667,100,000		2,534,400,000	2,046,800,000		1,748,500,000	1,686,300,000	1,095,400,000	2,050,900,000	184,800,000	24,400,000	(6,500,000)	(1,300,000)	0	6,700,000	247,000,000	(100,000)
Beginning Balance, Shares at Dec. 31, 2021	524,416,175							10,482,000		524,400,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Acquisition																																											$ 16,000,000
Dividends Paid on Common Stock			(37,500,000)		(130,000,000)	(70,000,000)	(45,000,000)	$ (20,000,000)	(57,500,000)
Net Income (Loss)	$ 1,922,900,000								260,200,000
Net Income (Loss) Attributable to Noncontrolling Interests	(700,000)								3,100,000
Net Income (Loss)	1,922,200,000	278,100,000	303,100,000	253,200,000	426,600,000	250,800,000	229,900,000	155,700,000	263,300,000
Other Comprehensive Income (Loss)	290,100,000		(3,800,000)	800,000		900,000			(1,200,000)
Ending Balance at Sep. 30, 2022					5,736,900,000														3,013,800,000									2,723,100,000
Ending Balance at Sep. 30, 2022	$ 24,512,300,000		4,914,000,000	3,850,000,000		2,968,300,000	3,032,200,000	2,430,600,000	3,705,100,000	$ 3,412,500,000	260,400,000	56,600,000	321,200,000	157,200,000	100,000	8,001,000,000	1,833,000,000	1,555,700,000		982,800,000	839,800,000	1,042,300,000	1,445,500,000	12,389,800,000		2,800,000,000	2,300,000,000		1,929,300,000	1,871,200,000	1,231,100,000	2,253,600,000	474,900,000	20,600,000	(5,700,000)	(400,000)	0	5,500,000	234,100,000	400,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contributions from Parent			4,300,000	1,800,000	64,200,000	1,900,000	1,000,000	$ 3,300,000	353,300,000
Ending Balance, Shares at Sep. 30, 2022	525,005,433							10,482,000		525,000,000
Beginning Balance at Mar. 31, 2022					5,491,500,000														2,949,600,000									2,541,900,000
Beginning Balance at Mar. 31, 2022	$ 24,038,100,000		4,748,000,000	3,664,100,000		2,849,500,000	2,914,500,000	$ 2,297,400,000	3,543,800,000	$ 3,411,100,000	260,400,000	56,600,000	321,200,000	157,200,000	100,000	7,964,500,000	1,828,700,000	1,553,900,000		980,900,000	838,800,000	1,039,000,000	1,442,200,000	11,985,100,000		2,635,800,000	2,116,400,000		1,813,000,000	1,754,500,000	1,101,200,000	2,095,000,000	430,600,000	23,100,000	(6,200,000)	(1,000,000)	0	6,400,000	246,800,000	100,000
Beginning Balance, Shares at Mar. 31, 2022										524,800,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of Common Stock, Value	3,200,000									$ 900,000						2,300,000
Issuance of Common Stock, Shares										100,000
Common Stock Dividends	(404,700,000)																							(402,600,000)	[2]
Common Stock Dividends			(18,700,000)			(25,000,000)	(15,000,000)		(12,500,000)																	(18,700,000)			(25,000,000)	(15,000,000)		(12,500,000)
Common Stock Dividends									(700,000)																														(2,100,000)	(700,000)
Other Changes in Equity	18,800,000															17,200,000								1,600,000
Capital Contribution from Member				1,300,000	2,800,000	1,300,000	700,000	2,200,000	2,200,000									1,300,000	2,800,000	1,300,000	700,000	2,200,000	2,200,000
Dividends Paid on Common Stock					(50,000,000)																							(50,000,000)
Net Income (Loss)																								524,500,000								76,700,000
Net Income (Loss) Attributable to Noncontrolling Interests																																							(3,700,000)	2,100,000
Net Income (Loss)	520,800,000		90,200,000	90,000,000	118,500,000	67,200,000	74,800,000	43,000,000	78,800,000																	90,200,000	90,000,000	118,500,000	67,200,000	74,800,000	43,000,000
Other Comprehensive Income (Loss)	120,800,000		(1,200,000)	200,000		300,000			(500,000)																								120,800,000	(1,200,000)	200,000	300,000		(500,000)
Ending Balance at Jun. 30, 2022					5,562,800,000														2,952,400,000									2,610,400,000
Ending Balance at Jun. 30, 2022	$ 24,297,000,000		4,821,100,000	3,755,600,000		2,893,300,000	2,975,000,000	2,342,600,000	3,611,100,000	$ 3,412,000,000	260,400,000	56,600,000	321,200,000	157,200,000	100,000	7,984,000,000	1,831,500,000	1,555,200,000		982,200,000	839,500,000	1,041,200,000	1,444,400,000	12,108,600,000		2,707,300,000	2,206,400,000		1,855,200,000	1,814,300,000	1,144,200,000	2,159,200,000	551,400,000	21,900,000	(6,000,000)	(700,000)	0	5,900,000	241,000,000	1,500,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contributions from Parent			2,800,000														2,800,000
Ending Balance, Shares at Jun. 30, 2022										524,900,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Dividends Per Share, Declared	$ 0.78
Issuance of Common Stock, Value	$ 14,500,000									$ 500,000						14,000,000
Issuance of Common Stock, Shares										100,000
Common Stock Dividends	(409,000,000)																							(402,500,000)
Common Stock Dividends						(20,000,000)	(15,000,000)	(20,000,000)	(45,000,000)																				(20,000,000)	(15,000,000)	(20,000,000)	(45,000,000)
Common Stock Dividends									(1,100,000)																														(6,500,000)	(1,100,000)
Other Changes in Equity	3,000,000															3,000,000
Capital Contribution from Member				500,000	61,400,000	600,000	300,000	1,100,000	1,100,000									500,000	61,400,000	600,000	300,000	1,100,000	1,100,000
Dividends Paid on Common Stock					(40,000,000)																							(40,000,000)
Net Income (Loss)	683,700,000								139,400,000															683,700,000								139,400,000
Net Income (Loss) Attributable to Noncontrolling Interests	(400,000)								0																														(400,000)	0
Net Income (Loss)	683,300,000	$ 96,200,000	92,700,000	93,600,000	152,700,000	94,100,000	71,900,000	106,900,000	139,400,000																	92,700,000	93,600,000	152,700,000	94,100,000	71,900,000	106,900,000
Other Comprehensive Income (Loss)	(76,500,000)		(1,300,000)	300,000		300,000			(400,000)																								(76,500,000)	(1,300,000)	300,000	300,000		(400,000)
Ending Balance at Sep. 30, 2022					$ 5,736,900,000														$ 3,013,800,000									$ 2,723,100,000
Ending Balance at Sep. 30, 2022	$ 24,512,300,000		4,914,000,000	$ 3,850,000,000		$ 2,968,300,000	$ 3,032,200,000	$ 2,430,600,000	$ 3,705,100,000	$ 3,412,500,000	$ 260,400,000	$ 56,600,000	$ 321,200,000	$ 157,200,000	$ 100,000	$ 8,001,000,000	1,833,000,000	$ 1,555,700,000		$ 982,800,000	$ 839,800,000	$ 1,042,300,000	$ 1,445,500,000	$ 12,389,800,000		$ 2,800,000,000	$ 2,300,000,000		$ 1,929,300,000	$ 1,871,200,000	$ 1,231,100,000	$ 2,253,600,000	$ 474,900,000	$ 20,600,000	$ (5,700,000)	$ (400,000)	$ 0	$ 5,500,000	$ 234,100,000	$ 400,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contributions from Parent			$ 1,500,000														$ 1,500,000
Ending Balance, Shares at Sep. 30, 2022	525,005,433							10,482,000		525,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Dividends Per Share, Declared	$ 0.78

[1]Cash dividends declared per AEP common share were $0.74.[2]Cash dividends declared per AEP common share were $0.78.

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Millions		Sep. 30, 2022	Dec. 31, 2021
Current Assets
Cash and Cash Equivalents		$ 522.2	$ 403.4
Restricted Cash		55.1	48
Other Temporary Investments		202.2	220.4
Accounts Receivable:
Customers		885.6	720.9
Accrued Unbilled Revenues		272.2	204.4
Pledged Accounts Receivable - AEP Credit		1,211.9	1,038
Miscellaneous		84.8	33.9
Allowance for Uncollectible Accounts		(53.2)	(55.6)
Total Accounts Receivable		2,401.3	1,941.6
Fuel		332.1	307.9
Materials and Supplies		801.9	681.3
Risk Management Assets		570.2	194.4
Accrued Tax Benefits		150.8	121.5
Assets Held for Sale		2,830.6	2,919.7
Regulatory Asset for Under-Recovered Fuel Costs		1,137.1	647.8
Prepayments and Other Current Assets		316.5	323.2
TOTAL CURRENT ASSETS		9,320	7,809.2
Property, Plant and Equipment
Generation		24,590.7	23,088.1
Transmission		31,271.5	29,911.1
Distribution		25,566.1	24,440
Other Property, Plant and Equipment		6,080.8	5,682.9
Construction Work in Progress		4,596	3,684.3
Total Property, Plant and Equipment		92,105.1	86,806.4
Accumulated Depreciation and Amortization		22,292	20,805.1
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		69,813.1	66,001.3
Other Noncurrent Assets
Regulatory Assets		3,877.5	4,142.3
Securitized Assets		474.3	552.8
Spent Nuclear Fuel and Decommissioning Trusts		3,130.5	3,867
Goodwill		52.5	52.5
Long-term Risk Management Assets		265.8	267
Operating Lease Assets		620	578.3
Deferred Charges and Other Noncurrent Assets		3,695.7	4,398.3
TOTAL OTHER NONCURRENT ASSETS		12,116.3	13,858.2
TOTAL ASSETS	[1]	91,249.4	87,668.7
Current Liabilities
Accounts Payable		2,240.2	2,054.6
Short-term Debt:
Securitized Debt for Receivables - AEP Credit	[2]	750	750
Other Short-term Debt		1,952.3	1,864
Total Short-term Debt		2,702.3	2,614
Long-term Debt Due Within One Year	[3]	1,403.5	2,153.8
Risk Management Liabilities		187.3	75.4
Customer Deposits		375.5	321.6
Accrued Taxes		1,116.9	1,586.4
Accrued Interest		375.4	273.2
Obligations Under Operating Leases		91.7	97.6
Liabilities Held for Sale		1,992	1,880.9
Other Current Liabilities		1,351.6	1,369.2
TOTAL CURRENT LIABILITIES		11,836.4	12,426.7
Noncurrent Liabilities
Long-term Debt	[4]	33,646.6	31,300.7
Deferred Income Tax Liabilities, Net		8,544.8	8,202.5
Long-term Risk Management Liabilities		388.2	230.3
Regulatory Liabilities and Deferred Investment Tax Credits		7,934.1	8,686.3
Asset Retirement Obligations		2,855.1	2,676.2
Employee Benefits and Pension Obligations		279.9	328.4
Obligations Under Operating Leases		540	492.8
Deferred Credits and Other Noncurrent Liabilities		638.7	601.3
TOTAL NONCURRENT LIABILITIES		54,827.4	52,518.5
TOTAL LIABILITIES		66,663.8	64,945.2
Rate Matters
Commitments and Contingencies
Contingently Reedemable Performance Share Awards		73.3	43.3
Total Mezzanine Equity		73.3	43.3
Equity
Common Stock		3,412.5	3,408.7
Paid-in Capital		8,001	7,172.6
Retained Earnings		12,389.8	11,667.1
Accumulated Other Comprehensive Income (Loss)		474.9	184.8
TOTAL COMMON SHAREHOLDER'S EQUITY		24,278.2	22,433.2
Noncontrolling Interests		234.1	247
TOTAL EQUITY		24,512.3	22,680.2
TOTAL LIABILITIES AND EQUITY		$ 91,249.4	$ 87,668.7
Common Stock, No Par Value		$ 6.50	$ 6.50
Common Stock, Shares Authorized		600,000,000	600,000,000
Common Stock, Shares, Issued		525,005,433	524,416,175
Treasury Stock, Shares		11,233,240	20,204,160
Commodity [Member]
Equity
Cross Default Provisions Maximum Third Party Obligation Amount		$ 50
Subsidiaries [Member]
Current Assets
Restricted Cash		55.1	$ 48
Other Temporary Investments		188.4	214.8
Short-term Debt:
Long-term Debt Due Within One Year		196.4	190.5
Noncurrent Liabilities
Long-term Debt		764	840.5
AEP Texas Inc. [Member]
Current Assets
Cash and Cash Equivalents		0.1	0.1
Restricted Cash		47.7	30.4
Advances to Affiliates		136.3	6.9
Accounts Receivable:
Customers		166	123.4
Affiliated Companies - Contracts with Customers		5.9	7.9
Accrued Unbilled Revenues		94.7	77.9
Miscellaneous		0.2	0
Allowance for Uncollectible Accounts		(4.1)	(4)
Total Accounts Receivable		262.7	205.2
Materials and Supplies		113.8	73.9
Risk Management Assets		0.2	0
Accrued Tax Benefits		21.7	24.8
Prepayments and Other Current Assets		6.5	5.9
TOTAL CURRENT ASSETS		589	347.2
Property, Plant and Equipment
Transmission		6,154.4	5,849.9
Distribution		5,192.3	4,917.2
Other Property, Plant and Equipment		1,013.6	961.1
Construction Work in Progress		697.7	551.3
Total Property, Plant and Equipment		13,058	12,279.5
Accumulated Depreciation and Amortization		1,746.3	1,644.1
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		11,311.7	10,635.4
Other Noncurrent Assets
Regulatory Assets		243.9	275.2
Securitized Assets		308.3	367.6
Long-term Risk Management Assets		0.1	0
Deferred Charges and Other Noncurrent Assets		237	211.3
TOTAL OTHER NONCURRENT ASSETS		789.3	854.1
TOTAL ASSETS		12,690	11,836.7
Current Liabilities
Advances from Affiliates		0	26.9
Accounts Payable		249.2	306.3
Affiliated Companies		32.6	32.5
Short-term Debt:
Long-term Debt Due Within One Year		277.5	716
Accrued Taxes		129.6	93.3
Accrued Interest		72.3	44.7
Obligations Under Operating Leases		14	14
Other Current Liabilities		110.5	78
TOTAL CURRENT LIABILITIES		885.7	1,311.7
Noncurrent Liabilities
Long-term Debt		5,416.4	4,464.8
Deferred Income Tax Liabilities, Net		1,132.2	1,088.9
Long-term Risk Management Liabilities		0.1	0
Regulatory Liabilities and Deferred Investment Tax Credits		1,258.3	1,242
Obligations Under Operating Leases		54.3	61.3
Deferred Credits and Other Noncurrent Liabilities		93	73.8
TOTAL NONCURRENT LIABILITIES		7,954.3	6,930.8
TOTAL LIABILITIES		8,840	8,242.5
Rate Matters
Commitments and Contingencies
Equity
Paid-in Capital		1,555.7	1,553.9
Retained Earnings		2,300	2,046.8
Accumulated Other Comprehensive Income (Loss)		(5.7)	(6.5)
TOTAL EQUITY		3,850	3,594.2
TOTAL LIABILITIES AND EQUITY		12,690	11,836.7
AEP Texas Inc. [Member] \| AEP Texas Transition Funding and Restoration Funding [Member]
Current Assets
Restricted Cash		47.7	30.4
Other Noncurrent Assets
Securitized Assets		308.3	367.6
Short-term Debt:
Long-term Debt Due Within One Year		92.5	91
Accrued Interest		2.5	2.3
Noncurrent Liabilities
Long-term Debt		259.2	313.7
AEP Transmission Co [Member]
Current Assets
Cash and Cash Equivalents		0	0
Advances to Affiliates		106.7	27.2
Accounts Receivable:
Customers		73.8	22.5
Affiliated Companies - Contracts with Customers		111	96.1
Total Accounts Receivable		184.8	118.6
Materials and Supplies		11.7	9.3
Accrued Tax Benefits		12.3	5.6
Assets Held for Sale		173.7	167.9
Prepayments and Other Current Assets		3.8	2.7
TOTAL CURRENT ASSETS		493	331.3
Property, Plant and Equipment
Transmission		11,609.8	10,886.3
Other Property, Plant and Equipment		440.6	427.4
Construction Work in Progress		1,644.6	1,394.8
Total Property, Plant and Equipment		13,695	12,708.5
Accumulated Depreciation and Amortization		952.4	772.8
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		12,742.6	11,935.7
Other Noncurrent Assets
Regulatory Assets		2.6	8.5
Deferred Property Taxes		75.7	245.7
Deferred Charges and Other Noncurrent Assets		5.3	3.2
TOTAL OTHER NONCURRENT ASSETS		83.6	257.4
TOTAL ASSETS	[5]	13,319.2	12,524.4
Current Liabilities
Advances from Affiliates		61	124
Accounts Payable		332.1	460.1
Affiliated Companies		121.5	69.9
Short-term Debt:
Long-term Debt Due Within One Year		104	104
Accrued Taxes		293	479
Accrued Interest		56	28.4
Obligations Under Operating Leases		1.3	0.9
Liabilities Held for Sale		27.6	27.6
Other Current Liabilities		14.8	3
TOTAL CURRENT LIABILITIES		1,011.3	1,296.9
Noncurrent Liabilities
Long-term Debt		4,782.6	4,239.9
Deferred Income Tax Liabilities, Net		1,032.8	962.9
Regulatory Liabilities and Deferred Investment Tax Credits		698.2	644.1
Obligations Under Operating Leases		1.8	1.3
Deferred Credits and Other Noncurrent Liabilities		55.6	3.2
TOTAL NONCURRENT LIABILITIES		6,571	5,851.4
TOTAL LIABILITIES		7,582.3	7,148.3
Rate Matters
Commitments and Contingencies
Equity
Paid-in Captial		3,013.8	2,949.6
Retained Earnings		2,723.1	2,426.5
TOTAL MEMBER'S EQUITY		5,736.9	5,376.1
TOTAL LIABILITIES AND EQUITY		13,319.2	12,524.4
Appalachian Power Co [Member]
Current Assets
Cash and Cash Equivalents		6.7	2.5
Restricted Cash		7.4	17.6
Advances to Affiliates		182.1	20.8
Accounts Receivable:
Customers		133.7	158.5
Affiliated Companies - Contracts with Customers		92.6	129.9
Accrued Unbilled Revenues		49.6	54
Miscellaneous		0.3	0.2
Allowance for Uncollectible Accounts		(1.5)	(1.6)
Total Accounts Receivable		274.7	341
Fuel		118.6	67.1
Materials and Supplies		120.4	109.8
Risk Management Assets		106.8	42
Accrued Tax Benefits		106.7	38.1
Regulatory Asset for Under-Recovered Fuel Costs		404	201.3
Margin Deposits		6.1	71.8
Prepayments and Other Current Assets		17.5	13.3
TOTAL CURRENT ASSETS		1,351	925.3
Property, Plant and Equipment
Generation		6,731	6,683.9
Transmission		4,445.2	4,322.4
Distribution		4,849.1	4,683.3
Other Property, Plant and Equipment		853.3	696.6
Construction Work in Progress		617.7	469.9
Total Property, Plant and Equipment		17,496.3	16,856.1
Accumulated Depreciation and Amortization		5,332.7	5,051.8
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		12,163.6	11,804.3
Other Noncurrent Assets
Regulatory Assets		970.3	757.6
Securitized Assets		165.9	185.1
Employee Benefits and Pension Assets		231.6	220.5
Operating Lease Assets		61.2	66.9
Deferred Charges and Other Noncurrent Assets		99.4	129.2
TOTAL OTHER NONCURRENT ASSETS		1,528.4	1,359.3
TOTAL ASSETS		15,043	14,088.9
Current Liabilities
Advances from Affiliates		0	199.3
Accounts Payable		374.6	262.2
Affiliated Companies		168.2	118.6
Short-term Debt:
Long-term Debt Due Within One Year		351.8	480.7
Customer Deposits		76.8	73.9
Accrued Taxes		89.4	119.7
Accrued Interest		84.1	47.9
Obligations Under Operating Leases		14.4	15.1
Other Current Liabilities		116.8	98.5
TOTAL CURRENT LIABILITIES		1,276.1	1,415.9
Noncurrent Liabilities
Long-term Debt		5,158	4,458.2
Deferred Income Tax Liabilities, Net		1,937	1,804.7
Regulatory Liabilities and Deferred Investment Tax Credits		1,218.4	1,238.8
Asset Retirement Obligations		418.8	394.9
Employee Benefits and Pension Obligations		40.2	41.5
Obligations Under Operating Leases		47.3	52.4
Deferred Credits and Other Noncurrent Liabilities		33.2	34.6
TOTAL NONCURRENT LIABILITIES		8,852.9	8,025.1
TOTAL LIABILITIES		10,129	9,441
Rate Matters
Commitments and Contingencies
Equity
Common Stock		260.4	260.4
Paid-in Capital		1,833	1,828.7
Retained Earnings		2,800	2,534.4
Accumulated Other Comprehensive Income (Loss)		20.6	24.4
TOTAL EQUITY		4,914	4,647.9
TOTAL LIABILITIES AND EQUITY		$ 15,043	$ 14,088.9
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		$ 25.8	$ 1.3
Advances to Affiliates		22.6	21.5
Accounts Receivable:
Customers		40.8	40.6
Affiliated Companies - Contracts with Customers		72.7	78.2
Accrued Unbilled Revenues		0.4	0
Miscellaneous		3.4	2.5
Allowance for Uncollectible Accounts		0	(0.1)
Total Accounts Receivable		117.3	121.2
Fuel		49.5	56.8
Materials and Supplies		179.4	175.2
Regulatory Asset for Under-Recovered Fuel Costs		25.4	6.4
Prepayments and Other Current Assets		50	57
TOTAL CURRENT ASSETS		470	439.4
Property, Plant and Equipment
Generation		5,601.6	5,531.8
Transmission		1,823.9	1,783.1
Distribution		2,955.9	2,800.1
Other Property, Plant and Equipment		854.6	792.9
Construction Work in Progress		314.7	302.8
Total Property, Plant and Equipment		11,550.7	11,210.7
Accumulated Depreciation and Amortization		4,161.3	3,899.8
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		7,389.4	7,310.9
Other Noncurrent Assets
Regulatory Assets		422.5	410.9
Spent Nuclear Fuel and Decommissioning Trusts		3,130.5	3,867
Operating Lease Assets		51.9	63.5
Deferred Charges and Other Noncurrent Assets		278.5	316.5
TOTAL OTHER NONCURRENT ASSETS		3,883.4	4,657.9
TOTAL ASSETS		11,742.8	12,408.2
Current Liabilities
Advances from Affiliates		104.9	93.3
Accounts Payable		187.3	174.4
Affiliated Companies		94	94.9
Short-term Debt:
Long-term Debt Due Within One Year		320.9	67
Customer Deposits		43	45.2
Accrued Taxes		76.9	106.5
Accrued Interest		24.5	37
Finance Lease, Liability, Current		94.1	130.5
Obligations Under Operating Leases		11.3	15.5
Regulatory Liability for Over-Recovered Fuel Costs		0	1.5
Other Current Liabilities		92.5	128.2
TOTAL CURRENT LIABILITIES		1,049.4	894
Noncurrent Liabilities
Long-term Debt		2,885.8	3,128
Deferred Income Tax Liabilities, Net		1,143.6	1,100.2
Regulatory Liabilities and Deferred Investment Tax Credits		1,577	2,447.9
Asset Retirement Obligations		2,009.8	1,946.2
Obligations Under Operating Leases		41.6	48.9
Deferred Credits and Other Noncurrent Liabilities		67.3	58.3
TOTAL NONCURRENT LIABILITIES		7,725.1	8,729.5
TOTAL LIABILITIES		8,774.5	9,623.5
Rate Matters
Commitments and Contingencies
Equity
Common Stock		56.6	56.6
Paid-in Capital		982.8	980.9
Retained Earnings		1,929.3	1,748.5
Accumulated Other Comprehensive Income (Loss)		(0.4)	(1.3)
TOTAL EQUITY		2,968.3	2,784.7
TOTAL LIABILITIES AND EQUITY		$ 11,742.8	$ 12,408.2
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		$ 68.8	$ 65
Ohio Power Co [Member]
Current Assets
Cash and Cash Equivalents		10.2	3
Advances to Affiliates		0	42
Accounts Receivable:
Customers		60.3	71.6
Affiliated Companies - Contracts with Customers		105.9	71.8
Accrued Unbilled Revenues		14.4	1.3
Miscellaneous		0.2	5.9
Allowance for Uncollectible Accounts		(0.1)	(0.6)
Total Accounts Receivable		180.7	150
Materials and Supplies		97.8	74.1
Renewable Energy Credits		33.6	30.5
Prepayments and Other Current Assets		27.2	27.9
TOTAL CURRENT ASSETS		349.5	327.5
Property, Plant and Equipment
Transmission		3,070.4	2,992.8
Distribution		6,336.9	6,070.6
Other Property, Plant and Equipment		1,038.7	992.9
Construction Work in Progress		491.6	365
Total Property, Plant and Equipment		10,937.6	10,421.3
Accumulated Depreciation and Amortization		2,541.6	2,458.3
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		8,396	7,963
Other Noncurrent Assets
Regulatory Assets		270.8	293
Operating Lease Assets		74.4	81.2
Deferred Charges and Other Noncurrent Assets		334.4	601.1
TOTAL OTHER NONCURRENT ASSETS		679.6	975.3
TOTAL ASSETS		9,425.1	9,265.8
Current Liabilities
Advances from Affiliates		68.8	0
Accounts Payable		314.9	213.5
Affiliated Companies		126.6	125.4
Short-term Debt:
Long-term Debt Due Within One Year		0.1	0.1
Risk Management Liabilities		0	6.7
Customer Deposits		103.8	66.4
Accrued Taxes		367	702.4
Obligations Under Operating Leases		13.5	13.1
Other Current Liabilities		159.5	118.1
TOTAL CURRENT LIABILITIES		1,154.2	1,245.7
Noncurrent Liabilities
Long-term Debt		2,969.8	2,968.4
Deferred Income Tax Liabilities, Net		1,053.2	1,000.9
Long-term Risk Management Liabilities		45.1	85.8
Regulatory Liabilities and Deferred Investment Tax Credits		1,049.3	1,020.9
Obligations Under Operating Leases		60.6	68.6
Deferred Credits and Other Noncurrent Liabilities		60.7	29.2
TOTAL NONCURRENT LIABILITIES		5,238.7	5,173.8
TOTAL LIABILITIES		6,392.9	6,419.5
Rate Matters
Commitments and Contingencies
Equity
Common Stock		321.2	321.2
Paid-in Capital		839.8	838.8
Retained Earnings		1,871.2	1,686.3
TOTAL EQUITY		3,032.2	2,846.3
TOTAL LIABILITIES AND EQUITY		$ 9,425.1	$ 9,265.8
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		$ 5.5	$ 1.3
Accounts Receivable:
Customers		44.2	41.5
Affiliated Companies - Contracts with Customers		93.5	35
Miscellaneous		5.7	0.6
Total Accounts Receivable		143.4	77.1
Fuel		8.4	14.5
Materials and Supplies		89	56.2
Risk Management Assets		44.5	12.1
Accrued Tax Benefits		66.4	17.6
Regulatory Asset for Under-Recovered Fuel Costs		178.7	194.6
Prepayments and Other Current Assets		32.8	13.4
TOTAL CURRENT ASSETS		568.7	386.8
Property, Plant and Equipment
Generation		2,386	1,802.4
Transmission		1,131.2	1,107.7
Distribution		3,137.3	3,004.9
Other Property, Plant and Equipment		464.8	437
Construction Work in Progress		225.4	156
Total Property, Plant and Equipment		7,344.7	6,508
Accumulated Depreciation and Amortization		1,810.5	1,705.2
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		5,534.2	4,802.8
Other Noncurrent Assets
Regulatory Assets		606.2	1,037.4
Employee Benefits and Pension Assets		97.7	95.2
Operating Lease Assets		107.3	68.9
Deferred Charges and Other Noncurrent Assets		23	7.9
TOTAL OTHER NONCURRENT ASSETS		834.2	1,209.4
TOTAL ASSETS		6,937.1	6,399
Current Liabilities
Advances from Affiliates		223.5	72.3
Accounts Payable		249	157.4
Affiliated Companies		105	51
Short-term Debt:
Long-term Debt Due Within One Year		0.5	125.5
Risk Management Liabilities		0	3.7
Customer Deposits		60.5	56.2
Accrued Taxes		54.9	27
Obligations Under Operating Leases		8.4	6.9
Other Current Liabilities		75	62.7
TOTAL CURRENT LIABILITIES		776.8	562.7
Noncurrent Liabilities
Long-term Debt		1,913.1	1,788
Deferred Income Tax Liabilities, Net		794.9	782.3
Regulatory Liabilities and Deferred Investment Tax Credits		827.9	835.3
Asset Retirement Obligations		74.6	57.5
Obligations Under Operating Leases		100.3	62.2
Deferred Credits and Other Noncurrent Liabilities		18.9	19.4
TOTAL NONCURRENT LIABILITIES		3,729.7	3,544.7
TOTAL LIABILITIES		4,506.5	4,107.4
Rate Matters
Commitments and Contingencies
Equity
Common Stock		157.2	157.2
Paid-in Capital		1,042.3	1,039
Retained Earnings		1,231.1	1,095.4
TOTAL EQUITY		2,430.6	2,291.6
TOTAL LIABILITIES AND EQUITY		$ 6,937.1	$ 6,399
Common Stock, Shares Authorized		11,000,000	11,000,000
Common Stock, Shares, Outstanding		9,013,000	9,013,000
Common Stock, Par or Stated Value Per Share		$ 15	$ 15
Common Stock, Shares, Issued		10,482,000	10,482,000
Southwestern Electric Power Co [Member]
Current Assets
Cash and Cash Equivalents		$ 84.4	$ 51.2
Advances to Affiliates		2.1	155.9
Accounts Receivable:
Customers		31.9	35.8
Affiliated Companies - Contracts with Customers		53.8	38.3
Miscellaneous		18.6	12.3
Total Accounts Receivable		104.3	86.4
Fuel		55.3	82.2
Materials and Supplies		85.3	81.9
Risk Management Assets		36.4	9.8
Accrued Tax Benefits		88.4	17.8
Regulatory Asset for Under-Recovered Fuel Costs		333.8	143.9
Prepayments and Other Current Assets		50	39.4
TOTAL CURRENT ASSETS		840	668.5
Property, Plant and Equipment
Generation		5,454.6	4,734.5
Transmission		2,380.3	2,316.9
Distribution		2,622.5	2,514.3
Other Property, Plant and Equipment		801.4	764
Construction Work in Progress		345.3	240.7
Total Property, Plant and Equipment		11,604.1	10,570.4
Accumulated Depreciation and Amortization		3,444.2	3,170.3
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		8,159.9	7,400.1
Other Noncurrent Assets
Regulatory Assets		992.4	1,005.3
Deferred Charges and Other Noncurrent Assets		300.8	251.8
TOTAL OTHER NONCURRENT ASSETS		1,293.2	1,257.1
TOTAL ASSETS		10,293.1	9,325.7
Current Liabilities
Advances from Affiliates		156.3	0
Accounts Payable		206.2	163.6
Affiliated Companies		100.5	61.4
Short-term Debt:
Long-term Debt Due Within One Year		6.2	6.2
Risk Management Liabilities		0	2.1
Customer Deposits		65.3	62.4
Accrued Taxes		113.8	44.3
Accrued Interest		30.3	36
Obligations Under Operating Leases		8.4	8.1
Other Current Liabilities		129	154.6
TOTAL CURRENT LIABILITIES		816	538.7
Noncurrent Liabilities
Long-term Debt		3,386.2	3,389
Deferred Income Tax Liabilities, Net		1,112	1,087.6
Regulatory Liabilities and Deferred Investment Tax Credits		818.2	806.9
Asset Retirement Obligations		247.5	192.7
Employee Benefits and Pension Obligations		23.2	20.3
Obligations Under Operating Leases		122.5	77.7
Deferred Credits and Other Noncurrent Liabilities		62.4	63
TOTAL NONCURRENT LIABILITIES		5,772	5,637.2
TOTAL LIABILITIES		6,588	6,175.9
Rate Matters
Commitments and Contingencies
Equity
Common Stock		0.1	0.1
Paid-in Capital		1,445.5	1,092.2
Retained Earnings		2,253.6	2,050.9
Accumulated Other Comprehensive Income (Loss)		5.5	6.7
TOTAL COMMON SHAREHOLDER'S EQUITY		3,704.7	3,149.9
Noncontrolling Interests		0.4	(0.1)
TOTAL EQUITY		3,705.1	3,149.8
TOTAL LIABILITIES AND EQUITY		$ 10,293.1	$ 9,325.7
Common Stock, No Par Value		$ 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		$ 79.2	$ 49.9
Accounts Receivable:
Fuel		9.9	13.1
Materials and Supplies		7.2	12
Property, Plant and Equipment
Other Property, Plant and Equipment		219.9	219.9
Accumulated Depreciation and Amortization		$ 201.8	$ 168.1

[1]Amount includes Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.[2]Amount of securitized debt for receivables as accounted for under the “Transfers and Servicing” accounting guidance.[3]Amount excludes $215 million and $200 million as of September 30, 2022 and December 31, 2021, respectively, of Long-term Debt Due Within One Year classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.[4]Amount excludes $963 million and $903 million as of September 30, 2022 and December 31, 2021, respectively, of Long-term Debt classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.[5]Amount includes Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.

Condensed Consolidated Statem_2

Condensed Consolidated Statements of Cash Flows $ in Millions	9 Months Ended
	Sep. 30, 2022 USD ($) $ / shares	Sep. 30, 2021 USD ($)
Operating Activities
Net Income (Loss)	$ 1,922.2	$ 1,949.5
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	2,416.8	2,103.9
Deferred Income Taxes	16.6	191.1
Other Asset Impairment Charges	24.9	0
Loss on the Expected Sale of the Kentucky Operations	24.9	0
Allowance for Equity Funds Used During Construction	(95.2)	(103.9)
Mark-to-Market of Risk Management Contracts	162.3	101
Property Taxes	459.9	415.1
Establishment of Regulatory Asset	(37)	0
Deferred Fuel Over/Under-Recovery, Net	(148.7)	(1,356.8)
Gain (Loss) on Disposition of Assets	(116.3)	0
Change in Other Noncurrent Assets	(6)	(108)
Change in Other Noncurrent Liabilities	324	162.7
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(495.7)	(199.2)
Fuel, Materials and Supplies	(134.6)	347.4
Accounts Payable	369.4	107.6
Accrued Taxes, Net	(512.8)	(471.1)
Other Current Assets	41.2	(33.3)
Other Current Liabilities	90.9	(133)
Net Cash Flows from (Used for) Operating Activities	4,733.2	2,973
Investing Activities
Construction Expenditures	(4,748.5)	(4,087)
Purchases of Investment Securities	(1,868.2)	(1,612.3)
Sales of Investment Securities	1,833.4	1,571.7
Acquisitions of Nuclear Fuel	(91.9)	(63.2)
Proceeds from Sale of Property, Plant, and Equipment	215.7	17.4
Other Investing Activities	44.3	34.4
Net Cash Flows from (Used for) Investing Activities	(5,822.5)	(4,906.2)
Financing Activities
Issuance of Common Stock	827.2	548
Issuance of Long-term Debt	3,428.4	5,062.3
Issuance of Short-term Debt with Original Maturities greater than 90 Days	271	1,178.5
Change in Short-term Debt with Original Maturities less than 90 Days, Net	803.4	(632.5)
Retirement of Long-term Debt	(1,679.1)	(1,549.8)
Redemption of Short-term Debt with Original Maturities Greater than 90 Days	(986.1)	(521.3)
Principal Payments for Finance Leases Obligations	(120.3)	(45.3)
Dividends Paid on Common Stock	(1,212.5)	(1,122.7)
Other Financing Activities	(116.8)	4.4
Net Cash Flows from (Used for) Financing Activities	1,215.2	2,921.6
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	125.9	988.4
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	451.4	438.3
Cash and Cash Equivalents at Beginning of Period	403.4
Cash, Cash Equivalents and Restricted Cash at End of Period	577.3	1,426.7
Cash and Cash Equivalents at End of Period	522.2
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	856.8	775.2
Net Cash Paid (Received) for Income Taxes	104.1	9.3
Lease Obligation Incurred	22.3	23
Construction Expenditures Included in Noncurrent Liabilities as of March 31,	985.8	764.1
Acquisition of Nuclear Fuel Included in Current Liabilities as of March 31,	8.5	0.3
Commitment from Bank Conduits to Finance Receivables	125
Commitment from Bank Conduits to Finance Receivables Two	$ 625
2020 Equity Units [Member] \| Maximum [Member]
Supplementary Information
AEP Share Price for Equity Unit Conversion \| $ / shares	$ 99.95
Dry Lake Solar Project
Investing Activities
Acquisitions of Assets	$ 0	(114.4)
Supplementary Information
Noncontrolling Interest Assumed - Dry Lake Solar Project	0	35
North Central Wind Energy Facilities
Investing Activities
Acquisitions of Assets	(1,207.3)	(652.8)
Mineral Rights
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Gain (Loss) on Disposition of Assets	(116.3)	0
Kentucky Power Co [Member]
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Loss on the Expected Sale of the Kentucky Operations	263.3	0
Flat Ridge II
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Impairment of Equity Method Investment	188	0
Cedar Creek Project
Supplementary Information
Noncash Contribution of Assets to Cedar Creek Project	0	(9.3)
AEP Texas Inc. [Member]
Operating Activities
Net Income (Loss)	253.2	225.4
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	342.7	287.1
Deferred Income Taxes	35.1	45.8
Allowance for Equity Funds Used During Construction	(13.2)	(16.7)
Mark-to-Market of Risk Management Contracts	(0.2)	0
Change in Other Noncurrent Assets	(48.4)	(73.4)
Change in Other Noncurrent Liabilities	49.2	17.5
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(57.5)	(40.2)
Fuel, Materials and Supplies	(39.9)	(2.5)
Accounts Payable	16	(10.9)
Accrued Taxes, Net	39.4	29.5
Other Current Assets	1	(2)
Other Current Liabilities	12.2	(5)
Net Cash Flows from (Used for) Operating Activities	589.6	454.6
Investing Activities
Construction Expenditures	(949.8)	(742.4)
Change in Advances to Affiliates, Net	(129.4)	(47.5)
Other Investing Activities	26.7	29.6
Net Cash Flows from (Used for) Investing Activities	(1,052.5)	(760.3)
Financing Activities
Capital Contributions from Parent	1.8	0
Issuance of Long-term Debt	1,188.7	444.2
Change in Advances from Affiliates, Net	(26.9)	(67.1)
Retirement of Long-term Debt	(678.6)	(52.2)
Principal Payments for Finance Leases Obligations	(5.1)	(5)
Other Financing Activities	0.3	1
Net Cash Flows from (Used for) Financing Activities	480.2	320.9
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	17.3	15.2
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	30.5	28.8
Cash and Cash Equivalents at Beginning of Period	0.1
Cash, Cash Equivalents and Restricted Cash at End of Period	47.8	44
Cash and Cash Equivalents at End of Period	0.1
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	121.1	110
Net Cash Paid (Received) for Income Taxes	10	(8.4)
Noncash Acquisitions Under Finance Leases	4.1	3.3
Construction Expenditures Included in Current Liabilities as of March 31,	156	134.9
AEP Transmission Co [Member]
Operating Activities
Net Income (Loss)	426.6	445.7
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	256.2	219
Deferred Income Taxes	60.6	46.8
Allowance for Equity Funds Used During Construction	(51.2)	(49.3)
Property Taxes	170	154
Provision for Refund Affiliated	65.7	17.7
Change in Other Noncurrent Assets	4	2.3
Change in Other Noncurrent Liabilities	55	8.3
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(66.4)	(23.6)
Fuel, Materials and Supplies	(2.4)	(0.5)
Accounts Payable	53.1	(10.7)
Accrued Taxes, Net	(194)	(138.8)
Other Current Assets	(1.2)	0.5
Other Current Liabilities	27.2	22.7
Net Cash Flows from (Used for) Operating Activities	737.5	676.4
Investing Activities
Construction Expenditures	(1,059.3)	(1,070.8)
Change in Advances to Affiliates, Net	(84.1)	29.9
Other Investing Activities	(5.3)	(7.9)
Net Cash Flows from (Used for) Investing Activities	(1,148.7)	(1,048.8)
Financing Activities
Capital Contributions from Parent	64.2	184
Issuance of Long-term Debt	540.9	443.7
Change in Advances from Affiliates, Net	(63.9)	(142.8)
Dividends Paid on Common Stock	(130)	(112.5)
Net Cash Flows from (Used for) Financing Activities	411.2	372.4
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect	0	0
Cash and Cash Equivalents at Beginning of Period	0	0
Cash and Cash Equivalents at End of Period	0	0
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	88.6	75.8
Net Cash Paid (Received) for Income Taxes	53.2	37.6
Construction Expenditures Included in Current Liabilities as of March 31,	240.5	206.8
Appalachian Power Co [Member]
Operating Activities
Net Income (Loss)	303.1	275.1
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	431	406.6
Deferred Income Taxes	70.7	(12)
Other Asset Impairment Charges	24.9	0
Loss on the Expected Sale of the Kentucky Operations	24.9	0
Allowance for Equity Funds Used During Construction	(6.8)	(12.1)
Mark-to-Market of Risk Management Contracts	(65.6)	(26.8)
Establishment of Regulatory Asset	(37)	0
Deferred Fuel Over/Under-Recovery, Net	(400.2)	(43.9)
Change in Other Noncurrent Assets	(15.2)	(39.2)
Change in Other Noncurrent Liabilities	39.7	20.2
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	68.7	38.1
Fuel, Materials and Supplies	(61.7)	126.3
Increase (Decrease) in Margin Deposits Outstanding	65.8	(15.8)
Accounts Payable	141.4	26.5
Accrued Taxes, Net	(98.9)	(48)
Other Current Assets	(4.2)	(4.9)
Other Current Liabilities	42.2	0.5
Net Cash Flows from (Used for) Operating Activities	497.9	690.6
Investing Activities
Construction Expenditures	(707.4)	(586.4)
Change in Advances to Affiliates, Net	(161.3)	(163.8)
Other Investing Activities	34.9	12.4
Net Cash Flows from (Used for) Investing Activities	(833.8)	(737.8)
Financing Activities
Capital Contributions from Parent	4.3	0
Issuance of Long-term Debt	698.2	494
Change in Advances from Affiliates, Net	(199.3)	(18.6)
Retirement of Long-term Debt	(130.4)	(393)
Principal Payments for Finance Leases Obligations	(5.9)	(5.8)
Dividends Paid on Common Stock	(37.5)	(37.5)
Other Financing Activities	0.5	0.5
Net Cash Flows from (Used for) Financing Activities	329.9	39.6
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(6)	(7.6)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	20.1	22.7
Cash and Cash Equivalents at Beginning of Period	2.5
Cash, Cash Equivalents and Restricted Cash at End of Period	14.1	15.1
Cash and Cash Equivalents at End of Period	6.7
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	128.3	124.2
Net Cash Paid (Received) for Income Taxes	14.2	52.6
Noncash Acquisitions Under Finance Leases	1	1.3
Construction Expenditures Included in Current Liabilities as of March 31,	160.4	92.3
Indiana Michigan Power Co [Member]
Operating Activities
Net Income (Loss)	250.8	232.1
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	400.2	328.7
Rockport Plant, Unit 2 Operating Lease Amortization	0	51.1
Deferred Income Taxes	(15.8)	(36.6)
Amortization (Deferral) of Incremental Nuclear Refueling Outage Expenses, Net	(35.2)	(2.5)
Allowance for Equity Funds Used During Construction	(7.9)	(9.7)
Mark-to-Market of Risk Management Contracts	(13.2)	0.5
Amortization of Nuclear Fuel	63.1	61.9
Deferred Fuel Over/Under-Recovery, Net	(20.5)	(18)
Change in Other Noncurrent Assets	12.5	7.3
Change in Other Noncurrent Liabilities	42.1	(10.2)
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	5.3	18.2
Fuel, Materials and Supplies	3.1	43
Accounts Payable	19.6	20.1
Accrued Taxes, Net	(17)	(20.3)
Operating Lease, Payments	0	(36.9)
Other Current Assets	19.3	(0.7)
Other Current Liabilities	(63.6)	(28)
Net Cash Flows from (Used for) Operating Activities	642.8	600
Investing Activities
Construction Expenditures	(407.4)	(370.2)
Change in Advances to Affiliates, Net	(1.1)	(67.3)
Purchases of Investment Securities	(1,854.8)	(1,586.3)
Sales of Investment Securities	1,818.4	1,556.6
Acquisitions of Nuclear Fuel	(91.9)	(63.2)
Other Investing Activities	8	12.9
Net Cash Flows from (Used for) Investing Activities	(528.8)	(517.5)
Financing Activities
Capital Contributions from Parent	1.9	0
Issuance of Long-term Debt	72.8	507
Change in Advances from Affiliates, Net	11.6	(103)
Retirement of Long-term Debt	(64.5)	(307.2)
Principal Payments for Finance Leases Obligations	(41.6)	(4.9)
Dividends Paid on Common Stock	(70)	(175)
Other Financing Activities	0.3	0.5
Net Cash Flows from (Used for) Financing Activities	(89.5)	(82.6)
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect	24.5	(0.1)
Cash and Cash Equivalents at Beginning of Period	1.3	3.3
Cash and Cash Equivalents at End of Period	25.8	3.2
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	101.6	93.9
Net Cash Paid (Received) for Income Taxes	(4.1)	11.8
Noncash Acquisitions Under Finance Leases	0.8	3.1
Construction Expenditures Included in Current Liabilities as of March 31,	68.1	59
Acquisition of Nuclear Fuel Included in Current Liabilities as of March 31,	8.5	0.3
Ohio Power Co [Member]
Operating Activities
Net Income (Loss)	229.9	198.6
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	216.9	228.6
Deferred Income Taxes	29.3	29.3
Carrying Costs Income	(0.2)	(1.1)
Allowance for Equity Funds Used During Construction	(10.3)	(7.6)
Mark-to-Market of Risk Management Contracts	(49.6)	(19.9)
Property Taxes	264.7	234.9
Change in Other Noncurrent Assets	(19.7)	(1.1)
Change in Other Noncurrent Liabilities	82.5	4.6
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(27)	20.7
Fuel, Materials and Supplies	(11.6)	(0.6)
Accounts Payable	87.6	(19.1)
Increase (Decrease) in Contract with Customer, Liability	37.4	68.4
Accrued Taxes, Net	(344.5)	(289.7)
Other Current Assets	11.3	(7.8)
Other Current Liabilities	25.7	5.8
Net Cash Flows from (Used for) Operating Activities	522.6	445.1
Investing Activities
Construction Expenditures	(600.6)	(536.6)
Change in Advances to Affiliates, Net	42	(622.9)
Other Investing Activities	21.3	10.7
Net Cash Flows from (Used for) Investing Activities	(537.3)	(1,148.8)
Financing Activities
Capital Contributions from Parent	1	0
Issuance of Long-term Debt	0	1,037.5
Change in Advances from Affiliates, Net	68.8	(259.2)
Retirement of Long-term Debt	(0.1)	(0.1)
Principal Payments for Finance Leases Obligations	(3.6)	(3.7)
Dividends Paid on Common Stock	(45)	(71.9)
Other Financing Activities	0.8	0.5
Net Cash Flows from (Used for) Financing Activities	21.9	703.1
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	7.2	(0.6)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	3	7.4
Cash and Cash Equivalents at Beginning of Period	3
Cash, Cash Equivalents and Restricted Cash at End of Period	10.2	6.8
Cash and Cash Equivalents at End of Period	10.2
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	75.8	78.6
Net Cash Paid (Received) for Income Taxes	24.2	0.3
Noncash Acquisitions Under Finance Leases	2.1	1.4
Construction Expenditures Included in Current Liabilities as of March 31,	108.3	66.5
Public Service Co Of Oklahoma [Member]
Operating Activities
Net Income (Loss)	155.7	136.6
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	172.7	149
Deferred Income Taxes	(20)	109.8
Mark-to-Market of Risk Management Contracts	(36.1)	(8.2)
Property Taxes	(12.2)	(10.9)
Deferred Fuel Over/Under-Recovery, Net	454	(776.4)
Change in Other Noncurrent Assets	(18.1)	(14.3)
Change in Other Noncurrent Liabilities	15.8	4.5
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(66.3)	(13.4)
Fuel, Materials and Supplies	(25.8)	9.9
Accounts Payable	150.8	16.4
Accrued Taxes, Net	(20.9)	9.3
Other Current Assets	(19.2)	(5.9)
Other Current Liabilities	11	(18.4)
Net Cash Flows from (Used for) Operating Activities	741.4	(412)
Investing Activities
Construction Expenditures	(322.6)	(219.6)
Change in Advances to Affiliates, Net	0	(59.5)
Acquisitions of Assets	549.3	297
Other Investing Activities	2.9	1.9
Net Cash Flows from (Used for) Investing Activities	(869)	(574.2)
Financing Activities
Capital Contributions from Parent	3.3	625
Issuance of Long-term Debt	499.7	1,290
Change in Advances from Affiliates, Net	151.2	(155.4)
Retirement of Long-term Debt	(500.4)	(750.4)
Principal Payments for Finance Leases Obligations	(2.4)	(2.5)
Dividends Paid on Common Stock	(20)	(20)
Other Financing Activities	0.4	0.5
Net Cash Flows from (Used for) Financing Activities	131.8	987.2
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect	4.2	1
Cash and Cash Equivalents at Beginning of Period	1.3	2.6
Cash and Cash Equivalents at End of Period	5.5	3.6
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	63.1	42.9
Net Cash Paid (Received) for Income Taxes	21.9	(101.2)
Noncash Acquisitions Under Finance Leases	1.7	3.1
Construction Expenditures Included in Current Liabilities as of March 31,	50.1	44.2
Southwestern Electric Power Co [Member]
Operating Activities
Net Income (Loss)	263.3	210.7
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	251.8	217.4
Deferred Income Taxes	7.5	22.5
Allowance for Equity Funds Used During Construction	(3.4)	(5.4)
Mark-to-Market of Risk Management Contracts	(27.6)	(18.1)
Property Taxes	(22)	(20)
Deferred Fuel Over/Under-Recovery, Net	(82)	(506.8)
Change in Regulatory Assets	3.1	(91.5)
Change in Other Noncurrent Assets	52	38.3
Change in Other Noncurrent Liabilities	17.3	40
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(17.9)	(70.2)
Fuel, Materials and Supplies	23.5	115.1
Accounts Payable	78.9	(21.1)
Accrued Taxes, Net	(1.1)	72.2
Other Current Assets	(12)	4.2
Other Current Liabilities	(38.1)	(48.2)
Net Cash Flows from (Used for) Operating Activities	493.3	(60.9)
Investing Activities
Construction Expenditures	(397)	(277.2)
Change in Advances to Affiliates, Net	153.8	0
Acquisitions of Assets	658	355.8
Other Investing Activities	3.9	2.1
Net Cash Flows from (Used for) Investing Activities	(897.3)	(630.9)
Financing Activities
Capital Contributions from Parent	353.3	280
Issuance of Long-term Debt	0	496.4
Change in Short-term Debt with Original Maturities less than 90 Days, Net	0	(35)
Change in Advances from Affiliates, Net	156.3	(1.7)
Retirement of Long-term Debt	(4.7)	(4.7)
Principal Payments for Finance Leases Obligations	(8)	(8.1)
Dividends Paid on Common Stock	(57.5)	0
Dividends Paid on Common Stock	(2.6)	(3.8)
Other Financing Activities	0.4	0.5
Net Cash Flows from (Used for) Financing Activities	437.2	723.6
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	33.2	31.8
Cash and Cash Equivalents at Beginning of Period	51.2	13.2
Cash and Cash Equivalents at End of Period	84.4	45
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	102.1	98
Net Cash Paid (Received) for Income Taxes	34.7	(11.3)
Noncash Acquisitions Under Finance Leases	3.2	4.4
Construction Expenditures Included in Current Liabilities as of March 31,	$ 71.8	$ 46.8

Significant Accounting Matters

Significant Accounting Matters	9 Months Ended
Significant Accounting Matters	Sep. 30, 2022
Significant Accounting Matters	SIGNIFICANT ACCOUNTING MATTERS The disclosures in this note apply to all Registrants unless indicated otherwise. General The unaudited condensed financial statements and footnotes were prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X of the SEC. Accordingly, they do not include all of the information and footnotes required by GAAP for complete annual financial statements. In the opinion of management, the unaudited condensed interim financial statements reflect all normal and recurring accruals and adjustments necessary for a fair statement of the net income, financial position and cash flows for the interim periods for each Registrant. Net income for the three and nine months ended September 30, 2022 is not necessarily indicative of results that may be expected for the year ending December 31, 2022. The condensed financial statements are unaudited and should be read in conjunction with the audited 2021 financial statements and notes thereto, which are included in the Registrants’ Annual Reports on Form 10-K as filed with the SEC on February 24, 2022. AEP System Tax Allocation The Registrant Subsidiaries join in the filing of a consolidated tax return. Historically, the allocation of the AEP System’s current consolidated federal income tax to the AEP System companies allocated the benefit of current tax loss of the parent company (Parent Company Loss Benefit) to the AEP System subsidiaries through a reduction of current tax expense. In the first quarter of 2022, AEP and subsidiaries changed accounting for the Parent Company Loss Benefit from a reduction of current tax expense to an allocation through equity. The impact of this change was immaterial to the Registrant Subsidiaries’ financial statements. Deferred Fuel Costs (Applies to all Registrants except AEP Texas, AEPTCo and OPCo) The cost of purchased electricity, fuel and related emission allowances and emission control chemicals/consumables is charged to Purchased Electricity, 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 an expectation that refunds or recoveries will extend beyond a one year period, based on a company’s filing with a commission or a commission directive. 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. 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. The following table presents AEP’s basic and diluted EPS calculations included on the statements of income: Three Months Ended September 30, 2022 2021 (in millions, except per share data) $/share $/share Earnings Attributable to AEP Common Shareholders $ 683.7 $ 796.0 Weighted-Average Number of Basic AEP Common Shares Outstanding 513.7 $ 1.33 501.2 $ 1.59 Weighted-Average Dilutive Effect of Stock-Based Awards 1.6 — 1.4 (0.01) Weighted-Average Number of Diluted AEP Common Shares Outstanding 515.3 $ 1.33 502.6 $ 1.58 Nine Months Ended September 30, 2022 2021 (in millions, except per share data) $/share $/share Earnings Attributable to AEP Common Shareholders $ 1,922.9 $ 1,949.2 Weighted-Average Number of Basic AEP Common Shares Outstanding 511.2 $ 3.76 499.4 $ 3.90 Weighted-Average Dilutive Effect of Stock-Based Awards 1.5 (0.01) 1.2 (0.01) Weighted-Average Number of Diluted AEP Common Shares Outstanding 512.7 $ 3.75 500.6 $ 3.89 Equity Units are potentially dilutive securities and were excluded from the calculation of diluted EPS for the three and nine months ended September 30, 2022 and 2021, as the dilutive stock price threshold was not met. See Note 12 - Financing Activities for more information related to Equity Units. There were 0 and 377 thousand antidilutive shares outstanding as of September 30, 2022 and 2021, respectively. 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 statements of cash flows: September 30, 2022 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 522.2 $ 0.1 $ 6.7 Restricted Cash 55.1 47.7 7.4 Total Cash, Cash Equivalents and Restricted Cash $ 577.3 $ 47.8 $ 14.1 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 Supplementary Cash Flow Information (Applies to AEP) Nine Months Ended September 30, Cash Flow Information 2022 2021 (in millions) Cash Paid for: Interest, Net of Capitalized Amounts $ 856.8 $ 775.2 Income Taxes 104.1 9.3 Noncash Investing and Financing Activities: Acquisitions Under Finance Leases 22.3 23.0 Construction Expenditures Included in Current Liabilities as of September 30, 985.8 764.1 Acquisition of Nuclear Fuel Included in Current Liabilities as of September 30, 8.5 0.3 Noncash Contribution of Assets to Cedar Creek Project — (9.3) Noncontrolling Interest Assumed - Dry Lake Solar Project — 35.0

New Accounting Standards

New Accounting Standards	9 Months Ended
New Accounting Standards	Sep. 30, 2022
New Accounting Standards	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	9 Months Ended
Comprehensive Income	Sep. 30, 2022
Comprehensive Income	COMPREHENSIVE INCOME The disclosures in this note apply to all Registrants except AEPTCo and OPCo. Presentation of Comprehensive Income The following tables provide the components of changes in AOCI and details of reclassifications from AOCI. The amortization of pension and OPEB AOCI components are included in the computation of net periodic pension and OPEB costs. See Note 7 - Benefit Plans for additional information. AEP Cash Flow Hedges Pension Three Months Ended September 30, 2022 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2022 $ 533.6 $ (10.8) $ 28.6 $ 551.4 Change in Fair Value Recognized in AOCI 94.3 7.4 (a) — 101.7 Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (b) 0.2 — — 0.2 Purchased Electricity for Resale (b) (222.6) — — (222.6) Interest Expense (b) — 0.9 — 0.9 Amortization of Prior Service Cost (Credit) — — (6.2) (6.2) Amortization of Actuarial (Gains) Losses — — 2.2 2.2 Reclassifications from AOCI, before Income Tax (Expense) Benefit (222.4) 0.9 (4.0) (225.5) Income Tax (Expense) Benefit (46.6) 0.1 (0.8) (47.3) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (175.8) 0.8 (3.2) (178.2) Net Current Period Other Comprehensive Income (Loss) (81.5) 8.2 (3.2) (76.5) Balance in AOCI as of September 30, 2022 $ 452.1 $ (2.6) $ 25.4 $ 474.9 Cash Flow Hedges Pension Three Months Ended September 30, 2021 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2021 $ 110.3 $ (32.2) $ 18.9 $ 97.0 Change in Fair Value Recognized in AOCI 220.8 4.9 (a) — 225.7 Amount of (Gain) Loss Reclassified from AOCI Purchased Electricity for Resale (b) (59.7) — — (59.7) Interest Expense (b) — 1.5 — 1.5 Amortization of Prior Service Cost (Credit) — — (4.8) (4.8) Amortization of Actuarial (Gains) Losses — — 2.3 2.3 Reclassifications from AOCI, before Income Tax (Expense) Benefit (59.7) 1.5 (2.5) (60.7) Income Tax (Expense) Benefit (12.5) 0.3 (0.5) (12.7) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (47.2) 1.2 (2.0) (48.0) Net Current Period Other Comprehensive Income (Loss) 173.6 6.1 (2.0) 177.7 Balance in AOCI as of September 30, 2021 $ 283.9 $ (26.1) $ 16.9 $ 274.7 AEP Cash Flow Hedges Pension Nine Months Ended September 30, 2022 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2021 $ 163.7 $ (21.3) $ 42.4 $ 184.8 Change in Fair Value Recognized in AOCI 629.8 16.2 (a) — 646.0 Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (b) 0.2 — — 0.2 Purchased Electricity for Resale (b) (432.3) — — (432.3) Interest Expense (b) — 3.1 — 3.1 Amortization of Prior Service Cost (Credit) — — (16.5) (16.5) Amortization of Actuarial (Gains) Losses — — 6.4 6.4 Reclassifications from AOCI, before Income Tax (Expense) Benefit (432.1) 3.1 (10.1) (439.1) Income Tax (Expense) Benefit (90.7) 0.6 (2.1) (92.2) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (341.4) 2.5 (8.0) (346.9) Reclassifications of KPCo Pension and OPEB Regulatory Assets to AOCI — — (11.4) (11.4) Income Tax (Expense) Benefit — — (2.4) (2.4) Reclassifications of KPCo Pension and OPEB Regulatory Assets to AOCI, Net of Income Tax (Expense) Benefit — — (9.0) (9.0) Net Current Period Other Comprehensive Income (Loss) 288.4 18.7 (17.0) 290.1 Balance in AOCI as of September 30, 2022 $ 452.1 $ (2.6) $ 25.4 $ 474.9 Cash Flow Hedges Pension Nine Months Ended September 30, 2021 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2020 $ (60.6) $ (47.5) $ 23.0 $ (85.1) Change in Fair Value Recognized in AOCI 534.5 17.6 (a) — 552.1 Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (b) 0.7 — — 0.7 Purchased Electricity for Resale (b) (241.2) — — (241.2) Interest Expense (b) — 4.8 — 4.8 Amortization of Prior Service Cost (Credit) — — (14.5) (14.5) Amortization of Actuarial (Gains) Losses — — 6.8 6.8 Reclassifications from AOCI, before Income Tax (Expense) Benefit (240.5) 4.8 (7.7) (243.4) Income Tax (Expense) Benefit (50.5) 1.0 (1.6) (51.1) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (190.0) 3.8 (6.1) (192.3) Net Current Period Other Comprehensive Income (Loss) 344.5 21.4 (6.1) 359.8 Balance in AOCI as of September 30, 2021 $ 283.9 $ (26.1) $ 16.9 $ 274.7 AEP Texas Cash Flow Hedge – Pension Three Months Ended September 30, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2022 $ (0.8) $ (5.2) $ (6.0) Change in Fair Value Recognized in AOCI 0.1 — 0.1 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.3 — 0.3 Amortization of Prior Service Cost (Credit) — (0.1) (0.1) Amortization of Actuarial (Gains) Losses — 0.1 0.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.3 — 0.3 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.2 — 0.2 Net Current Period Other Comprehensive Income (Loss) 0.3 — 0.3 Balance in AOCI as of September 30, 2022 $ (0.5) $ (5.2) $ (5.7) Cash Flow Hedge – Pension Three Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2021 $ (1.8) $ (6.5) $ (8.3) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.4 — 0.4 Amortization of Prior Service Cost (Credit) — (0.1) (0.1) Amortization of Actuarial (Gains) Losses — 0.1 0.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.4 — 0.4 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.3 — 0.3 Net Current Period Other Comprehensive Income (Loss) 0.3 — 0.3 Balance in AOCI as of September 30, 2021 $ (1.5) $ (6.5) $ (8.0) AEP Texas Cash Flow Hedge – Pension Nine Months Ended September 30, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2021 $ (1.3) $ (5.2) $ (6.5) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.0 — 1.0 Amortization of Prior Service Cost (Credit) — (0.1) (0.1) Amortization of Actuarial (Gains) Losses — 0.1 0.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.0 — 1.0 Income Tax (Expense) Benefit 0.2 — 0.2 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.8 — 0.8 Net Current Period Other Comprehensive Income (Loss) 0.8 — 0.8 Balance in AOCI as of September 30, 2022 $ (0.5) $ (5.2) $ (5.7) Cash Flow Hedge – Pension Nine Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2020 $ (2.3) $ (6.6) $ (8.9) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.0 — 1.0 Amortization of Prior Service Cost (Credit) — (0.1) (0.1) Amortization of Actuarial (Gains) Losses — 0.2 0.2 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.0 0.1 1.1 Income Tax (Expense) Benefit 0.2 — 0.2 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.8 0.1 0.9 Net Current Period Other Comprehensive Income (Loss) 0.8 0.1 0.9 Balance in AOCI as of September 30, 2021 $ (1.5) $ (6.5) $ (8.0) APCo Cash Flow Hedge – Pension Three Months Ended September 30, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2022 $ 7.1 $ 14.8 $ 21.9 Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (0.3) — (0.3) Amortization of Prior Service Cost (Credit) — (1.4) (1.4) Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.3) (1.4) (1.7) Income Tax (Expense) Benefit (0.1) (0.3) (0.4) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.2) (1.1) (1.3) Net Current Period Other Comprehensive Income (Loss) (0.2) (1.1) (1.3) Balance in AOCI as of September 30, 2022 $ 6.9 $ 13.7 $ 20.6 Cash Flow Hedge – Pension Three Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2021 $ 8.0 $ 5.9 $ 13.9 Change in Fair Value Recognized in AOCI 0.2 — 0.2 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (0.6) — (0.6) Amortization of Prior Service Cost (Credit) — (1.2) (1.2) Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.6) (1.2) (1.8) Income Tax (Expense) Benefit (0.1) (0.2) (0.3) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.5) (1.0) (1.5) Net Current Period Other Comprehensive Income (Loss) (0.3) (1.0) (1.3) Balance in AOCI as of September 30, 2021 $ 7.7 $ 4.9 $ 12.6 APCo Cash Flow Hedge – Pension Nine Months Ended September 30, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2021 $ 7.5 $ 16.9 $ 24.4 Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (0.8) — (0.8) Amortization of Prior Service Cost (Credit) — (4.1) (4.1) Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.8) (4.1) (4.9) Income Tax (Expense) Benefit (0.2) (0.9) (1.1) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.6) (3.2) (3.8) Net Current Period Other Comprehensive Income (Loss) (0.6) (3.2) (3.8) Balance in AOCI as of September 30, 2022 $ 6.9 $ 13.7 $ 20.6 Cash Flow Hedge – Pension Nine Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2020 $ (0.8) $ 8.0 $ 7.2 Change in Fair Value Recognized in AOCI 9.3 — 9.3 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (1.0) — (1.0) Amortization of Prior Service Cost (Credit) — (3.9) (3.9) Reclassifications from AOCI, before Income Tax (Expense) Benefit (1.0) (3.9) (4.9) Income Tax (Expense) Benefit (0.2) (0.8) (1.0) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.8) (3.1) (3.9) Net Current Period Other Comprehensive Income (Loss) 8.5 (3.1) 5.4 Balance in AOCI as of September 30, 2021 $ 7.7 $ 4.9 $ 12.6 I&M Cash Flow Hedge – Pension Three Months Ended September 30, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2022 $ (5.9) $ 5.2 $ (0.7) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.5 — 0.5 Amortization of Prior Service Cost (Credit) — (0.3) (0.3) Amortization of Actuarial (Gains) Losses — 0.1 0.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.5 (0.2) 0.3 Income Tax (Expense) Benefit 0.1 (0.1) — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.4 (0.1) 0.3 Net Current Period Other Comprehensive Income (Loss) 0.4 (0.1) 0.3 Balance in AOCI as of September 30, 2022 $ (5.5) $ 5.1 $ (0.4) Cash Flow Hedge – Pension Three Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2021 $ (7.4) $ 1.2 $ (6.2) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.5 — 0.5 Amortization of Prior Service Cost (Credit) — (0.2) (0.2) Amortization of Actuarial (Gains) Losses — 0.2 0.2 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.5 — 0.5 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.4 — 0.4 Net Current Period Other Comprehensive Income (Loss) 0.4 — 0.4 Balance in AOCI as of September 30, 2021 $ (7.0) $ 1.2 $ (5.8) I&M Cash Flow Hedge – Pension Nine Months Ended September 30, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2021 $ (6.7) $ 5.4 $ (1.3) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.5 — 1.5 Amortization of Prior Service Cost (Credit) — (0.7) (0.7) Amortization of Actuarial (Gains) Losses — 0.3 0.3 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.5 (0.4) 1.1 Income Tax (Expense) Benefit 0.3 (0.1) 0.2 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.2 (0.3) 0.9 Net Current Period Other Comprehensive Income (Loss) 1.2 (0.3) 0.9 Balance in AOCI as of September 30, 2022 $ (5.5) $ 5.1 $ (0.4) Cash Flow Hedge – Pension Nine Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2020 $ (8.3) $ 1.3 $ (7.0) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.6 — 1.6 Amortization of Prior Service Cost (Credit) — (0.6) (0.6) Amortization of Actuarial (Gains) Losses — 0.5 0.5 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.6 (0.1) 1.5 Income Tax (Expense) Benefit 0.3 — 0.3 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.3 (0.1) 1.2 Net Current Period Other Comprehensive Income (Loss) 1.3 (0.1) 1.2 Balance in AOCI as of September 30, 2021 $ (7.0) $ 1.2 $ (5.8) PSO Cash Flow Hedge – Three Months Ended September 30, 2022 Interest Rate (in millions) Balance in AOCI as of June 30, 2022 $ — 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 September 30, 2022 $ — Cash Flow Hedge – Three Months Ended September 30, 2021 Interest Rate (in millions) Balance in AOCI as of June 30, 2021 $ — 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 September 30, 2021 $ — Cash Flow Hedge – Nine Months Ended September 30, 2022 Interest Rate (in millions) Balance in AOCI as of December 31, 2021 $ — 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 September 30, 2022 $ — Cash Flow Hedge – Nine Months Ended September 30, 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 September 30, 2021 $ — SWEPCo Cash Flow Hedge – Pension Three Months Ended September 30, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2022 $ 1.2 $ 4.7 $ 5.9 Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Amortization of Prior Service Cost (Credit) — (0.5) (0.5) Reclassifications from AOCI, before Income Tax (Expense) Benefit — (0.5) (0.5) Income Tax (Expense) Benefit — (0.1) (0.1) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit — (0.4) (0.4) Net Current Period Other Comprehensive Income (Loss) — (0.4) (0.4) Balance in AOCI as of September 30, 2022 $ 1.2 $ 4.3 $ 5.5 Cash Flow Hedge – Pension Three Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2021 $ 0.5 $ 1.4 $ 1.9 Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.4 — 0.4 Amortization of Prior Service Cost (Credit) — (0.5) (0.5) Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.4 (0.5) (0.1) Income Tax (Expense) Benefit 0.1 (0.1) — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.3 (0.4) (0.1) Net Current Period Other Comprehensive Income (Loss) 0.3 (0.4) (0.1) Balance in AOCI as of September 30, 2021 $ 0.8 $ 1.0 $ 1.8 SWEPCo Cash Flow Hedge – Pension Nine Months Ended September 30, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2021 $ 1.2 $ 5.5 $ 6.7 Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Amortization of Prior Service Cost (Credit) — (1.5) (1.5) Reclassifications from AOCI, before Income Tax (Expense) Benefit — (1.5) (1.5) Income Tax (Expense) Benefit — (0.3) (0.3) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit — (1.2) (1.2) Net Current Period Other Comprehensive Income (Loss) — (1.2) (1.2) Balance in AOCI as of September 30, 2022 $ 1.2 $ 4.3 $ 5.5 Cash Flow Hedge – Pension Nine Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2020 $ (0.3) $ 2.2 $ 1.9 Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.4 — 1.4 Amortization of Prior Service Cost (Credit) — (1.5) (1.5) Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.4 (1.5) (0.1) Income Tax (Expense) Benefit 0.3 (0.3) — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.1 (1.2) (0.1) Net Current Period Other Comprehensive Income (Loss) 1.1 (1.2) (0.1) Balance in AOCI as of September 30, 2021 $ 0.8 $ 1.0 $ 1.8 (a) The change in fair value includes $(4) million and $(1) million, respectively, for the three months ended September 30, 2022 and 2021 and $(9) million and $(5) million, respectively, for the nine months ended September 30, 2022 and 2021 related to AEP's investment in joint venture wind farms acquired as part of the purchase of Sempra Renewables LLC. (b) Amounts reclassified to the referenced line item on the statements of income.

Rate Matters

Rate Matters	9 Months Ended
Rate Matters	Sep. 30, 2022
Rate Matters	RATE MATTERS The disclosures in this note apply to all Registrants unless indicated otherwise. As discussed in the 2021 Annual Report, the Registrants are involved in rate and regulatory proceedings at the FERC and their state commissions. The Rate Matters note within the 2021 Annual Report should be read in conjunction with this report to gain a complete understanding of material rate matters still pending that could impact net income, cash flows and possibly financial condition. The following discusses ratemaking developments in 2022 and updates the 2021 Annual Report. 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 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 below 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 below for additional information. As of September 30, 2022, SWEPCo had 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 2021. As part of the 2021 Arkansas Base Rate Case, the APSC authorized recovery of SWEPCo’s Arkansas jurisdictional share of the Dolet Hills Power Station over five years, but denied SWEPCo the ability to earn a return on this investment resulting in a disallowance of $2 million in the second quarter of 2022. Also, the APSC did not rule on the prudency of the early retirement of the Dolet Hills Power Station, which will be addressed in a future proceeding. SWEPCo has requested recovery of the Dolet Hills Power Station in the Louisiana jurisdiction through the 2020 Louisiana Base Rate Case. As of September 30, 2022, SWEPCo had a regulatory asset of $55 million, pending approval, recorded on its balance sheet related to the Louisiana and FERC jurisdictional shares of the Dolet Hills Power Station. The Dolet Hills Power Station is currently being recovered through 2026 in the Louisiana jurisdiction, through 2027 in the Arkansas jurisdiction and through 2046 in the Texas jurisdiction. See “2020 Texas Base Rate Case”, “2020 Louisiana Base Rate Case” and “2021 Arkansas Base Rate Case” sections below for additional information. 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. SWEPCo In November 2020, management announced plans to retire Pirkey 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 September 30, 2022, 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 $ 143.7 $ 141.4 $ 20.2 (b) 2026 (c) $ 14.9 Pirkey Plant 65.0 150.7 39.6 2023 (d) 12.5 Welsh Plant, Units 1 and 3 432.3 75.7 58.2 (e) 2028 (f) 39.8 (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 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. While in operation, DHLC provided 100% of the fuel supply to Dolet Hills Power Station. The remaining book value of Dolet Hills Power Station non-fuel related assets are recoverable by SWEPCo through a combination of base rates and rate riders. As of September 30, 2022, SWEPCo’s share of the net investment in the Dolet Hills Power Station was $113 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 and are subject to prudency determinations by the various commissions. After closure of the DHLC mining operations and the Dolet Hills Power Station, additional reclamation and other land-related costs incurred by DHLC and Oxbow will continue to be billed to SWEPCo and included in existing fuel clauses. As of September 30, 2022, SWEPCo had a net under-recovered fuel balance of $236 million, inclusive of costs related to the Dolet Hills Power Station billed by DHLC, but excluding impacts of the February 2021 severe winter weather event. 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 August 2022, the LPSC staff filed testimony recommending fuel disallowances of $72 million, including denial of recovery of the $30 million deferral, with refunds to customers over five years. In September 2022, SWEPCO filed rebuttal testimony addressing the LPSC staff recommendations. In March 2021, the APSC approved fuel rates that provide recovery of $20 million for the Arkansas share of the 2021 Dolet Hills Power Station fuel costs over five years through the existing fuel clause. In August 2022, SWEPCo filed a fuel reconciliation with the PUCT covering the fuel period of January 1, 2020 through December 31, 2021. If any of these costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. Pirkey Plant and Related Fuel Operations (Applies to AEP and SWEPCo) In 2020, management announced plans to retire the Pirkey Plant in 2023. The Pirkey Plant non-fuel costs are recoverable by SWEPCo through base rates and fuel costs are recovered through active fuel clauses and are subject to prudency determinations by the various commissions. As of September 30, 2022, SWEPCo’s share of the net investment in the Pirkey Plant was $216 million, including CWIP, before cost of removal. Sabine is a mining operator providing mining services to the Pirkey 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 $49 million as of September 30, 2022. As of September 30, 2022, SWEPCo had a net under-recovered fuel balance of $236 million, inclusive of costs related to the Pirkey Plant billed by Sabine, but excluding impacts of the February 2021 severe winter weather event. Upon cessation of lignite deliveries by Sabine to the Pirkey 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. Regulatory Assets Pending Final Regulatory Approval (Applies to all Registrants except AEPTCo) AEP September 30, December 31, 2022 2021 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Pirkey Plant Accelerated Depreciation $ 150.7 $ 87.0 Unrecovered Winter Storm Fuel Costs (a) 126.1 430.2 Welsh Plant, Units 1 and 3 Accelerated Depreciation 75.7 45.9 Dolet Hills Power Station Accelerated Depreciation 54.7 72.3 Plant Retirement Costs – Unrecovered Plant, Louisiana 35.2 35.2 Dolet Hills Power Station Fuel Costs - Louisiana 31.8 30.9 Other Regulatory Assets Pending Final Regulatory Approval 21.2 9.2 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 306.5 241.8 2017-2019 Virginia Triennial Under-Earnings 37.0 — Plant Retirement Costs – Asset Retirement Obligation Costs 25.9 25.9 2020-2022 Virginia Triennial Under-Earnings 25.3 15.1 COVID-19 8.7 11.2 Renewable Energy Portfolio Standards Costs - Virginia — 2.1 Other Regulatory Assets Pending Final Regulatory Approval 42.4 41.8 Total Regulatory Assets Pending Final Regulatory Approval $ 941.2 $ 1,048.6 (a) Includes $37 million and $63 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of September 30, 2022 and December 31, 2021, respectively. AEP Texas September 30, December 31, 2022 2021 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Mobile Generation Lease Payments $ 9.2 $ — Regulatory Assets Currently Not Earning a Return Storm-Related Costs 27.0 22.4 Vegetation Management Program 5.2 5.2 Texas Retail Electric Provider Bad Debt Expense 4.1 4.1 COVID-19 3.8 2.1 Other Regulatory Assets Pending Final Regulatory Approval 8.2 7.4 Total Regulatory Assets Pending Final Regulatory Approval $ 57.5 $ 41.2 APCo September 30, December 31, 2022 2021 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return COVID-19 – Virginia $ 7.0 $ 6.8 Regulatory Assets Currently Not Earning a Return Storm-Related Costs - West Virginia 69.9 53.7 2017-2019 Virginia Triennial Under-Earnings 37.0 — Plant Retirement Costs – Asset Retirement Obligation Costs 25.9 25.9 2020-2022 Virginia Triennial Under-Earnings 25.3 15.1 Renewable Energy Portfolio Standards Costs - Virginia — 2.1 Other Regulatory Assets Pending Final Regulatory Approval 1.6 1.5 Total Regulatory Assets Pending Final Regulatory Approval $ 166.7 $ 105.1 I&M September 30, December 31, 2022 2021 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Other Regulatory Assets Pending Final Regulatory Approval $ 0.1 $ 0.1 Regulatory Assets Currently Not Earning a Return COVID-19 0.1 1.7 Other Regulatory Assets Pending Final Regulatory Approval 1.7 1.9 Total Regulatory Assets Pending Final Regulatory Approval $ 1.9 $ 3.7 OPCo September 30, December 31, 2022 2021 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Not Earning a Return Storm-Related Costs $ 32.5 $ 3.8 Other Regulatory Assets Pending Final Regulatory Approval 0.1 — Total Regulatory Assets Pending Final Regulatory Approval $ 32.6 $ 3.8 PSO September 30, December 31, 2022 2021 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Not Earning a Return Storm-Related Costs $ 24.3 $ 13.9 Other Regulatory Assets Pending Final Regulatory Approval 0.1 0.3 Total Regulatory Assets Pending Final Regulatory Approval $ 24.4 $ 14.2 . SWEPCo September 30, December 31, 2022 2021 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Pirkey Plant Accelerated Depreciation $ 150.7 $ 87.0 Unrecovered Winter Storm Fuel Costs (a) 126.1 430.2 Welsh Plant, Units 1 and 3 Accelerated Depreciation 75.7 45.9 Dolet Hills Power Station Accelerated Depreciation 54.7 72.3 Plant Retirement Costs – Unrecovered Plant, Louisiana 35.2 35.2 Dolet Hills Power Station Fuel Costs- Louisiana 31.8 30.9 Other Regulatory Assets Pending Final Regulatory Approval 4.9 2.4 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 151.3 148.0 Asset Retirement Obligation - Louisiana 11.3 10.3 Other Regulatory Assets Pending Final Regulatory Approval 14.9 18.4 Total Regulatory Assets Pending Final Regulatory Approval $ 656.6 $ 880.6 (a) Includes $37 million and $63 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of September 30, 2022 and December 31, 2021, respectively. If these costs are ultimately determined not to be recoverable, it could reduce future net income and cash flows and impact financial condition. AEP Texas Rate Matters (Applies to AEP and AEP Texas) AEP Texas Interim Transmission and Distribution Rates Through September 30, 2022, AEP Texas’ cumulative revenues from interim base rate increases that are subject to review is approximately $524 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 March 2021, APCo filed an appeal with the Virginia Supreme Court related to 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 October 2021, the Virginia SCC and additional intervenors filed briefs with the Virginia Supreme Court disagreeing with the items appealed by APCo in the Triennial Review decision. Additionally, the Virginia SCC and APCo filed briefs disagreeing with the items appealed by an intervenor in a separate appeal of the same decision. In March 2022, oral arguments were held at the Virginia Supreme Court. In August 2022, the Virginia Supreme Court issued its opinion on submitted appeals of APCo’s 2017-2019 Virginia Triennial Review concluding that the Virginia SCC: a) erred in finding it was not reasonable for APCo to record all remaining costs associated with early retirement of certain coal-fired generating plants in the 2017-2019 earnings test period, b) did not err by ordering APCo to retroactively implement depreciation rates for the years 2018 and 2019 and c) did not err in finding that APCo’s affiliate costs from OVEC were reasonable. The Virginia Supreme Court then remanded the issue regarding the retired coal-fired plants back to the Virginia SCC for further proceedings. In September 2022, and in response to the Virginia Supreme Court opinion and subsequent Virginia SCC order initiating a remand proceeding, APCo submitted with the Virginia SCC: (a) an updated 2017-2019 Virginia earnings calculation resulting in a proposed $37 million regulatory asset related to previously incurred costs that APCo is expecting to recover as a result of earning below its 2017-2019 authorized ROE band, (b) an updated requested annual base rate increase of $41 million effective October 2022 and (c) a requested rider to recover, over the period October 2022 through January 2024, approximately $72 million related to an APCo Virginia base rate increase for the period January 2021 through September 2022. APCo’s requested $41 million annual base rate increase includes approximately $12 million related to the recovery of APCo’s regulatory asset for previously incurred costs as a result of earning below its 2017-2019 authorized ROE band. APCo implemented interim base rate and rider rate increases effective October 2022, both of which are subject to refund and review by the Virginia SCC. An order from the Virginia SCC in the remand proceeding is expected in the fourth quarter of 2022. In September 2022, APCo expensed the remaining $25 million closed coal plant regulatory asset that was previously ordered by the Virginia SCC and recorded a $37 million regulatory asset for previously incurred costs that APCo is expecting to recover as a result of earning below its 2017-2019 authorized ROE band. APCo’s October 2022 through January 2024 net income, cash flows and financial condition is expected to be positively impacted pending the Virginia SCC’s order on APCo’s requested base rate and rider rate increases. 2020-2022 Virginia Triennial Review In March 2023, APCo will submit its required Virginia earnings test calculation for the 2020-2022 Triennial Review period. For Triennial Review periods in which a Virginia utility earns below its authorized ROE band, the utility may file to recover expenses incurred, up to the bottom of the authorized ROE band, related to major storms, the early retirement of fossil fuel generating assets and certain projects necessary to comply with state and federal environmental legislation. As of September 2022, APCo has deferred approximately $25 million related to previously incurred costs as a result of the current estimate that APCo will earn below the bottom of its authorized ROE band during the 2020-2022 Triennial Review period. If it is determined that APCo has earned above the bottom of its authorized ROE band for the 2020-2022 Triennial Review period it could reduce future net income and cash flows and impact financial conditions. 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. In August 2021, the Virginia SCC issued an order approving recovery of CCR-related operation and maintenance expenses and investments at the Amos and Mountaineer Plants through an active rider. The order also denied APCo’s request to recover the cost of ELG investments and denied recovery of previously incurred ELG costs, but did not preclude APCo from refiling for approval. In March 2022, APCo refiled for approval to recover the cost of the ELG investments and previously incurred ELG costs. Intervenor testimony was submitted in August 2022 recommending the denial of ELG cost recovery. In October 2022, a Virginia Hearing Examiner recommended that the Virginia SCC approve recovery of APCo’s requested ELG investment costs at Amos and Mountaineer Plants. Management expects to receive an order from the Virginia SCC in the fourth 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 those 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 WVPSC also ordered that APCo will be given the opportunity to recover, from West Virginia customers, the ELG and 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. The October 2021 order further states that unless the Virginia jurisdictional customers of APCo pay for their share of costs for ELG improvements and costs necessary to continue operations beyond 2028, the benefit of the capacity and energy made possible by those improvements and operating the Amos and Mountaineer Plants beyond 2028 should benefit only West Virginia and FERC jurisdictional customers who have shared in paying for those costs. APCo expects the total Amos and Mountaineer Plant ELG investment, excluding AFUDC, to be approximately $162 million. As of September 30, 2022, 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 $62 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. 2021 and 2022 ENEC (Expanded Net Energy Cost) Filings In April 2021, APCo and WPCo (the Companies) requested a $73 million annual increase in ENEC rates based on a cumulative combined $55 million ENEC under-recovery as of February 28, 2021 and a combined $18 million increase in projected ENEC costs for the period September 2021 through August 2022. In September 2021, the WVPSC issued an order approving a $7 million overall increase in ENEC rates, including an approval for recovery of the Companies’ cumulative $55 million ENEC under-recovery balance and a $48 million reduction in projected costs for the period September 2021 through August 2022. Subsequently, the Companies submitted a request for reconsideration of this order, identifying flaws in the WVPSC’s calculation of forecasted future year fuel expense and purchased power costs. In March 2022, the WVPSC issued an order granting the Companies’ request for reconsideration, in part, and approving $31 million in projected costs for the period September 2021 through August 2022. The order also reopened the 2021 ENEC case to require the Companies to explain the significant growth in the reported under-recovery of ENEC costs and to provide various other information including revised projected costs for the period March 2022 through August 2022. Also, in March 2022, the Companies filed testimony providing the information requested in the WVPSC’s order and requested a $155 million annual increase in ENEC rates effective May 1, 2022. In May 2022, the WVPSC issued an order approving a $93 million overall increase to ENEC rates to recover projected annual ENEC costs. However, the WVPSC stated that actual and projected ENEC costs are still subject to a prudency review. In April 2022, the Companies submitted their 2022 annual ENEC filing with the WVPSC requesting a $297 million annual increase in ENEC revenues, inclusive of the previously requested $155 million increase, effective September 1, 2022. In September 2022, following an agreed upon delay in the proceedings of the Companies’ 2022 ENEC case, certain intervenors submitted testimony recommending disallowances of at least $83 million to the Companies’ historical period ENEC under-recovery balance along with proposals to either securitize the Companies’ remaining ENEC balance or defer recovery of this balance beyond the traditional one-year period. West Virginia Staff recommended a $13 million increase in ENEC rates pending the outcome of the ENEC prudency review. Management expects to receive a WVPSC order on the Companies’ 2022 ENEC filing in the fourth quarter of 2022 and a separate WVPSC order on the prudency review of the Companies’ ENEC costs in the first quarter of 2023. As of September 30, 2022, the Companies’ cumulative ENEC under-recovery was $430 million. If any deferred ENEC costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. June 2022 West Virginia Storm Costs In June 2022, the West Virginia service territories of APCo and WPCo (the Companies) were impacted by strong winds from multiple storms resulting in system damages and power outages. As of September 30, 2022, the Companies incurred and deferred an estimated $15 million in incremental distribution operation and maintenance expenses related to service restoration efforts. The Companies will seek recovery of these deferrals in future filings. If any of the storm restoration costs are not recoverable, it could 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 September 30, 2022, AEP’s share of ETT’s cumulative revenues that are subject to review is approximately $1.5 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 $1.5 billion of cumulative revenues above will be subject to review. I&M Rate Matters (Applies to AEP and I&M) Michigan Power Supply Cost Recovery (PSCR) Reconciliation In April 2022, an Administrative Law Judge (ALJ) issued a Proposal for Decision (PFD) for I&M’s PSCR reconciliation for the 12-month period ending December 31, 2020, recommending the MPSC disallow approximately $8 million of purchased power costs that I&M incurred under the Inter-Company Power Agreement with OVEC and the Unit Power Agreement with AEGCo. In May 2022, I&M submitted exceptions to the ALJ’s PFD related to the recommended disallowance of purchased power costs described above. I&M anticipates that the MPSC will issue a final decision in the fourth quarter of 2022. Management is unable to predict the impact, if any, that the MPSC’s final decision may have on future results of operations, financial condition and cash flows. Indiana Earnings Test Filings I&M is required by Indiana law to submit an earnings test evaluation for the most recent one-year and five-year periods as part of I&M’s semi-annual Indiana FAC filings. These earnings test evaluations require I&M to include a credit in the FAC factor computation for periods in which I&M earned above its authorized return for both the one-year and five-year periods. The credit is determined as 50% of the lower of the one-year or five-year earnings above the authorized level. In August 2022, I&M submitted its FAC filing and earnings test evaluation for the period ended May 2022, which calculated a credit due to customers of $14 million. In October 2022, the IURC approved the FAC filing and earnings test evaluation, with the credit to customers starting in November 2022 through the FAC. 2022 Michigan Integrated Resource Plan (IRP) Filing In February 2022, I&M filed a request with the MPSC for approval of its 2022 IRP. Included in that filing were requests for approval and deferral of costs associated with resources commencing construction within three years of the Commission’s order in the filing. These resources include the new generation resources expected to be in-service by 2028, and demand-side resources, including load management programs and conservation voltage reduction investments. I&M is also requesting MPSC approval of I&M’s Rockport Unit 2 transition plan consistent with that approved by the IURC, including certain cost recovery related to remaining net book value of leasehold improvements made during the term of the Rockport Unit 2 lease and future use of Rockport Unit 2 as a capacity resource. In addition, I&M has made requests for approval of a financial incentive on certain power purchase agreements and load management programs. As of September 30, 2022, I&M’s total net book value for these Rockport Unit 2 leasehold improvements was $102 million. In June 2022, intervening parties recommended various adjustments to I&M’s proposals, including the process I&M would use to receive approval of new generation resources, changes to or denial of requested financial incentives and requests for deferral and pre-approval of costs. Specific to I&M’s Rockport Unit 2 transition plan, certain intervening parties recommended that the MPSC order I&M to credit back to Michigan ratepayers the jurisdictional share of post-lease revenues in excess of costs from Rockport Unit 2’s operations as a merchant facility and that I&M only receive a post-lease debt return on remaining net book value of Rockport Unit 2 leasehold improvements. A hearing with the MPSC was held in August 2022. Management currently anticipates that the MPSC will issue an order on I&M’s 2022 Michigan IRP filing in the first quarter of 2023. Any disallowance or reduction in the recovery of the I&M Michigan jurisdictional share of the Rockport Unit 2 leasehold improvements could reduce future net income and cash flows and impact financial condition. KPCo Rate Matters (Applies to AEP) CCR/ELG Compliance Plan Filings KPCo and WPCo each own a 50% interest in the Mitchell Plant. As of September

Commitments, Guarantees and Con

Commitments, Guarantees and Contingencies	9 Months Ended
Commitments, Guarantees and Contingencies	Sep. 30, 2022
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. The Commitments, Guarantees and Contingencies note within the 2021 Annual Report should be read in conjunction with this report. 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 2027 and 2024, respectively, under which up to $1.2 billion may be issued as letters of credit on behalf of subsidiaries. As of September 30, 2022, 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 $400 million. The Registrants’ maximum future payments for letters of credit issued under the uncommitted facilities as of September 30, 2022 were as follows: Company Amount Maturity (in millions) AEP $ 309.9 October 2022 to August 2023 AEP Texas 1.8 July 2023 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 September 30, 2022, the maximum potential amount of future payments associated with these guarantees was $120 million, with the last guarantee expiring in December 2037. The non-contingent liability recorded associated with these guarantees was $5 million, with an additional $395 thousand expected credit loss liability for the contingent portion of the guarantees. In accordance with the accounting guidance for guarantees, the initial recognition of the non-contingent liabilities increased AEP’s carrying values of the respective equity method investees. 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. 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 September 30, 2022, 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. 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 September 30, 2022, 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 $ 45.9 AEP Texas 10.9 APCo 6.3 I&M 4.3 OPCo 7.4 PSO 4.8 SWEPCo 5.4 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 the 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 approval, 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 September 30, 2022, inclusive of the purchase obligation, were as follows: Future Minimum Lease Payments AEP (a) I&M (in millions) 2022 $ 174.9 $ 87.4 Total Future Minimum Lease Payments $ 174.9 $ 87.4 (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 AEGCo and I&M. Neither AEGCo nor I&M 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 trust 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 September 30, 2022, the maximum potential amount of future payments required under the guaranteed leases was $36 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 September 30, 2022, 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 sheets. In February 2020, the nonaffiliated party filed Chapter 11 bankruptcy. The party entered into a restructuring support agreement and has announced it expected 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. 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. For remediation processes not specifically discussed, management does not anticipate that the liabilities, if any, arising from such remediation processes would have a material effect on the financial statements. NUCLEAR CONTINGENCIES (Applies to AEP and I&M) I&M owns and operates the Cook Plant under licenses granted by the Nuclear Regulatory Commission. 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. OPERATIONAL CONTINGENCIES 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 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. Management believes its financial statements appropriately reflect the resolution of the litigation. Upon the end of the Rockport Unit 2 lease in December 2022, AEGCo’s 50% ownership share of Rockport Unit 2 will be billed 100% to I&M under a FERC-approved unit power agreement. In addition, upon the end of the Rockport Unit 2 lease, I&M’s 50% ownership share of Rockport Unit 2 and I&M’s purchased power from AEGCo related to Rockport Unit 2 will be a merchant resource for I&M until Rockport Unit 2 is retired. A 2021 IURC order approved a settlement agreement addressing the future use of Rockport Unit 2 as a short-term capacity resource through the June 2023 - May 2024 PJM planning year. I&M has a similar proposal pending before the MPSC in I&M’s 2022 Michigan Integrated Resource Plan (IRP) filing. If I&M cannot recover its future investment and expenses related to the merchant share of Rockport Unit 2, it could reduce future net income and cash flows and impact financial condition. 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. On August 16, 2022, the district court granted the motion to dismiss the complaint without prejudice. The plaintiffs have filed a motion for leave to file an amended complaint. 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) 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 failed 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 court entered a scheduling order in the New York state court derivative action staying the case other than with respect to briefing the motion to dismiss. AEP filed its motion to dismiss on April 29, 2022. On September 13, 2022, the New York state court granted the motion to dismiss with prejudice and plaintiffs have filed a notice of appeal with the New York appellate court. The two derivative actions pending in federal district court in Ohio have been consolidated and the plaintiffs in the consolidated action filed an amended complaint. AEP filed a motion to dismiss on May 3, 2022 and briefing on the motion to dismiss has been completed. Discovery remains stayed pending the district court’s ruling on the motion to dismiss. The plaintiff in the Ohio state court case advised that they no longer agreed to stay the proceedings, therefore, AEP filed a motion to continue the stays of proceedings on May 20, 2022 and the plaintiff filed an amended complaint on June 2, 2022. On June 15, 2022, the Ohio state court entered an order continuing the stays of that case until the resolution of the consolidated derivative actions pending in Ohio federal district court. 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 since withdrawn the litigation demand, which is now terminated and of no further effect. In May 2021, AEP received a subpoena from the SEC’s Division of Enforcement seeking various documents, including documents relating to the passage of HB 6 and documents relating to AEP’s policies and financial processes and controls. In August 2022, AEP received a second subpoena from the SEC seeking various additional documents relating to its ongoing inquiry. AEP is cooperating fully with the SEC’s investigation. 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 financial condition, results of operations or cash flows.

Acquisitions and Dispositions

Acquisitions and Dispositions	9 Months Ended
Acquisitions and Dispositions	Sep. 30, 2022
Acquisitions and Dispositions	ACQUISITIONS, ASSETS AND LIABILITIES HELD FOR SALE, DISPOSITIONS AND IMPAIRMENTS The disclosures in this note apply to AEP unless indicated otherwise. ACQUISITIONS 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% 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. The nonaffiliated interest in Dry Lake is presented in Noncontrolling Interests on the balance sheets. Subsequent to close of the transaction, the noncontrolling interest made additional asset contributions of $16 million. As of September 30, 2022, AEP recognized approximately $143 million of Property, Plant and Equipment and approximately $34 million of Noncontrolling Interest on the balance sheets. 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 own undivided interests of 45.5% and 54.5% of the NCWF, respectively. In total, the three wind facilities cost approximately $2 billion and consist of Traverse (998 MW), Maverick (287 MW) and Sundance (199 MW). Output from the NCWF serves 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 through base rates was approved by the APSC in May 2022. 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. 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 March 2022, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Traverse during its development and construction for $1.2 billion, the third of the three NCWF acquisitions. Immediately following the acquisition, PSO and SWEPCo liquidated the entity and simultaneously distributed the Traverse assets in proportion to their undivided ownership interests. Traverse was placed in-service in March 2022. In accordance with the guidance for “Business Combinations,” management determined that the acquisitions of the NCWF projects represent asset acquisitions. As of September 30, 2022, PSO and SWEPCo had approximately $894 million and $1.1 billion, of gross Property, Plant and Equipment on the balance sheets, respectively, related to the 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 the NCWF projects. The respective Purchase and Sale Agreements (PSAs) include 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, Maverick and Traverse were built upon. The lessee interests in the land contracts were transferred to Sundance, Maverick and Traverse (and subsequently to PSO and SWEPCo) as a part of the closings of the respective PSAs. The current Obligations Under Operating Leases related to the NCWF projects were immaterial as of September 30, 2022 and December 31, 2021 for PSO and SWEPCo. See the table below for the noncurrent Obligations Under Operating Leases for the NCWF projects for PSO and SWEPCo: PSO SWEPCo September 30, 2022 December 31, 2021 September 30, 2022 December 31, 2021 (in millions) Project Sundance $ 12.6 $ 12.6 $ 15.0 $ 15.1 Maverick 18.0 18.0 21.6 21.6 Traverse 39.7 — 47.7 — Total $ 70.3 $ 30.6 $ 84.3 $ 36.7 ASSETS AND LIABILITIES HELD FOR SALE 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 (SPA) 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. In May 2022, the KPSC approved the transfer of KPCo to Liberty subject to certain conditions contingent upon the closing of the sale. AEP has received clearance under the Hart-Scott-Rodino Antitrust Improvements Act of 1976 and the Committee on Foreign Investment in the United States. The sale remains subject to FERC approval under Section 203 of the Federal Power Act. In September 2022, AEP, AEPTCo and Liberty entered into an amendment (Amendment) to the SPA which reduced the purchase price to approximately $2.646 billion and Liberty agreed to waive, upon FERC approval of the sale, the SPA condition precedent to closing requiring the issuance of regulatory orders approving a new proposed Mitchell Plant Operations and Maintenance Agreement and Mitchell Plant Ownership Agreement between KPCo and WPCo. The Amendment also provided that the closing shall not occur prior to January 4, 2023, unless mutually agreed to by AEP and Liberty. Mitchell Plant Operations and Maintenance Agreement and Ownership Agreement KPCo and WPCo each own a 50% undivided interest in the 1,560 MW coal-fired Mitchell Plant. As of September 30, 2022, the net book value of KPCo’s share of the Mitchell Plant, before cost of removal including CWIP and inventory, was $576 million. In November 2021, AEP made filings with the KPSC, WVPSC and FERC seeking approval of a new proposed Mitchell Plant Operations and Maintenance Agreement and Mitchell Plant Ownership Agreement. In February 2022, AEP filed a motion to withdraw its filing with the FERC. The KPSC and WVPSC issued orders addressing AEP’s filings in May 2022 and July 2022. Those orders proposed materially different modifications to the Mitchell Plant agreements filed by AEP such that the new agreements could not be executed by the parties. In lieu of new agreements, in July 2022, KPCo and WPCo confirmed with the KPSC and WVPSC, respectively, that they will continue operating under the existing Mitchell Agreement, utilizing the Mitchell Agreement Operating Committee’s authority under that agreement to issue appropriate resolutions so the parties can operate in accordance with each state commission’s directives related to CCR and ELG investment. In September 2022, pursuant to resolutions under the existing Mitchell Plant agreement, WPCo replaced KPCo as the Operator of Mitchell Plant. Transfer of Ownership FERC Proceedings In December 2021, Liberty, KPCo and KTCo requested FERC approval of the sale under Section 203 of the Federal Power Act. In February 2022, several intervenors in the case filed protests related to whether the sale will negatively impact the wholesale transmission rates of applicants. In April 2022, the FERC issued a deficiency letter stating that the Section 203 application is deficient and that additional information is required to process it. In May 2022, Liberty, KPCo and KTCo supplemented the application and in June 2022, the FERC issued an order formally notifying AEP that it was exercising its ability to take up to an additional 180 days to act on the application. An order from the FERC is expected in the fourth quarter of 2022. KPSC Proceedings In May 2022, the KPSC approved the transfer of KPCo to Liberty subject to conditions contingent upon the closing of the sale, including establishment of regulatory liabilities to subsidize retail customer transmission and distribution expenses, a fuel adjustment clause bill credit, and a three-year Big Sandy decommissioning rider rate holiday during which KPCo’s carrying charge is reduced by 50%. As a result of the conditions imposed by KPSC, in the second quarter of 2022, AEP recorded a $69 million loss on the expected sale of the Kentucky Operations in accordance with accounting guidance for Fair Value Measurement. Further, as a result of the Amendment and the change to the anticipated timing of the completion of the transaction, AEP recorded an additional $194 million pretax loss ($149 million net of tax) on the expected sale of the Kentucky Operations in the third quarter of 2022 in accordance with the accounting guidance for Fair Value Measurement. AEP recorded a $263 million pretax loss ($218 million net of tax) on the expected sale of the Kentucky Operations for the nine months ended September 30, 2022. AEP expects cash proceeds, net of taxes and transaction fees, from the sale of approximately $1.2 billion. Subject to receipt of FERC authorization under Section 203 of the Federal Power Act, the sale is expected to close in January 2023 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 plans to use the proceeds from the sale to fund its continued investment in regulated businesses, including transmission and regulated renewables projects. If additional reductions in the fair value of the Kentucky Operations occur, it would reduce future net income and cash flows. The Income Before Income Tax Expense (Benefit) of KPCo and KTCo were not material to AEP and AEPTCo on their respective statements of income for the three and nine months ended September 30, 2022 and 2021. 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 are shown in the table below: AEP AEPTCo September 30, 2022 December 31, 2021 September 30, 2022 December 31, 2021 (in millions) ASSETS Accounts Receivable and Accrued Unbilled Revenues $ 77.8 $ 33.2 $ 1.7 $ 1.5 Fuel, Materials and Supplies 36.7 30.6 — — Property, Plant and Equipment, Net 2,387.4 2,302.7 167.0 165.3 Regulatory Assets 508.6 484.7 — — Other Classes of Assets that are not Major 38.1 68.5 5.0 1.1 Total Major Classes of Assets Held for Sale 3,048.6 2,919.7 173.7 167.9 Loss on the Expected Sale of Kentucky Operations (net of $45 million of Income Taxes) (218.0) — — — Assets Held for Sale $ 2,830.6 $ 2,919.7 $ 173.7 $ 167.9 LIABILITIES Accounts Payable $ 62.4 $ 53.4 $ 0.7 $ 1.1 Long-term Debt Due Within One Year 215.0 200.0 — — Customer Deposits 38.0 32.4 — — Deferred Income Taxes 497.8 441.6 16.4 15.4 Long-term Debt 963.4 903.1 — — Regulatory Liabilities and Deferred Investment Tax Credits 138.1 148.1 8.0 7.6 Other Classes of Liabilities that are not Major 77.3 102.3 2.5 3.5 Liabilities Held for Sale $ 1,992.0 $ 1,880.9 $ 27.6 $ 27.6 DISPOSITIONS Disposition of Cardinal Plant (Generation & Marketing Segment) (Applies to AEP) In March 2022, AGR entered into an Asset Purchase agreement with a nonaffiliated electric cooperative to sell Cardinal Plant, Unit 1, a competitive generation asset totaling 595 MWs. The FERC approved the sale in May 2022 and the sale closed in the third quarter of 2022. The proceeds from the sale were not material. Concurrent with the closing of the sale, AGR executed a PPA with the nonaffiliated electric cooperative for rights to Unit 1’s power and capacity through 2028. AGR also retained certain obligations related to environmental remediation. Subsequent to the closing of the sale, AGR continues to recognize Cardinal Plant, Unit 1 on its balance sheet due to continuing involvement through the PPA. As of September 30, 2022, the net book value of Cardinal Plant, Unit 1 was not material. Disposition of Mineral Rights (Generation & Marketing Segment) (Applies to AEP) In June 2022, AEP closed on the sale of certain mineral rights to a nonaffiliated third-party and received $120 million of proceeds. The sale resulted in a pretax gain of $116 million in the second quarter of 2022. IMPAIRMENTS Flat Ridge 2 Wind 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. The acquisition included a 50% ownership interest in five non-consolidated joint ventures, including Flat Ridge 2 Wind LLC (Flat Ridge 2), and two tax equity partnerships. The five non-consolidated joint ventures are jointly owned and operated by BP Wind Energy. Flat Ridge 2 sells electricity to three counterparties through long-term PPAs.

Benefit Plans

Benefit Plans	9 Months Ended
Benefit Plans	Sep. 30, 2022
Benefit Plans	BENEFIT PLANS The disclosures in this note apply to all Registrants except AEPTCo. AEP sponsors a qualified pension plan and two unfunded nonqualified pension plans. Substantially all AEP employees are covered by the qualified plan or both the qualified and a nonqualified pension plan. AEP also sponsors OPEB plans to provide health and life insurance benefits for retired employees. 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 Three Months Ended September 30, Three Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 30.7 $ 32.3 $ 1.8 $ 2.4 Interest Cost 37.1 34.3 7.3 7.7 Expected Return on Plan Assets (63.4) (57.4) (27.5) (22.8) Amortization of Prior Service Credit — — (17.9) (17.8) Amortization of Net Actuarial Loss 15.8 25.3 — — Net Periodic Benefit Cost (Credit) $ 20.2 $ 34.5 $ (36.3) $ (30.5) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 92.3 $ 96.9 $ 5.5 $ 7.2 Interest Cost 111.2 102.9 21.9 22.9 Expected Return on Plan Assets (190.1) (172.3) (82.5) (68.4) Amortization of Prior Service Credit — — (53.6) (53.2) Amortization of Net Actuarial Loss 47.3 76.1 — — Net Periodic Benefit Cost (Credit) $ 60.7 $ 103.6 $ (108.7) $ (91.5) AEP Texas Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 2.8 $ 3.0 $ 0.1 $ 0.2 Interest Cost 3.1 2.8 0.6 0.6 Expected Return on Plan Assets (5.3) (4.9) (2.3) (1.9) Amortization of Prior Service Credit — — (1.5) (1.5) Amortization of Net Actuarial Loss 1.2 2.1 — — Net Periodic Benefit Cost (Credit) $ 1.8 $ 3.0 $ (3.1) $ (2.6) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 8.4 $ 8.9 $ 0.3 $ 0.5 Interest Cost 9.1 8.4 1.7 1.8 Expected Return on Plan Assets (15.8) (14.6) (6.8) (5.6) Amortization of Prior Service Credit — — (4.5) (4.5) Amortization of Net Actuarial Loss 3.8 6.2 — — Net Periodic Benefit Cost (Credit) $ 5.5 $ 8.9 $ (9.3) $ (7.8) APCo Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 2.9 $ 3.0 $ 0.2 $ 0.3 Interest Cost 4.3 4.1 1.2 1.3 Expected Return on Plan Assets (8.1) (7.3) (4.1) (3.4) Amortization of Prior Service Credit — — (2.6) (2.6) Amortization of Net Actuarial Loss 1.9 3.0 — — Net Periodic Benefit Cost (Credit) $ 1.0 $ 2.8 $ (5.3) $ (4.4) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 8.6 $ 8.9 $ 0.6 $ 0.8 Interest Cost 13.1 12.3 3.5 3.7 Expected Return on Plan Assets (24.3) (21.8) (12.2) (10.1) Amortization of Prior Service Credit — — (7.8) (7.8) Amortization of Net Actuarial Loss 5.5 9.0 — — Net Periodic Benefit Cost (Credit) $ 2.9 $ 8.4 $ (15.9) $ (13.4) I&M Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 4.0 $ 4.4 $ 0.2 $ 0.4 Interest Cost 4.3 4.0 0.8 0.8 Expected Return on Plan Assets (8.1) (7.2) (3.3) (2.7) Amortization of Prior Service Credit — — (2.4) (2.5) Amortization of Net Actuarial Loss 1.8 2.9 — — Net Periodic Benefit Cost (Credit) $ 2.0 $ 4.1 $ (4.7) $ (4.0) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 12.1 $ 13.1 $ 0.7 $ 1.0 Interest Cost 12.7 12.1 2.5 2.6 Expected Return on Plan Assets (24.2) (21.6) (10.2) (8.3) Amortization of Prior Service Credit — — (7.3) (7.3) Amortization of Net Actuarial Loss 5.3 8.8 — — Net Periodic Benefit Cost (Credit) $ 5.9 $ 12.4 $ (14.3) $ (12.0) OPCo Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 2.8 $ 2.9 $ 0.2 $ 0.2 Interest Cost 3.4 3.1 0.7 0.7 Expected Return on Plan Assets (6.2) (5.7) (3.0) (2.4) Amortization of Prior Service Credit — — (1.8) (1.7) Amortization of Net Actuarial Loss 1.3 2.3 — — Net Periodic Benefit Cost (Credit) $ 1.3 $ 2.6 $ (3.9) $ (3.2) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 8.4 $ 8.6 $ 0.5 $ 0.6 Interest Cost 10.0 9.3 2.2 2.3 Expected Return on Plan Assets (18.6) (16.8) (8.9) (7.3) Amortization of Prior Service Credit — — (5.4) (5.3) Amortization of Net Actuarial Loss 4.1 6.8 — — Net Periodic Benefit Cost (Credit) $ 3.9 $ 7.9 $ (11.6) $ (9.7) PSO Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 1.8 $ 2.0 $ 0.2 $ 0.1 Interest Cost 1.8 1.7 0.4 0.4 Expected Return on Plan Assets (3.3) (3.0) (1.6) (1.3) Amortization of Prior Service Credit — — (1.1) (1.1) Amortization of Net Actuarial Loss 0.7 1.2 — — Net Periodic Benefit Cost (Credit) $ 1.0 $ 1.9 $ (2.1) $ (1.9) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 5.5 $ 6.0 $ 0.4 $ 0.4 Interest Cost 5.3 5.0 1.1 1.2 Expected Return on Plan Assets (10.1) (9.2) (4.6) (3.8) Amortization of Prior Service Credit — — (3.3) (3.3) Amortization of Net Actuarial Loss 2.2 3.7 — — Net Periodic Benefit Cost (Credit) $ 2.9 $ 5.5 $ (6.4) $ (5.5) SWEPCo Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 2.7 $ 2.7 $ 0.1 $ 0.3 Interest Cost 2.2 2.2 0.5 0.4 Expected Return on Plan Assets (3.6) (3.3) (1.8) (1.5) Amortization of Prior Service Credit — — (1.4) (1.4) Amortization of Net Actuarial Loss 0.9 1.5 — — Net Periodic Benefit Cost (Credit) $ 2.2 $ 3.1 $ (2.6) $ (2.2) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 8.0 $ 8.4 $ 0.4 $ 0.6 Interest Cost 6.8 6.4 1.4 1.4 Expected Return on Plan Assets (10.9) (10.1) (5.5) (4.5) Amortization of Prior Service Credit — — (4.0) (4.0) Amortization of Net Actuarial Loss 2.8 4.6 — — Net Periodic Benefit Cost (Credit) $ 6.7 $ 9.3 $ (7.7) $ (6.5)

Business Segments

Business Segments	9 Months Ended
Business Segments	Sep. 30, 2022
Business Segments	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 ROEs. • Development, construction and operation of transmission facilities through investments in AEP’s transmission-only joint ventures. These investments have PUCT-approved or FERC-approved ROEs. Generation & Marketing • Contracted renewable energy investments and management services. • Marketing, risk management and retail activities in ERCOT, PJM, SPP and MISO. • Competitive generation in PJM. The remainder of AEP’s activities is 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, interest expense, income tax expense and other nonallocated costs. The tables below represent AEP’s reportable segment income statement information for the three and nine months ended September 30, 2022 and 2021 and reportable segment balance sheet information as of September 30, 2022 and December 31, 2021. Three Months Ended September 30, 2022 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) Revenues from: External Customers $ 3,174.6 $ 1,525.5 $ 81.9 $ 733.1 $ 11.0 $ — $ 5,526.1 Other Operating Segments 51.7 4.7 349.0 2.3 17.3 (425.0) — Total Revenues $ 3,226.3 $ 1,530.2 $ 430.9 $ 735.4 $ 28.3 $ (425.0) $ 5,526.1 Net Income (Loss) $ 476.9 $ 165.5 $ 171.4 $ 96.2 $ (226.7) $ — $ 683.3 Three Months Ended September 30, 2021 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) Revenues from: External Customers $ 2,716.8 $ 1,195.0 $ 90.3 $ 617.4 $ 3.5 $ — $ 4,623.0 Other Operating Segments 42.5 5.3 301.3 3.7 23.2 (376.0) — Total Revenues $ 2,759.3 $ 1,200.3 $ 391.6 $ 621.1 $ 26.7 $ (376.0) $ 4,623.0 Net Income (Loss) $ 438.7 $ 155.9 $ 167.9 $ 99.5 $ (65.1) $ — $ 796.9 Nine Months Ended September 30, 2022 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) Revenues from: External Customers $ 8,416.4 $ 4,064.5 $ 244.4 $ 1,997.0 $ 36.1 $ — $ 14,758.4 Other Operating Segments 145.8 14.1 976.7 17.3 36.6 (1,190.5) — Total Revenues $ 8,562.2 $ 4,078.6 $ 1,221.1 $ 2,014.3 $ 72.7 $ (1,190.5) $ 14,758.4 Net Income (Loss) $ 1,079.4 $ 483.1 $ 487.8 $ 278.1 $ (406.2) $ — $ 1,922.2 Nine Months Ended September 30, 2021 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) Revenues from: External Customers $ 7,445.9 $ 3,366.9 $ 264.6 $ 1,641.6 $ 11.6 $ — $ 12,730.6 Other Operating Segments 111.3 24.9 882.2 50.3 43.5 (1,112.2) — Total Revenues $ 7,557.2 $ 3,391.8 $ 1,146.8 $ 1,691.9 $ 55.1 $ (1,112.2) $ 12,730.6 Net Income (Loss) $ 938.9 $ 424.0 $ 510.7 $ 184.2 $ (108.3) $ — $ 1,949.5 September 30, 2022 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Consolidated (in millions) Total Assets (d) $ 49,056.9 $ 22,139.7 $ 14,708.9 $ 5,376.3 $ 6,278.3 (b) $ (6,310.7) (c) $ 91,249.4 December 31, 2021 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Consolidated (in millions) Total Assets (d) $ 46,974.2 $ 21,120.2 $ 13,873.3 $ 4,263.6 $ 5,846.5 (b) $ (4,409.1) (c) $ 87,668.7 (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) Amount includes Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 6 for additional information. 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 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 three and nine months ended September 30, 2022 and 2021 and reportable segment balance sheet information as of September 30, 2022 and December 31, 2021. Three Months Ended September 30, 2022 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Revenues from: External Customers $ 87.2 $ — $ — $ 87.2 Sales to AEP Affiliates 331.3 — — 331.3 Total Revenues $ 418.5 $ — $ — $ 418.5 Net Income $ 152.6 $ 0.1 (a) $ — $ 152.7 Three Months Ended September 30, 2021 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Revenues from: External Customers $ 79.2 $ — $ — $ 79.2 Sales to AEP Affiliates 297.6 — — 297.6 Other Revenues 0.2 — — 0.2 Total Revenues $ 377.0 $ — $ — $ 377.0 Net Income $ 145.3 $ 0.1 (a) $ — $ 145.4 Nine Months Ended September 30, 2022 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo Consolidated (in millions) Revenues from: External Customers $ 249.5 $ — $ — $ 249.5 Sales to AEP Affiliates 933.8 — — 933.8 Total Revenues $ 1,183.3 $ — $ — $ 1,183.3 Net Income $ 426.4 $ 0.2 (a) $ — $ 426.6 Nine Months Ended September 30, 2021 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo Consolidated (in millions) Revenues from: External Customers $ 239.3 $ — $ — $ 239.3 Sales to AEP Affiliates 864.6 — — 864.6 Other Revenues 0.3 — — 0.3 Total Revenues $ 1,104.2 $ — $ — $ 1,104.2 Net Income $ 445.5 $ 0.2 (a) $ — $ 445.7 September 30, 2022 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Total Assets (d) $ 13,359.9 $ 4,972.4 (b) $ (5,013.1) (c) $ 13,319.2 December 31, 2021 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Total Assets (d) $ 12,564.3 $ 4,389.5 (b) $ (4,429.4) (c) $ 12,524.4 (a) Includes the elimination of AEPTCo Parent’s equity earnings in the State Transcos. (b) Includes the elimination of AEPTCo Parent’s investments in State Transcos. (c) Primarily relates to the elimination of Notes Receivable from the State Transcos. (d) Amount includes Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.

Derivatives and Hedging

Derivatives and Hedging	9 Months Ended
Derivatives and Hedging	Sep. 30, 2022
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: Notional Volume of Derivative Instruments September 30, 2022 Primary Risk Unit of AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power MWhs 260.6 — 29.0 6.2 2.6 5.7 4.3 Natural Gas MMBtus 80.3 — — — — — 1.8 Heating Oil and Gasoline Gallons 6.4 1.7 0.9 0.6 1.3 0.7 0.9 Interest Rate USD $ 99.9 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt USD $ 1,150.0 $ — $ — $ — $ — $ — $ — 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 $ — $ — $ — $ — $ — $ — 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 $847 million and $263 million as of September 30, 2022 and December 31, 2021, respectively. AEP netted cash collateral paid to third-parties against short-term and long-term risk management liabilities in the amounts of $0 and $3 million as of September 30, 2022 and December 31, 2021, 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 September 30, 2022 and December 31, 2021. The following tables represent the gross fair value of the Registrants’ derivative activity on the balance sheets. Unless shown as a separate line on the balance sheets due to materiality, Current Risk Management Assets are included in Prepayments and Other Current Assets, Long-term Risk Management Assets are included in Deferred Charges and Other Noncurrent Assets, Current Risk Management Liabilities are included in Other Current Liabilities and Long-term Risk Management Liabilities are included in Deferred Credits and Other Noncurrent Liabilities on the balance sheets. AEP September 30, 2022 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) $ 1,482.1 $ 411.1 $ 8.8 $ 1,902.0 $ (1,331.8) $ 570.2 Long-term Risk Management Assets 686.6 177.4 — 864.0 (598.2) 265.8 Total Assets 2,168.7 588.5 8.8 2,766.0 (1,930.0) 836.0 Current Risk Management Liabilities (e) 1,005.7 10.9 21.3 1,037.9 (850.6) 187.3 Long-term Risk Management Liabilities 501.6 4.9 114.1 620.6 (232.4) 388.2 Total Liabilities 1,507.3 15.8 135.4 1,658.5 (1,083.0) 575.5 Total MTM Derivative Contract Net Assets (Liabilities) (f) $ 661.4 $ 572.7 $ (126.6) $ 1,107.5 $ (847.0) $ 260.5 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 AEP Texas September 30, 2022 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 0.1 $ 0.1 $ 0.2 Long-term Risk Management Assets (0.1) 0.2 0.1 Total Assets — 0.3 0.3 Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — 0.1 0.1 Total Liabilities — 0.1 0.1 Total MTM Derivative Contract Net Assets $ — $ 0.2 $ 0.2 December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) 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 Contract Net Assets (Liabilities) $ 0.6 $ (0.6) $ — APCo September 30, 2022 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 106.8 $ — $ 106.8 Long-term Risk Management Assets 0.7 (0.6) 0.1 Total Assets 107.5 (0.6) 106.9 Current Risk Management Liabilities — — — Long-term Risk Management Liabilities 0.7 (0.7) — Total Liabilities 0.7 (0.7) — Total MTM Derivative Contract Net Assets (f) $ 106.8 $ 0.1 $ 106.9 December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 47.5 $ (5.5) $ 42.0 Long-term Risk Management Assets 0.2 (0.2) — Total Assets 47.7 (5.7) 42.0 Current Risk Management Liabilities 7.2 (6.4) 0.8 Long-term Risk Management Liabilities 0.2 (0.2) — Total Liabilities 7.4 (6.6) 0.8 Total MTM Derivative Contract Net Assets $ 40.3 $ 0.9 $ 41.2 I&M September 30, 2022 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 12.3 $ (0.9) $ 11.4 Long-term Risk Management Assets 0.6 (0.4) 0.2 Total Assets 12.9 (1.3) 11.6 Current Risk Management Liabilities 0.9 (0.9) — Long-term Risk Management Liabilities 0.5 (0.5) — Total Liabilities 1.4 (1.4) — Total MTM Derivative Contract Net Assets (f) $ 11.5 $ 0.1 $ 11.6 December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 11.1 $ (7.8) $ 3.3 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 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) OPCo September 30, 2022 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 2.0 $ 0.1 $ 2.1 Long-term Risk Management Assets (0.1) 0.1 — Total Assets 1.9 0.2 2.1 Current Risk Management Liabilities — — — Long-term Risk Management Liabilities 45.1 — 45.1 Total Liabilities 45.1 — 45.1 Total MTM Derivative Contract Net Assets (Liabilities) (f) $ (43.2) $ 0.2 $ (43.0) December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) 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) PSO September 30, 2022 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 44.4 $ 0.1 $ 44.5 Long-term Risk Management Assets — — — Total Assets 44.4 0.1 44.5 Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — — — Total Liabilities — — — Total MTM Derivative Contract Net Assets (f) $ 44.4 $ 0.1 $ 44.5 December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) 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 Contract Net Assets (Liabilities) $ 8.7 $ (0.3) $ 8.4 SWEPCo September 30, 2022 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 37.2 $ (0.8) $ 36.4 Long-term Risk Management Assets — 0.1 0.1 Total Assets 37.2 (0.7) 36.5 Current Risk Management Liabilities 0.8 (0.8) — Long-term Risk Management Liabilities — — — Total Liabilities 0.8 (0.8) — Total MTM Derivative Contract Net Assets (f) $ 36.4 $ 0.1 $ 36.5 December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 10.1 $ (0.3) $ 9.8 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 Long-term Risk Management Liabilities — — — Total Liabilities 2.1 — 2.1 Total MTM Derivative Contract Net Assets (Liabilities) $ 9.1 $ (0.3) $ 8.8 (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 $14.4 million and $6 million as of September 30, 2022 and December 31, 2021, respectively, classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 for additional information. (e) Amount excludes Risk Management Liabilities of $0 and $0.1 million as of September 30, 2022 and December 31, 2021, respectively, classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 for additional information. (f) Increase in amounts as of September 30, 2022 are primarily due to increases in commodity prices for power and natural gas and an increase in value of FTRs. The tables below present the Registrants’ amount of gain (loss) recognized on risk management contracts: Amount of Gain (Loss) Recognized on Risk Management Contracts Three Months Ended September 30, 2022 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 2.1 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 116.7 — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.3 — — — — Other Revenues - Nonaffiliated — — — 1.9 — — — Purchased Electricity for Resale 0.9 — 0.9 0.1 — — — Other Operation 1.4 0.4 0.1 0.1 0.2 0.2 0.2 Maintenance 2.0 0.5 0.2 0.2 0.4 0.2 0.3 Regulatory Assets (a) 4.3 — — 0.1 4.1 — 0.1 Regulatory Liabilities (a) 103.2 (1.5) 59.7 3.8 0.9 19.7 7.0 Total Gain (Loss) on Risk Management Contracts (b) $ 230.6 $ (0.6) $ 61.2 $ 6.2 $ 5.6 $ 20.1 $ 7.6 Three Months Ended September 30, 2021 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ (0.9) $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 128.8 — — — — — — Electric Generation, Transmission and Distribution Revenues — — (0.9) — — — — Purchased Electricity for Resale 0.2 — 0.1 — — — — Other Operation 0.9 0.3 0.1 0.1 0.1 0.1 0.2 Maintenance 1.1 0.2 0.2 0.1 0.2 0.1 0.1 Regulatory Assets (a) (7.2) — (2.9) (16.9) 14.9 — 0.1 Regulatory Liabilities (a) 46.5 (0.1) 14.2 1.7 0.8 14.0 12.7 Total Gain (Loss) on Risk Management Contracts $ 169.4 $ 0.4 $ 10.8 $ (15.0) $ 16.0 $ 14.2 $ 13.1 Nine Months Ended September 30, 2022 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 2.2 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 390.0 — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.4 (0.1) — — — Other Revenues - Nonaffiliated — — — 1.9 — — — Purchased Electricity for Resale 3.3 — 3.0 0.1 — 0.1 — Other Operation 3.7 1.1 0.3 0.4 0.6 0.5 0.6 Maintenance 5.2 1.4 0.7 0.5 0.9 0.6 0.8 Regulatory Assets (a) 49.3 0.1 — (1.2) 49.0 3.6 (2.1) Regulatory Liabilities (a) 250.1 (0.6) 79.9 7.0 2.5 71.4 64.8 Total Gain on Risk Management Contracts (b) $ 703.8 $ 2.0 $ 84.3 $ 8.6 $ 53.0 $ 76.2 $ 64.1 Nine Months Ended September 30, 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 144.9 — — — — — — Electric Generation, Transmission and Distribution Revenues — — (0.6) — — — — Purchased Electricity for Resale 1.2 — 1.0 0.1 — — — Other Operation 1.9 0.6 0.2 0.2 0.3 0.2 0.3 Maintenance 2.4 0.6 0.4 0.2 0.4 0.2 0.3 Regulatory Assets (a) (7.9) — (2.9) (22.9) 20.3 — 1.4 Regulatory Liabilities (a) 123.6 0.5 28.9 1.9 5.9 40.2 38.5 Total Gain (Loss) on Risk Management Contracts $ 265.5 $ 1.7 $ 27.0 $ (20.5) $ 26.9 $ 40.6 $ 40.5 (a) Represents realized and unrealized gains and losses subject to regulatory accounting treatment recorded as either current or noncurrent on the balance sheets. (b) Increase in amounts for the three and nine months ended September 30, 2022 are primarily due to increases in commodity prices for power and natural gas and an increase in value of FTRs. 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 Liabilities Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of the Hedged Liabilities September 30, 2022 December 31, 2021 September 30, 2022 December 31, 2021 (in millions) Long-term Debt (a) (b) $ (849.1) $ (952.3) $ 95.7 $ (8.5) (a) Amounts included on the Balance Sheet within Current and Noncurrent Liabilities line items Long-term Debt Due within One Year and Long-term Debt, respectively. (b) Amounts include $(40) million and $(46) million as of September 30, 2022 and December 31, 2021, 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: Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (in millions) Gain (Loss) on Interest Rate Contracts: Fair Value Hedging Instruments (a) $ (36.0) $ (0.1) $ (98.4) $ (23.8) Fair Value Portion of Long-term Debt (a) 36.0 0.1 98.4 23.8 (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 statements 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, AEP Texas, APCo, I&M 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 three and nine months ended September 30, 2022 and 2021, 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 three and nine months ended September 30, 2022, AEP applied cash flow hedging to outstanding interest rate derivatives and the Registrant Subsidiaries did not. During the three months ended September 30, 2021, AEP applied cash flow hedging to outstanding interest rate derivatives and the Registrant Subsidiaries did not. During the nine months ended September 30, 2021, AEP and APCo applied cash flow hedging to outstanding interest rate derivatives and the other Registrant Subsidiaries did not. 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 September 30, 2022 December 31, 2021 Commodity Interest Rate Commodity Interest Rate (in millions) AOCI Gain (Loss) Net of Tax $ 452.1 $ (2.6) $ 163.7 $ (21.3) Portion Expected to be Reclassed to Net Income During the Next Twelve Months 316.2 (1.5) 106.7 (3.3) As of September 30, 2022 the maximum length of time that AEP is hedging its exposure to variability in future cash flows related to forecasted transactions is 102 months and 99 months for commodity and interest rate hedges, respectively. Impact of Cash Flow Hedges on the Registrant Subsidiaries’ Balance Sheets September 30, 2022 December 31, 2021 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 $ (0.5) $ (0.4) $ (1.3) $ (1.1) APCo 6.9 0.8 7.5 0.8 I&M (5.5) (1.0) (6.7) (1.6) SWEPCo 1.2 0.2 1.2 0.1 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 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. Credit-Risk-Related Contingent Features 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 with a total exposure of $10 million and $9 million as of September 30, 2022 and December 31, 2021, respectively. The Registrant Subsidiaries had no derivative contracts with collateral triggering events in a net liability position as of September 30, 2022 and December 31, 2021. Cross-Acceleration Triggers Certain interest rate derivative contracts contain cross-acceleration provisions that, if triggered, would permit the counterparty to declare a default and require settlement of the outstanding payable. These cross-acceleration provisions could be triggered if there was a non-performance event by the Registrants under any of their outstanding debt of at least $50 million and the lender on that debt has accelerated the entire repayment obligation. On an ongoing basis, AEP’s risk management organization assesses the appropriateness of these cross-acceleration provisions in contracts. AEP had derivative contracts with cross-acceleration provisions in a net liability position of $135 million and $40 million as of September 30, 2022 and December 31, 2021, respectively. There was no cash collateral posted as of September 30, 2022 and December 31, 2021, respectively. If a cross-acceleration provision would have been triggered, settlement at fair value would have been required. The Registrant Subsidiaries had no derivative contracts with cross-acceleration provisions outstanding as of September 30, 2022 and December 31, 2021. 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. AEP had de

Fair Value Measurements

Fair Value Measurements	9 Months Ended
Fair Value Measurements	Sep. 30, 2022
Fair Value Measurements	FAIR VALUE MEASUREMENTS The disclosures in this note apply to all Registrants except AEPTCo unless indicated otherwise. Fair Value Hierarchy and Valuation Techniques 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 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 nuclear trusts, cash and cash equivalents, other temporary investments 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. 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: September 30, 2022 December 31, 2021 Company Book Value Fair Value Book Value Fair Value (in millions) AEP (a)(b)(c) $ 35,050.1 $ 30,352.7 $ 33,454.5 $ 37,564.7 AEP Texas 5,693.9 4,889.7 5,180.8 5,663.8 AEPTCo 4,886.6 3,926.3 4,343.9 4,968.2 APCo 5,509.8 4,994.1 4,938.9 6,037.1 I&M 3,206.7 2,846.2 3,195.0 3,748.0 OPCo 2,969.9 2,442.0 2,968.5 3,437.5 PSO 1,913.6 1,616.9 1,913.5 2,163.7 SWEPCo 3,392.4 2,797.3 3,395.2 3,792.9 (a) The fair value amounts include debt related to AEP’s Equity Units and had a fair value of $842 million and $1.7 billion as of September 30, 2022 and December 31, 2021, respectively. See “Equity Units” section of Note 12 for additional information. (b) The book value amounts exclude Long-term Debt of $1.2 billion and $1.1 billion as of September 30, 2022 and December 31, 2021, respectively, classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 for additional information. (c) The fair value amounts exclude Long-term Debt of $1.1 billion and $1.2 billion as of September 30, 2022 and December 31, 2021, respectively, related to KPCo. See “Disposition of KPCo and KTCo” section of Note 6 for additional information. Fair Value Measurements of Other Temporary Investments and Restricted Cash (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. The following is a summary of Other Temporary Investments and Restricted Cash: September 30, 2022 Gross Gross Unrealized Unrealized Fair Other Temporary Investments and Restricted Cash Cost Gains Losses Value (in millions) Restricted Cash (a) $ 55.1 $ — $ — $ 55.1 Other Cash Deposits 18.1 — — 18.1 Fixed Income Securities – Mutual Funds (b) 155.1 — (9.7) 145.4 Equity Securities – Mutual Funds 20.4 18.6 (0.3) 38.7 Total Other Temporary Investments and Restricted Cash $ 248.7 $ 18.6 $ (10.0) $ 257.3 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 (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: Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (in millions) Proceeds from Investment Sales $ — $ 6.0 $ 15.0 $ 15.1 Purchases of Investments 11.8 12.9 13.4 26.0 Gross Realized Gains on Investment Sales — 2.4 3.6 3.6 Gross Realized Losses on Investment Sales — — 0.5 — Fair Value Measurements of Trust Assets for Decommissioning and SNF Disposal (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. The following is a summary of nuclear trust fund investments: September 30, 2022 December 31, 2021 Gross Other-Than- Gross Other-Than- Fair Unrealized Temporary Fair Unrealized Temporary Value Gains Impairments Value Gains Impairments (in millions) Cash and Cash Equivalents $ 20.8 $ — $ — $ 84.7 $ — $ — Fixed Income Securities: United States Government 1,115.2 (26.2) (39.8) 1,156.4 66.3 (7.9) Corporate Debt 60.9 (7.7) (1.2) 76.7 6.7 (2.1) State and Local Government 7.0 — (0.1) 7.3 0.4 (0.1) Subtotal Fixed Income Securities 1,183.1 (33.9) (41.1) 1,240.4 73.4 (10.1) Equity Securities - Domestic (a) 1,926.6 1,279.1 — 2,541.9 1,901.3 — Spent Nuclear Fuel and Decommissioning Trusts $ 3,130.5 $ 1,245.2 $ (41.1) $ 3,867.0 $ 1,974.7 $ (10.1) (a) Amount reported as Gross Unrealized Gains includes unrealized gains of $1.3 billion and $1.9 billion and unrealized losses of $14 million and $4 million as of September 30, 2022 and December 31, 2021, respectively. The following table provides the securities activity within the decommissioning and SNF trusts: Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (in millions) Proceeds from Investment Sales $ 588.5 $ 433.9 $ 1,818.4 $ 1,556.6 Purchases of Investments 601.6 436.6 1,854.8 1,586.3 Gross Realized Gains on Investment Sales 24.6 9.6 41.3 98.3 Gross Realized Losses on Investment Sales 8.4 7.0 33.5 12.5 The base cost of fixed income securities was $1.2 billion and $1.2 billion as of September 30, 2022 and December 31, 2021, respectively. The base cost of equity securities was $647 million and $641 million as of September 30, 2022 and December 31, 2021, respectively. The fair value of fixed income securities held in the nuclear trust funds, summarized by contractual maturities, as of September 30, 2022 was as follows: Fair Value of Fixed Income Securities (in millions) Within 1 year $ 369.4 After 1 year through 5 years 393.8 After 5 years through 10 years 229.0 After 10 years 190.9 Total $ 1,183.1 Fair Value Measurements of Financial Assets and Liabilities 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 Assets and Liabilities Measured at Fair Value on a Recurring Basis September 30, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments and Restricted Cash Restricted Cash $ 55.1 $ — $ — $ — $ 55.1 Other Cash Deposits (a) — — — 18.1 18.1 Fixed Income Securities – Mutual Funds 145.4 — — — 145.4 Equity Securities – Mutual Funds (b) 38.7 — — — 38.7 Total Other Temporary Investments and Restricted Cash 239.2 — — 18.1 257.3 Risk Management Assets Risk Management Commodity Contracts (c) (d) (i) 31.7 1,650.1 467.7 (1,910.8) 238.7 Cash Flow Hedges: Commodity Hedges (c) — 612.1 45.3 (68.9) 588.5 Interest Rate Hedges — 9.3 — (0.5) 8.8 Total Risk Management Assets 31.7 2,271.5 513.0 (1,980.2) 836.0 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 10.4 — — 10.4 20.8 Fixed Income Securities: United States Government — 1,115.2 — — 1,115.2 Corporate Debt — 60.9 — — 60.9 State and Local Government — 7.0 — — 7.0 Subtotal Fixed Income Securities — 1,183.1 — — 1,183.1 Equity Securities – Domestic (b) 1,926.6 — — — 1,926.6 Total Spent Nuclear Fuel and Decommissioning Trusts 1,937.0 1,183.1 — 10.4 3,130.5 Total Assets $ 2,207.9 $ 3,454.6 $ 513.0 $ (1,951.7) $ 4,223.8 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (d) (j) $ 20.1 $ 1,227.7 $ 240.5 $ (1,063.9) $ 424.4 Cash Flow Hedges: Commodity Hedges (c) — 83.7 0.9 (68.9) 15.7 Interest Rate Hedges — 0.5 — (0.5) — Fair Value Hedges — 135.4 — — 135.4 Total Risk Management Liabilities $ 20.1 $ 1,447.3 $ 241.4 $ (1,133.3) $ 575.5 AEP Assets and Liabilities Measured at Fair Value on a Recurring Basis 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) (f) (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) (f) (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 Texas Assets and Liabilities Measured at Fair Value on a Recurring Basis September 30, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 47.7 $ — $ — $ — $ 47.7 Risk Management Assets Risk Management Commodity Contracts (c) — 0.1 — 0.2 0.3 Total Assets $ 47.7 $ 0.1 $ — $ 0.2 $ 48.0 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 0.1 $ — $ — $ 0.1 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 APCo Assets and Liabilities Measured at Fair Value on a Recurring Basis September 30, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 7.4 $ — $ — $ — $ 7.4 Risk Management Assets Risk Management Commodity Contracts (c) (g) — 0.9 106.7 (0.8) 106.8 Total Assets $ 7.4 $ 0.9 $ 106.7 $ (0.8) $ 114.2 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 0.7 $ 0.1 $ (0.8) $ — 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 I&M Assets and Liabilities Measured at Fair Value on a Recurring Basis September 30, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 2.4 $ 10.3 $ (1.1) $ 11.6 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 10.4 — — 10.4 20.8 Fixed Income Securities: United States Government — 1,115.2 — — 1,115.2 Corporate Debt — 60.9 — — 60.9 State and Local Government — 7.0 — — 7.0 Subtotal Fixed Income Securities — 1,183.1 — — 1,183.1 Equity Securities - Domestic (b) 1,926.6 — — — 1,926.6 Total Spent Nuclear Fuel and Decommissioning Trusts 1,937.0 1,183.1 — 10.4 3,130.5 Total Assets $ 1,937.0 $ 1,185.5 $ 10.3 $ 9.3 $ 3,142.1 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 0.5 $ 0.7 $ (1.2) $ — 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 OPCo Assets and Liabilities Measured at Fair Value on a Recurring Basis September 30, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.1 $ — $ 2.0 $ 2.1 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 0.1 $ 43.2 $ 1.8 $ 45.1 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 (g) $ — $ — $ 92.5 $ — $ 92.5 PSO Assets and Liabilities Measured at Fair Value on a Recurring Basis September 30, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ — $ 45.2 $ (0.7) $ 44.5 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 0.8 $ (0.8) $ — 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 SWEPCo Assets and Liabilities Measured at Fair Value on a Recurring Basis September 30, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.1 $ 37.0 $ (0.7) $ 36.4 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 0.8 $ (0.8) $ — 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 (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 September 30, 2022 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $2 million in 2022 and $9 million in periods 2023-2025; Level 2 matures $47 million in 2022, $363 million in periods 2023-2025, $10 million in periods 2026-2027 and $3 million in periods 2028-2033; Level 3 matures $87 million in 2022, $139 million in periods 2023-2025, $18 million in periods 2026-2027 and $(2) 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, 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. (g) Substantially comprised of power contracts for the Registrant Subsidiaries. (h) See “Warrants Held in Investee” section of Note 10 in the 2021 Annual Report for additional information. (i) Amount excludes Risk Management Assets of $14.4 million and $6 million as of September 30, 2022 and December 31, 2021, respectively, classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 for additional information. (j) Amount excludes Risk Management Liabilities of $0 and $0.1 million as of September 30, 2022 and December 31, 2021, respectively, classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 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: Three Months Ended September 30, 2022 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of June 30, 2022 $ 270.4 $ 79.6 $ 9.8 $ (48.4) $ 64.5 $ 45.4 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 64.3 20.1 2.1 0.3 23.8 15.4 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (12.6) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 13.1 — — — — — Settlements (138.3) (34.6) (4.8) (1.1) (49.1) (31.6) Transfers into Level 3 (d) (e) (0.5) — — — — — Transfers out of Level 3 (e) 3.5 — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 72.5 41.5 2.5 6.0 5.2 7.0 Assets and Liabilities Held for Sale related to KPCo (g) (0.8) — — — — — Balance as of September 30, 2022 $ 271.6 $ 106.6 $ 9.6 $ (43.2) $ 44.4 $ 36.2 Three Months Ended September 30, 2021 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of June 30, 2021 $ 101.2 $ 36.6 $ 7.3 $ (105.4) $ 22.9 $ 14.6 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 27.5 4.0 0.1 0.1 13.5 5.8 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) 2.9 — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 17.8 — — — — — Settlements (54.5) (10.5) (3.8) 0.9 (20.6) (9.8) Transfers into Level 3 (d) (e) (5.8) — — — — — Transfers out of Level 3 (e) (4.1) 0.1 — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 44.0 15.7 (0.3) 14.0 2.7 9.0 Balance as of September 30, 2021 $ 129.0 $ 45.9 $ 3.3 $ (90.4) $ 18.5 $ 19.6 Nine Months Ended September 30, 2022 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of December 31, 2021 $ 97.3 $ 41.7 $ (0.7) $ (92.5) $ 12.1 $ 10.9 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 69.3 3.0 3.7 4.6 24.2 35.8 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (44.6) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 29.4 — — — — — Settlements (153.8) (44.7) (3.0) 0.2 (36.3) (45.0) Transfers into Level 3 (d) (e) 1.7 — — — — — Transfers out of Level 3 (e) 13.2 — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 267.6 106.6 9.6 44.5 44.4 34.5 Assets and Liabilities Held for Sale related to KPCo (g) (8.5) — — — — — Balance as of September 30, 2022 $ 271.6 $ 106.6 $ 9.6 $ (43.2) $ 44.4 $ 36.2 Nine Months Ended September 30, 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) 68.9 38.8 0.4 0.4 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) (64.1) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 35.5 — — — — — Settlements (113.3) (58.2) (2.5) 5.8 (26.4) (13.0) Transfers into Level 3 (d) (e) (0.2) — — — — — Transfers out of Level 3 (e) (26.2) — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 115.1 46.0 3.3 13.7 18.5 21.5 Balance as of September 30, 2021 $ 129.0 $ 45.9 $ 3.3 $ (90.4) $ 18.5 $ 19.6 (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 represents Risk Management Assets classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 for additional information. The following tables quantify the significant unobservable inputs used in developing the fair value of Level 3 positions: AEP Significant Unobservable Inputs September 30, 2022 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (c) (in millions) Energy Contracts $ 292.7 $ 230.6 Discounted Cash Flow Forward Market Price (a) $ (4.31) $ 172.05 $ 49.58 Natural Gas Contracts 6.9 — Discounted Cash Flow Forward Market Price (b) 3.22 7.37 5.92 FTRs (d) (e) 213.4 10.8 Discounted Cash Flow Forward Market Price (a) (37.97) 27.55 0.99 Total $ 513.0 $ 241.4 December 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (c) (in millions) Energy Contracts (f) $ 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 (g) (h) 77.5 13.0 Discounted Cash Flow Forward Market Price (a) (23.93) 26.38 0.86 Total $ 245.5 $ 148.2 APCo Significant Unobservable Inputs September 30, 2022 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) FTRs $ 106.7 $ 0.1 Discounted Cash Flow Forward Market Price $ (2.01) $ 20.64 $ 3.75 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 I&M Significant Unobservable Inputs September 30, 2022 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) FTRs $ 10.3 $ 0.7 Discounted Cash Flow Forward Market Price $ 0.21 $ 17.73 $ 1.61 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 OPCo Significant Unobservable Inputs September 30, 2022 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ — $ 43.2 Discounted Cash Flow Forward Market Price $ 1.65 $ 143.38 $ 47.12 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 PSO Significant Unobservable Inputs September 30, 2022 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) FTRs $ 45.2 $ 0.8 Discounted Cash Flow Forward Market Price $ (36.83) $ 5.65 $ (7.55) 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) SWEPCo Significant Unobservable Inputs September 30,

Income Taxes

Income Taxes	9 Months Ended
Income Taxes	Sep. 30, 2022
Income Taxes	INCOME TAXES The disclosures in this note apply to all Registrants unless indicated otherwise. Effective Tax Rates (ETR) The Registrants’ interim ETR reflect the estimated annual ETR for 2022 and 2021, adjusted for tax expense associated with certain discrete items. The Registrants include the amortization of Excess ADIT not subject to normalization requirements in the annual estimated ETR when regulatory proceedings instruct the Registrants to provide the benefits of Tax Reform to customers over multiple interim periods. Certain regulatory proceedings instruct the Registrants to provide the benefits of Tax Reform to customers in a single period (e.g. by applying the Excess ADIT not subject to normalization requirements against an existing regulatory asset balance) and in these circumstances, the Registrants recognize the tax benefit discretely in the period recorded. The annual amount of Excess ADIT approved by the Registrant’s regulatory commissions may not impact the ETR ratably during each interim period due to the variability of pretax book income between interim periods and the application of an annual estimated ETR. The ETR for each of the Registrants are included in the following tables: Three Months Ended September 30, 2022 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo U.S. Federal Statutory Rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % Increase (decrease) due to: State Income Tax, net of Federal Benefit (0.8) % 0.5 % 2.6 % (6.2) % 2.7 % 0.7 % 3.0 % (5.3) % Tax Reform Excess ADIT Reversal (9.7) % (2.0) % 0.3 % (8.6) % (13.3) % (6.2) % (21.9) % (4.6) % Production and Investment Tax Credits (12.0) % (0.4) % — % — % — % — % (43.7) % (24.1) % Flow Through (0.3) % 0.2 % 0.3 % (0.7) % (1.5) % 0.4 % 0.4 % (1.3) % AFUDC Equity (1.4) % (1.2) % (1.9) % (0.4) % (0.6) % (0.8) % (0.4) % (0.2) % Discrete Tax Adjustments (0.2) % — % — % — % — % — % — % — % Other 1.0 % 0.2 % 0.2 % — % (0.5) % 0.2 % 0.2 % (0.2) % Effective Income Tax Rate (2.4) % 18.3 % 22.5 % 5.1 % 7.8 % 15.3 % (41.4) % (14.7) % Three Months Ended September 30, 2021 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo U.S. Federal Statutory Rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % Increase (decrease) due to: State Income Tax, net of Federal Benefit 0.6 % 0.3 % 3.0 % (0.3) % 1.9 % 1.2 % 5.0 % (6.9) % Tax Reform Excess ADIT Reversal (8.5) % (6.3) % 0.3 % (14.2) % (16.1) % (8.9) % (19.8) % (4.2) % Production and Investment Tax Credits (4.7) % (0.3) % — % (0.2) % (2.0) % — % (8.9) % (5.4) % Flow Through — % 0.3 % 0.3 % 0.4 % (2.8) % 0.6 % 0.7 % (0.2) % AFUDC Equity (1.2) % (1.0) % (2.2) % (1.8) % (1.0) % (0.3) % (0.2) % (0.5) % Parent Company Loss Benefit — % (1.1) % (2.3) % (1.2) % (3.6) % — % — % 0.7 % Discrete Tax Adjustments 0.2 % — % — % — % — % — % — % 1.2 % Other 0.7 % (0.1) % 0.1 % 0.3 % 0.8 % — % (0.1) % (0.2) % Effective Income Tax Rate 8.1 % 12.8 % 20.2 % 4.0 % (1.8) % 13.6 % (2.3) % 5.5 % Nine Months Ended September 30, 2022 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo U.S. Federal Statutory Rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % Increase (decrease) due to: State Income Tax, net of Federal Benefit 0.7 % 0.5 % 2.7 % (0.8) % 1.3 % 0.8 % 3.2 % (1.5) % Tax Reform Excess ADIT Reversal (7.8) % (2.0) % 0.3 % (10.3) % (15.7) % (7.3) % (20.8) % (4.8) % Production and Investment Tax Credits (8.7) % (0.4) % — % — % (1.4) % — % (39.5) % (22.5) % Flow Through — % 0.2 % 0.3 % 0.2 % (1.6) % 0.5 % 0.3 % (0.8) % AFUDC Equity (1.1) % (1.2) % (1.9) % (0.8) % (0.8) % (0.7) % (0.4) % (0.4) % Discrete Tax Adjustments (0.2) % — % — % (1.8) % — % — % — % 0.3 % Other 0.6 % 0.1 % 0.1 % — % 0.2 % 0.1 % 0.2 % — % Effective Income Tax Rate 4.5 % 18.2 % 22.5 % 7.5 % 3.0 % 14.4 % (36.0) % (8.7) % Nine Months Ended September 30, 2021 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo U.S. Federal Statutory Rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % Increase (decrease) due to: State Income Tax, net of Federal Benefit 1.2 % 0.3 % 2.8 % 1.5 % 1.6 % 0.8 % 4.8 % (3.4) % Tax Reform Excess ADIT Reversal (8.9) % (7.2) % 0.3 % (15.2) % (17.7) % (9.1) % (19.8) % (4.3) % Production and Investment Tax Credits (4.9) % (0.3) % — % — % (2.2) % — % (8.1) % (4.6) % Flow Through 0.2 % 0.3 % 0.3 % 1.7 % (3.0) % 0.9 % 0.7 % (0.2) % AFUDC Equity (1.1) % (1.1) % (1.9) % (1.2) % (1.0) % (0.8) % (0.3) % (0.6) % Parent Company Loss Benefit — % (0.7) % (1.9) % (1.3) % (2.8) % — % — % — % Discrete Tax Adjustments 1.1 % — % — % — % — % (1.3) % (0.9) % 0.6 % Other 0.1 % — % — % 0.1 % 0.4 % 0.2 % (0.2) % (0.1) % Effective Income Tax Rate 8.7 % 12.3 % 20.6 % 6.6 % (3.7) % 11.7 % (2.8) % 8.4 % 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 September 30, 2022, the IRS has accepted the 2014-2016 amended tax returns as filed which completes the IRS audit of these tax years. Additionally, AEP has received and agreed to two proposed adjustments on the 2017 tax return, which were immaterial. AEP has agreed to extend the statute of limitations on the 2017 and 2018 tax return to December 31, 2023 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. Generally, the statutes of limitations have expired for tax years prior to 2017. In addition, management is monitoring and continues to evaluate the potential impact of federal legislation and corresponding state conformity. Federal Legislation On August 16, 2022, President Biden signed H.R. 5376 into law, commonly known as the Inflation Reduction Act of 2022 or IRA. Most notably this budget reconciliation legislation creates a 15% minimum tax on adjusted financial statement income (Corporate Alternative Minimum Tax or CAMT), extends and increases the value of PTCs and ITCs, adds a nuclear and clean hydrogen PTC, an energy storage ITC and allows the sale or transfer of tax credits to third parties for cash. With the exception of PTCs and ITCs, this legislation is prospective and has no material impact on the current period financial statements. As significant guidance from Treasury and the IRS is expected on the tax provisions in the IRA, AEP will continue to monitor any issued guidance and evaluate the impact on future net income, cash flows and financial condition.

Financing Activities

Financing Activities	9 Months Ended
Financing Activities	Sep. 30, 2022
Financing Activities	FINANCING ACTIVITIES The disclosures in this note apply to all Registrants, unless indicated otherwise. Common Stock (Applies to AEP) At-the-Market (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. There were no issuances under the ATM program for the nine months ended September 30, 2022. Long-term Debt Outstanding (Applies to AEP) The following table details long-term debt outstanding, net of issuance costs and premiums or discounts: Type of Debt September 30, 2022 December 31, 2021 (in millions) Senior Unsecured Notes $ 28,892.7 $ 27,497.3 Pollution Control Bonds 1,804.9 1,804.5 Notes Payable 218.0 211.3 Securitization Bonds 524.8 603.5 Spent Nuclear Fuel Obligation (a) 283.2 281.3 Junior Subordinated Notes (b) 2,377.3 2,373.0 Other Long-term Debt 949.2 683.6 Total Long-term Debt Outstanding 35,050.1 33,454.5 Long-term Debt Due Within One Year (c) 1,403.5 2,153.8 Long-term Debt (d) $ 33,646.6 $ 31,300.7 (a) Pursuant to the Nuclear Waste Policy Act of 1982, I&M, a nuclear licensee, has an obligation to the United States Department of Energy for SNF disposal. The obligation includes a one-time fee for nuclear fuel consumed prior to April 7, 1983. Trust fund assets related to this obligation were $326 million and $329 million as of September 30, 2022 and December 31, 2021, respectively, and are included in Spent Nuclear Fuel and Decommissioning Trusts on the balance sheets. (b) See “Equity Units” section below for additional information. (c) Amount excludes $215 million and $200 million as of September 30, 2022 and December 31, 2021, respectively, of Long-term Debt Due Within One Year classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 6 for additional information. (d) Amount excludes $963 million and $903 million as of September 30, 2022 and December 31, 2021, respectively, of Long-term Debt classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 6 for additional information. Long-term Debt Activity Long-term debt and other securities issued, retired and principal payments made during the first nine months of 2022 are shown in the following tables: Principal Interest Company Type of Debt Amount (a) Rate Due Date Issuances: (in millions) (%) AEP Texas Other Long-term Debt $ 200.0 Variable 2025 AEP Texas Senior Unsecured Notes 500.0 4.70 2032 AEP Texas Senior Unsecured Notes 500.0 5.25 2052 AEPTCo Senior Unsecured Notes 550.0 4.50 2052 APCo Other Long-term Debt 100.0 Variable 2023 APCo Pollution Control Bonds 104.4 3.75 2025 APCo Senior Unsecured Notes 500.0 4.50 2032 I&M Notes Payable 72.8 3.44 2026 PSO Other Long-term Debt 500.0 Variable 2022 Non-Registrant: AEGCo Pollution Control Bonds 45.0 3.13 2025 KPCo Other Long-term Debt 150.0 Variable 2023 Transource Energy Other Long-term Debt 5.0 Variable 2023 WPCo Other Long-term Debt 165.0 Variable 2024 WPCo Pollution Control Bonds 65.0 3.00 2027 Total Issuances $ 3,457.2 (a) Amounts indicated on the statements of cash flows are net of issuance costs and premium or discount and will not tie to the issuance amounts. Principal Interest Company Type of Debt Amount Paid Rate Due Date Retirements and Principal Payments: (in millions) (%) AEP Texas Other Long-term Debt $ 200.0 Variable 2022 AEP Texas Senior Unsecured Notes 400.0 2.40 2022 AEP Texas Senior Unsecured Notes 25.0 3.27 2022 AEP Texas Securitization Bonds 30.6 2.85 2024 AEP Texas Securitization Bonds 23.0 2.06 2025 APCo Pollution Control Bonds 104.4 2.63 2022 APCo Securitization Bonds 25.9 2.01 2023 APCo Other Long-term Debt 0.1 13.72 2026 I&M Notes Payable 3.4 Variable 2022 I&M Notes Payable 1.3 Variable 2022 I&M Notes Payable 6.7 Variable 2023 I&M Notes Payable 10.8 Variable 2024 I&M Notes Payable 18.9 0.93 2025 I&M Notes Payable 13.7 Variable 2025 I&M Notes Payable 8.0 3.44 2026 I&M Other Long-term Debt 1.7 6.00 2025 OPCo Other Long-term Debt 0.1 1.15 2028 PSO Other Long-term Debt 500.0 Variable 2022 PSO Other Long-term Debt 0.4 3.00 2027 SWEPCo Other Long-term Debt 1.5 4.68 2028 SWEPCo Notes Payable 3.2 4.58 2032 Non-Registrant: AEGCo Pollution Control Bonds 45.0 1.35 2022 KPCo Other Long-term Debt 75.0 Variable 2022 Transource Energy Senior Unsecured Notes 2.4 2.75 2050 WPCo Pollution Control Bonds 65.0 3.00 2022 WPCo Senior Unsecured Notes 113.0 3.36 2022 Total Retirements and Principal Payments $ 1,679.1 Long-term Debt Subsequent Event In October 2022, AEGCo retired $120 million of Other Long-term Debt. In October 2022, AEGCo issued $80 million of variable rate Other Long-term Debt due in 2024. In October 2022, AEPTCo retired $104 million of Senior Unsecured Notes. In October 2022, APCo retired $100 million of Pollution Control Bonds. In October 2022, I&M retired $7 million of Notes Payable related to DCC Fuel. In October 2022, Transource Energy issued $64 million of variable rate Other Long-term Debt due in 2025. In October 2022, Transource Energy retired $64 million of Other Long-term Debt. 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 settled 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 used the debt remarketing proceeds to settle the forward equity purchase contract with AEP. The interest rate on the notes was reset to 2.031% with the maturity remaining in 2024. In March 2022, AEP issued 8,970,920 shares of AEP common stock and received proceeds totaling $805 million under the settlement of the forward equity purchase contract. AEP common stock held in treasury was used to settle the forward equity purchase contract. 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 0.5% of consolidated tangible net assets as of September 30, 2022. The method for calculating the consolidated tangible net assets is contractually-defined in the note purchase agreements. 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 requirement that prohibits the payment of dividends out of capital accounts in certain circumstances; payment of dividends is generally allowed out of retained earnings. The Federal Power Act also creates a reserve on 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 Federal Power Act restriction does not limit the ability of the AEP subsidiaries to pay dividends out of retained earnings. 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. Corporate Borrowing Program - AEP System (Applies to all 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 September 30, 2022 and December 31, 2021 are included in Advances to Affiliates and Advances from Affiliates, respectively, on the Registrant Subsidiaries’ balance sheets. The Utility Money Pool participants’ activity and corresponding authorized borrowing limits for the nine months ended September 30, 2022 are described in the following table: 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 September 30, 2022 Limit (in millions) AEP Texas $ 348.8 $ 652.3 $ 208.1 $ 319.8 $ 129.5 $ 500.0 AEPTCo 480.2 137.0 197.4 31.3 78.7 (a) 820.0 (b) APCo 438.4 214.2 180.9 52.8 182.1 500.0 I&M 159.1 22.6 86.0 22.1 (82.3) 500.0 OPCo 147.2 246.1 59.9 86.9 (68.8) 500.0 PSO 338.3 432.5 200.9 402.8 (223.5) 400.0 SWEPCo 261.6 156.6 191.0 109.7 (156.3) 400.0 (a) Amount excludes $5 million of Advances to Affiliates classified as Assets Held for Sale on the AEPTCo balance sheet. See “Dispositions of KPCo and KTCo” section of Note 6 for additional information. (b) Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions. The activity in the above table 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 September 30, 2022 and December 31, 2021 are included in Advances to Affiliates on the subsidiaries’ balance sheets. The Nonutility Money Pool participants’ activity for the nine months ended September 30, 2022 is described in the following table: Maximum Loans Average Loans Loans to the Nonutility to the Nonutility to the Nonutility Money Pool as of Company Money Pool Money Pool September 30, 2022 (in millions) AEP Texas $ 6.9 $ 6.8 $ 6.8 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 September 30, 2022 and December 31, 2021 are included in Advances to Affiliates and Advances from Affiliates, respectively, on AEPTCo’s balance sheets. AEPTCo’s direct borrowing and lending activity with AEP and corresponding authorized borrowing limit for the nine months ended September 30, 2022 are described in the following table: 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 September 30, 2022 September 30, 2022 Borrowing Limit (in millions) $ 52.4 $ 141.8 $ 7.1 $ 59.6 $ 33.0 $ — $ 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: Nine Months Ended September 30, 2022 2021 Maximum Interest Rate 3.39 % 0.40 % Minimum Interest Rate 0.10 % 0.02 % The average interest rates for funds borrowed from and loaned to the Utility Money Pool are summarized for all Registrant Subsidiaries in the following table: Average Interest Rate for Funds Average Interest Rate for Funds Borrowed from the Utility Money Pool Loaned to the Utility Money Pool for Nine Months Ended September 30, for Nine Months Ended September 30, Company 2022 2021 2022 2021 AEP Texas 0.90 % 0.33 % 1.82 % 0.27 % AEPTCo 1.03 % 0.32 % 2.14 % 0.07 % APCo 1.39 % 0.28 % 2.13 % 0.28 % I&M 1.38 % 0.32 % 1.46 % 0.25 % OPCo 1.81 % 0.27 % 1.22 % 0.15 % PSO 1.70 % 0.34 % 0.75 % 0.06 % SWEPCo 1.67 % 0.28 % 0.55 % 0.38 % Maximum, minimum and average interest rates for funds loaned to the Nonutility Money Pool are summarized in the following table: Nine Months Ended September 30, 2022 Nine Months Ended September 30, 2021 Maximum Minimum Average Maximum Minimum 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 Loaned to Loaned to Loaned to Loaned to Loaned to Loaned to the Nonutility the Nonutility the Nonutility the Nonutility the Nonutility the Nonutility Company Money Pool Money Pool Money Pool Money Pool Money Pool Money Pool AEP Texas 3.39 % 0.46 % 1.51 % 0.41 % 0.21 % 0.34 % SWEPCo 3.39 % 0.46 % 1.52 % 0.41 % 0.21 % 0.34 % 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 Nine Months for Funds for Funds for Funds for Funds for Funds for Funds Ended Borrowed Borrowed Loaned Loaned Borrowed Loaned September 30, from AEP from AEP to AEP to AEP from AEP to AEP 2022 3.39 % 0.46 % 3.37 % 0.46 % 1.56 % 1.38 % 2021 0.86 % 0.25 % 0.86 % 0.25 % 0.35 % 0.34 % Short-term Debt (Applies to AEP) Outstanding short-term debt was as follows: September 30, 2022 December 31, 2021 Outstanding Interest Outstanding Interest Company Type of Debt Amount Rate (a) Amount Rate (a) (dollars in millions) AEP Securitized Debt for Receivables (b) $ 750.0 1.16 % $ 750.0 0.19 % AEP Commercial Paper 1,952.3 3.38 % 1,364.0 0.34 % AEP Term Loan — — % 500.0 0.81 % Total Short-term Debt $ 2,702.3 $ 2,614.0 (a) Weighted-average rate. (b) Amount of securitized debt for receivables as accounted for under the “Transfers and Servicing” accounting guidance. Credit Facilities For a discussion of credit facilities, see “Letters of Credit” section of Note 5. 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. The $125 million facility was renewed in September 2022 and amended to extend the expiration date to September 2024. The $625 million facility also expires in September 2024. As of September 30, 2022, the affiliated utility subsidiaries are in compliance with all requirements under the agreement. Accounts receivable information for AEP Credit was as follows: Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (dollars in millions) Effective Interest Rates on Securitization of Accounts Receivable 2.25 % 0.18 % 1.16 % 0.19 % Net Uncollectible Accounts Receivable Written-Off $ 9.5 $ 7.5 $ 23.1 $ 22.6 September 30, 2022 December 31, 2021 (in millions) Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts $ 1,172.5 $ 995.2 Short-term – Securitized Debt of Receivables 750.0 750.0 Delinquent Securitized Accounts Receivable 57.4 57.9 Bad Debt Reserves Related to Securitization 39.4 42.8 Unbilled Receivables Related to Securitization 252.3 307.1 AEP Credit’s delinquent customer accounts receivable represent accounts greater than 30 days past due. Securitized Accounts Receivables – AEP Credit (Applies to all 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 ceased selling accounts receivable to AEP Credit in the first quarter of 2022, based on the pending sale to Liberty. As a result, in the first quarter of 2022, KPCo recorded 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 agreements were: Company September 30, 2022 December 31, 2021 (in millions) APCo $ 127.5 $ 153.1 I&M 187.8 156.9 OPCo 476.7 392.7 PSO 188.4 114.5 SWEPCo 217.0 153.0 The fees paid to AEP Credit for customer accounts receivable sold were: Three Months Ended September 30, Nine Months Ended September 30, Company 2022 2021 (a) 2022 2021 (a) (in millions) APCo $ 2.8 $ 1.3 $ 5.6 $ 3.7 I&M 2.8 2.1 6.5 5.3 OPCo 7.3 4.6 22.2 3.5 PSO 2.4 1.1 4.6 2.4 SWEPCo 3.2 1.3 6.0 4.1 (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. The proceeds on the sale of receivables to AEP Credit were: Three Months Ended September 30, Nine Months Ended September 30, Company 2022 2021 2022 2021 (in millions) APCo $ 360.4 $ 342.2 $ 1,114.9 $ 980.6 I&M 558.5 536.8 1,574.3 1,478.9 OPCo 874.1 668.4 2,284.0 1,867.5 PSO 588.5 460.1 1,380.4 1,068.8 SWEPCo 593.6 488.5 1,425.3 1,265.5

Property, Plant and Equipment

Property, Plant and Equipment	9 Months Ended
Property, Plant and Equipment	Sep. 30, 2022
Property, Plant and Equipment	13. PROPERTY, PLANT AND EQUIPMENT The disclosure in this note applies to AEP, PSO and SWEPCo. 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. The discussion below summarizes significant changes to the Registrants ARO recorded in 2022 and should be read in conjunction with the Property, Plant and Equipment note within the 2021 Annual Report. In March 2022, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Traverse during its development and construction. Immediately following the acquisition, PSO and SWEPCo liquidated the entity and simultaneously distributed the Traverse assets in proportion to their undivided ownership interests. Traverse was placed in-service in March 2022. As a result, PSO and SWEPCo incurred additional ARO liabilities of $13 million and $15 million, respectively. See the “North Central Wind Energy Facilities” section of Note 6 for additional information. Additionally, in March 2022, SWEPCo recorded a $13 million revision due to an increase in estimated ash pond closure costs at the Pirkey Plant and the Welsh Plant. In June 2022, SWEPCo recorded a $16 million revision due to an increase in estimated reclamation costs at Sabine. In September 2022, SWEPCo recorded a $14 million revision due to an increase in estimated landfill closure costs at Pirkey Plant. The following is a reconciliation of the aggregate carrying amounts of ARO for AEP, PSO and SWEPCo: Company ARO as of December 31, 2021 Accretion Liabilities Liabilities Revisions in ARO as of September 30, 2022 (in millions) AEP (a)(b)(c)(d)(e) $ 2,741.7 $ 82.1 $ 37.4 $ (29.4) $ 90.9 $ 2,922.7 PSO (a)(d) 57.6 3.0 12.8 (0.6) 1.9 74.7 SWEPCo (a)(c)(d) 222.7 8.3 15.4 (16.9) 48.0 277.5 (a) Includes ARO related to ash disposal facilities. (b) Includes ARO related to nuclear decommissioning costs for the Cook Plant of $1.98 billion and $1.93 billion as of September 30, 2022 and December 31, 2021, respectively. (c) Includes ARO related to Sabine and DHLC. (d) Includes ARO related to asbestos removal. (e) Includes $18 million and $18 million as of September 30, 2022 and December 31, 2021, respectively, of ARO classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.

Revenue from Contracts with Cus

Revenue from Contracts with Customers	9 Months Ended
Revenue from Contracts with Customers	Sep. 30, 2021
Revenue from Contract with Customer	14. REVENUE FROM CONTRACTS WITH CUSTOMERS The disclosures in this note apply to all Registrants, unless indicated otherwise. Disaggregated Revenues from Contracts with Customers The tables below represent AEP’s reportable segment revenues from contracts with customers, net of respective provisions for refund, by type of revenue: Three Months Ended September 30, 2022 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 $ 1,298.0 $ 721.9 $ — $ — $ — $ — $ 2,019.9 Commercial Revenues 725.1 373.0 — — — — 1,098.1 Industrial Revenues 658.5 191.5 — — — (0.3) 849.7 Other Retail Revenues 54.3 15.0 — — — — 69.3 Total Retail Revenues 2,735.9 1,301.4 — — — (0.3) 4,037.0 Wholesale and Competitive Retail Revenues: Generation Revenues 299.3 — — 83.7 — (0.2) 382.8 Transmission Revenues (a) 120.3 162.3 424.9 — — (392.7) 314.8 Renewable Generation Revenues (b) — — — 44.3 — (2.5) 41.8 Retail, Trading and Marketing Revenues — — — 482.9 2.2 0.2 485.3 Total Wholesale and Competitive Retail Revenues 419.6 162.3 424.9 610.9 2.2 (395.2) 1,224.7 Other Revenues from Contracts with Customers (c) 69.7 74.5 (0.3) 1.7 24.3 (31.9) 138.0 Total Revenues from Contracts with Customers 3,225.2 1,538.2 424.6 612.6 26.5 (427.4) 5,399.7 Other Revenues: Alternative Revenues (b) 0.9 (13.5) 6.3 — — 4.4 (1.9) Other Revenues (b) (d) 0.2 5.5 — 122.8 1.8 (2.0) 128.3 Total Other Revenues 1.1 (8.0) 6.3 122.8 1.8 2.4 126.4 Total Revenues $ 3,226.3 $ 1,530.2 $ 430.9 $ 735.4 $ 28.3 $ (425.0) $ 5,526.1 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $342 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 Corporate and Other was $18 million. The remaining affiliated amounts were immaterial. (d) Generation & Marketing includes economic hedge activity. Three Months Ended September 30, 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 $ 1,144.3 $ 598.0 $ — $ — $ — $ — $ 1,742.3 Commercial Revenues 618.9 279.9 — — — — 898.8 Industrial Revenues 566.0 95.2 — — — (0.1) 661.1 Other Retail Revenues 47.5 11.1 — — — — 58.6 Total Retail Revenues 2,376.7 984.2 — — — (0.1) 3,360.8 Wholesale and Competitive Retail Revenues: Generation Revenues 233.8 — — 47.8 — — 281.6 Transmission Revenues (a) 99.8 150.6 375.8 — — (317.4) 308.8 Renewable Generation Revenues (b) — — — 24.1 — (0.6) 23.5 Retail, Trading and Marketing Revenues (c) — — — 397.1 0.1 (3.1) 394.1 Total Wholesale and Competitive Retail Revenues 333.6 150.6 375.8 469.0 0.1 (321.1) 1,008.0 Other Revenues from Contracts with Customers (b) 49.4 54.2 5.1 1.4 23.5 (40.1) 93.5 Total Revenues from Contracts with Customers 2,759.7 1,189.0 380.9 470.4 23.6 (361.3) 4,462.3 Other Revenues: Alternative Revenues (b) 0.5 6.4 10.7 — — (11.7) 5.9 Other Revenues (b) (d) (0.9) 4.9 — 150.7 3.1 (3.0) 154.8 Total Other Revenues (0.4) 11.3 10.7 150.7 3.1 (14.7) 160.7 Total Revenues $ 2,759.3 $ 1,200.3 $ 391.6 $ 621.1 $ 26.7 $ (376.0) $ 4,623.0 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $286 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 $4 million. The remaining affiliated amounts were immaterial. (d) Generation & Marketing includes economic hedge activity. Three Months Ended September 30, 2022 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 204.0 $ — $ 360.5 $ 238.6 $ 517.9 $ 299.6 $ 285.5 Commercial Revenues 107.1 — 161.1 154.3 266.1 153.4 182.3 Industrial Revenues 35.4 — 163.3 155.6 156.1 98.9 108.3 Other Retail Revenues 11.5 — 20.6 1.2 3.5 30.1 0.6 Total Retail Revenues 358.0 — 705.5 549.7 943.6 582.0 576.7 Wholesale Revenues: Generation Revenues (a) — — 107.9 126.3 — 9.4 87.6 Transmission Revenues (b) 140.8 411.7 41.5 8.8 21.5 10.2 42.3 Total Wholesale Revenues 140.8 411.7 149.4 135.1 21.5 19.6 129.9 Other Revenues from Contracts with Customers (c) 9.5 (0.3) 33.7 30.6 64.8 6.4 7.6 Total Revenues from Contracts with Customers 508.3 411.4 888.6 715.4 1,029.9 608.0 714.2 Other Revenues: Alternative Revenues (d) 0.6 7.1 — — (14.1) 0.2 3.3 Other Revenues (d) — — 0.3 — 5.5 — — Total Other Revenues 0.6 7.1 0.3 — (8.6) 0.2 3.3 Total Revenues $ 508.9 $ 418.5 $ 888.9 $ 715.4 $ 1,021.3 $ 608.2 $ 717.5 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $44 million primarily related to the PPA with KGPCo. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $339 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $15 million primarily related to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. Three Months Ended September 30, 2021 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 172.5 $ — $ 340.1 $ 231.7 $ 425.4 $ 236.8 $ 230.9 Commercial Revenues 89.1 — 146.9 143.9 190.8 120.9 145.4 Industrial Revenues 25.4 — 154.8 146.8 69.8 77.1 85.4 Other Retail Revenues 8.2 — 18.6 1.3 3.1 23.4 2.3 Total Retail Revenues 295.2 — 660.4 523.7 689.1 458.2 464.0 Wholesale Revenues: Generation Revenues (a) — — 83.7 80.2 — 7.2 77.1 Transmission Revenues (b) 131.5 360.1 35.2 8.7 19.1 10.6 37.1 Total Wholesale Revenues 131.5 360.1 118.9 88.9 19.1 17.8 114.2 Other Revenues from Contracts with Customers (c) 6.8 5.0 22.5 24.2 47.3 8.3 6.1 Total Revenues from Contracts with Customers 433.5 365.1 801.8 636.8 755.5 484.3 584.3 Other Revenues: Alternative Revenues (d) (0.9) 11.9 2.2 (1.1) 7.3 (0.5) (0.2) Other Revenues (d) — — — — 4.9 — — Total Other Revenues (0.9) 11.9 2.2 (1.1) 12.2 (0.5) (0.2) Total Revenues $ 432.6 $ 377.0 $ 804.0 $ 635.7 $ 767.7 $ 483.8 $ 584.1 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $30 million primarily related to the PPA with KGPCo. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $281 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $17 million primarily related to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. Nine Months Ended September 30, 2022 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 $ 3,428.1 $ 1,884.1 $ — $ — $ — $ — $ 5,312.2 Commercial Revenues 1,922.8 994.4 — — — — 2,917.2 Industrial Revenues (b) 1,863.3 487.3 — — — (0.7) 2,349.9 Other Retail Revenues 154.6 39.4 — — — — 194.0 Total Retail Revenues 7,368.8 3,405.2 — — — (0.7) 10,773.3 Wholesale and Competitive Retail Revenues: Generation Revenues (b) 674.8 — — 207.0 — (0.1) 881.7 Transmission Revenues (a) 334.4 482.1 1,261.0 — — (1,086.5) 991.0 Renewable Generation Revenues (b) — — — 104.9 — (6.2) 98.7 Retail, Trading and Marketing Revenues (c) — — — 1,280.0 6.7 (11.1) 1,275.6 Total Wholesale and Competitive Retail Revenues 1,009.2 482.1 1,261.0 1,591.9 6.7 (1,103.9) 3,247.0 Other Revenues from Contracts with Customers (d) 180.5 194.2 (0.3) 11.9 59.1 (71.6) 373.8 Total Revenues from Contracts with Customers 8,558.5 4,081.5 1,260.7 1,603.8 65.8 (1,176.2) 14,394.1 Other Revenues: Alternative Revenues (b) 3.4 (21.5) (39.6) — — (7.4) (65.1) Other Revenues (b) (e) 0.3 18.6 — 410.5 6.9 (6.9) 429.4 Total Other Revenues 3.7 (2.9) (39.6) 410.5 6.9 (14.3) 364.3 Total Revenues $ 8,562.2 $ 4,078.6 $ 1,221.1 $ 2,014.3 $ 72.7 $ (1,190.5) $ 14,758.4 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $1 billion. The affiliated revenue for Vertically Integrated Utilities was $120 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 $11 million. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $36 million. The remaining affiliated amounts were immaterial. (e) Generation & Marketing includes economic hedge activity. Nine Months Ended September 30, 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 $ 3,016.2 $ 1,641.2 $ — $ — $ — $ — $ 4,657.4 Commercial Revenues 1,642.0 804.1 — — — — 2,446.1 Industrial Revenues 1,602.5 283.8 — — — (0.5) 1,885.8 Other Retail Revenues 125.9 32.4 — — — — 158.3 Total Retail Revenues 6,386.6 2,761.5 — — — (0.5) 9,147.6 Wholesale and Competitive Retail Revenues: Generation Revenues 757.1 — — 119.4 — — 876.5 Transmission Revenues (a) 267.3 420.7 1,092.1 — — (901.5) 878.6 Renewable Generation Revenues (b) — — — 66.7 — (1.7) 65.0 Retail, Trading and Marketing Revenues (c) — — — 1,325.6 0.6 (48.5) 1,277.7 Total Wholesale and Competitive Retail Revenues 1,024.4 420.7 1,092.1 1,511.7 0.6 (951.7) 3,097.8 Other Revenues from Contracts with Customers (b) 136.1 149.3 12.5 4.9 46.1 (87.9) 261.0 Total Revenues from Contracts with Customers 7,547.1 3,331.5 1,104.6 1,516.6 46.7 (1,040.1) 12,506.4 Other Revenues: Alternative Revenues (b) 10.7 46.1 42.2 — — (63.5) 35.5 Other Revenues (b) (d) (0.6) 14.2 — 175.3 8.4 (8.6) 188.7 Total Other Revenues 10.1 60.3 42.2 175.3 8.4 (72.1) 224.2 Total Revenues $ 7,557.2 $ 3,391.8 $ 1,146.8 $ 1,691.9 $ 55.1 $ (1,112.2) $ 12,730.6 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $835 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 $49 million. The remaining affiliated amounts were immaterial. (d) Generation & Marketing includes economic hedge activity. Nine Months Ended September 30, 2022 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 520.8 $ — $ 1,131.7 $ 665.6 $ 1,363.3 $ 650.7 $ 650.0 Commercial Revenues 312.6 — 467.6 419.5 681.9 372.1 458.8 Industrial Revenues (d) 102.6 — 479.0 452.1 384.8 270.0 290.1 Other Retail Revenues 29.2 — 61.4 3.7 10.2 77.1 7.4 Total Retail Revenues 965.2 — 2,139.7 1,540.9 2,440.2 1,369.9 1,406.3 Wholesale Revenues: Generation Revenues (a) — — 227.6 310.9 — 19.2 206.2 Transmission Revenues (b) 417.7 1,218.1 123.4 26.3 64.4 28.9 116.8 Total Wholesale Revenues 417.7 1,218.1 351.0 337.2 64.4 48.1 323.0 Other Revenues from Contracts with Customers (c) 24.4 (0.4) 78.6 86.3 169.6 21.4 18.9 Total Revenues from Contracts with Customers 1,407.3 1,217.7 2,569.3 1,964.4 2,674.2 1,439.4 1,748.2 Other Revenues: Alternative Revenues (d) (2.9) (34.4) 0.1 7.3 (18.6) (0.7) 0.7 Other Revenues (d) — — 0.4 (0.1) 18.6 — — Total Other Revenues (2.9) (34.4) 0.5 7.2 — (0.7) 0.7 Total Revenues $ 1,404.4 $ 1,183.3 $ 2,569.8 $ 1,971.6 $ 2,674.2 $ 1,438.7 $ 1,748.9 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $122 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 $992 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $44 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. Nine Months Ended September 30, 2021 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 423.7 $ — $ 1,025.0 $ 624.4 $ 1,217.5 $ 516.4 $ 547.1 Commercial Revenues 265.2 — 409.5 384.5 538.9 286.8 385.4 Industrial Revenues 81.6 — 433.4 418.9 202.2 202.1 247.1 Other Retail Revenues 23.1 — 51.7 3.9 9.4 58.2 7.2 Total Retail Revenues 793.6 — 1,919.6 1,431.7 1,968.0 1,063.5 1,186.8 Wholesale Revenues: Generation Revenues (a) — — 231.2 248.1 — 6.8 326.2 Transmission Revenues (b) 364.5 1,045.2 94.1 25.3 56.2 28.8 94.5 Total Wholesale Revenues 364.5 1,045.2 325.3 273.4 56.2 35.6 420.7 Other Revenues from Contracts with Customers (c) 35.4 12.5 43.6 81.9 113.8 24.8 17.7 Total Revenues from Contracts with Customers 1,193.5 1,057.7 2,288.5 1,787.0 2,138.0 1,123.9 1,625.2 Other Revenues: Alternative Revenues (d) 1.8 46.5 9.5 (3.0) 44.3 0.5 5.1 Other Revenues (d) — — — — 14.2 — — Total Other Revenues 1.8 46.5 9.5 (3.0) 58.5 0.5 5.1 Total Revenues $ 1,195.3 $ 1,104.2 $ 2,298.0 $ 1,784.0 $ 2,196.5 $ 1,124.4 $ 1,630.3 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $90 million primarily relating to the PPA with KGPCo. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $823 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $46 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 The following table represents the Registrants’ remaining fixed performance obligations satisfied over time as of September 30, 2022. 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 $ 318.7 $ 172.1 $ 157.8 $ 96.9 $ 745.5 AEP Texas 145.8 — — — 145.8 AEPTCo 369.4 — — — 369.4 APCo 50.1 33.7 26.6 11.5 121.9 I&M 9.7 13.6 9.2 4.5 37.0 OPCo 19.2 3.4 — — 22.6 PSO 3.4 — — — 3.4 SWEPCo 10.9 — — — 10.9 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 material contract assets as of September 30, 2022 and December 31, 2021. 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 sheets 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 material contract liabilities as of September 30, 2022 and December 31, 2021. Accounts Receivable from Contracts with Customers Accounts receivable from contracts with customers are presented on the Registrant Subsidiaries’ balance sheets within the Accounts Receivable - Customers line item. The Registrant Subsidiaries’ 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 September 30, 2022 and December 31, 2021. See “Securitized Accounts Receivable - AEP Credit” section of Note 12 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: Company September 30, 2022 December 31, 2021 (in millions) AEP Texas $ — $ 0.4 AEPTCo 110.6 95.5 APCo 65.8 117.8 I&M 51.1 61.2 OPCo 61.5 51.7 PSO 36.8 18.8 SWEPCo 20.2 24.7

Significant Accounting Matters

Significant Accounting Matters (Policies)	9 Months Ended
Significant Accounting Matters (Policies)	Sep. 30, 2022
Basis of Accounting	General The unaudited condensed financial statements and footnotes were prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X of the SEC. Accordingly, they do not include all of the information and footnotes required by GAAP for complete annual financial statements. In the opinion of management, the unaudited condensed interim financial statements reflect all normal and recurring accruals and adjustments necessary for a fair statement of the net income, financial position and cash flows for the interim periods for each Registrant. Net income for the three and nine months ended September 30, 2022 is not necessarily indicative of results that may be expected for the year ending December 31, 2022. The condensed financial statements are unaudited and should be read in conjunction with the audited 2021 financial statements and notes thereto, which are included in the Registrants’ Annual Reports on Form 10-K as filed with the SEC on February 24, 2022.
Income Tax, Policy	AEP System Tax Allocation The Registrant Subsidiaries join in the filing of a consolidated tax return. Historically, the allocation of the AEP System’s current consolidated federal income tax to the AEP System companies allocated the benefit of current tax loss of the parent company (Parent Company Loss Benefit) to the AEP System subsidiaries through a reduction of current tax expense. In the first quarter of 2022, AEP and subsidiaries changed accounting for the Parent Company Loss Benefit from a reduction of current tax expense to an allocation through equity. The impact of this change was immaterial to the Registrant Subsidiaries’ financial statements.
Capitalization and Amortization of Fuel Costs, Policy	Deferred Fuel Costs (Applies to all Registrants except AEP Texas, AEPTCo and OPCo) The cost of purchased electricity, fuel and related emission allowances and emission control chemicals/consumables is charged to Purchased Electricity, 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 an expectation that refunds or recoveries will extend beyond a one year period, based on a company’s filing with a commission or a commission directive. 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.
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.

Derivatives and Hedging (Polici

Derivatives and Hedging (Policies)	9 Months Ended
Derivatives and Hedging (Policies)	Sep. 30, 2022
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, AEP Texas, APCo, I&M 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 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. Credit-Risk-Related Contingent Features Credit Downgrade Triggers (Applies to AEP, APCo, I&M, PSO and SWEPCo)

Fair Value Measurements (Polici

Fair Value Measurements (Policies)	9 Months Ended
Fair Value Measurements (Policies)	Sep. 30, 2022
Valuation Techniques	Fair Value Hierarchy and Valuation Techniques 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 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 nuclear trusts, cash and cash equivalents, other temporary investments 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.
Fair Values of Long-term Debt	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.
Trust Assets for Decommissioning and Spent Nuclear Fuel Disposal	Fair Value Measurements of Trust Assets for Decommissioning and SNF Disposal (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
Fair Value Assets and Liabilities Measured on Recurring Basis	Fair Value Measurements of Financial Assets and Liabilities 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.

Income Taxes (Policies)

Income Taxes (Policies)	9 Months Ended
Income Taxes (Policies)	Sep. 30, 2022
Amortization of Excess ADIT Not Subject to Normalization Requirements Policy	The Registrants include the amortization of Excess ADIT not subject to normalization requirements in the annual estimated ETR when regulatory proceedings instruct the Registrants to provide the benefits of Tax Reform to customers over multiple interim periods. Certain regulatory proceedings instruct the Registrants to provide the benefits of Tax Reform to customers in a single period (e.g. by applying the Excess ADIT not subject to normalization requirements against an existing regulatory asset balance) and in these circumstances, the Registrants recognize the tax benefit discretely in the period recorded. The annual amount of Excess ADIT approved by the Registrant’s regulatory commissions may not impact the ETR ratably during each interim period due to the variability of pretax book income between interim periods and the application of an annual estimated ETR.

Property, Plant and Equipment (

Property, Plant and Equipment (Policies)	9 Months Ended
Property, Plant and Equipment (Policies)	Sep. 30, 2022
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. The discussion below summarizes significant changes to the Registrants ARO recorded in 2022 and should be read in conjunction with the Property, Plant and Equipment note within the 2021 Annual Report.

Significant Accounting Matter_2

Significant Accounting Matters (Tables)	9 Months Ended
Significant Accounting Matters (Tables)	Sep. 30, 2022
Reconciliation of Cash, Cash Equivalents and Restricted Cash	September 30, 2022 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 522.2 $ 0.1 $ 6.7 Restricted Cash 55.1 47.7 7.4 Total Cash, Cash Equivalents and Restricted Cash $ 577.3 $ 47.8 $ 14.1 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
Earnings Per Share	Three Months Ended September 30, 2022 2021 (in millions, except per share data) $/share $/share Earnings Attributable to AEP Common Shareholders $ 683.7 $ 796.0 Weighted-Average Number of Basic AEP Common Shares Outstanding 513.7 $ 1.33 501.2 $ 1.59 Weighted-Average Dilutive Effect of Stock-Based Awards 1.6 — 1.4 (0.01) Weighted-Average Number of Diluted AEP Common Shares Outstanding 515.3 $ 1.33 502.6 $ 1.58 Nine Months Ended September 30, 2022 2021 (in millions, except per share data) $/share $/share Earnings Attributable to AEP Common Shareholders $ 1,922.9 $ 1,949.2 Weighted-Average Number of Basic AEP Common Shares Outstanding 511.2 $ 3.76 499.4 $ 3.90 Weighted-Average Dilutive Effect of Stock-Based Awards 1.5 (0.01) 1.2 (0.01) Weighted-Average Number of Diluted AEP Common Shares Outstanding 512.7 $ 3.75 500.6 $ 3.89
Supplementary Information	Nine Months Ended September 30, Cash Flow Information 2022 2021 (in millions) Cash Paid for: Interest, Net of Capitalized Amounts $ 856.8 $ 775.2 Income Taxes 104.1 9.3 Noncash Investing and Financing Activities: Acquisitions Under Finance Leases 22.3 23.0 Construction Expenditures Included in Current Liabilities as of September 30, 985.8 764.1 Acquisition of Nuclear Fuel Included in Current Liabilities as of September 30, 8.5 0.3 Noncash Contribution of Assets to Cedar Creek Project — (9.3) Noncontrolling Interest Assumed - Dry Lake Solar Project — 35.0

Comprehensive Income (Tables)

Comprehensive Income (Tables)	9 Months Ended
Comprehensive Income (Tables)	Sep. 30, 2022
Changes in Accumulated Other Comprehensive Income (Loss) by Component	AEP Cash Flow Hedges Pension Three Months Ended September 30, 2022 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2022 $ 533.6 $ (10.8) $ 28.6 $ 551.4 Change in Fair Value Recognized in AOCI 94.3 7.4 (a) — 101.7 Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (b) 0.2 — — 0.2 Purchased Electricity for Resale (b) (222.6) — — (222.6) Interest Expense (b) — 0.9 — 0.9 Amortization of Prior Service Cost (Credit) — — (6.2) (6.2) Amortization of Actuarial (Gains) Losses — — 2.2 2.2 Reclassifications from AOCI, before Income Tax (Expense) Benefit (222.4) 0.9 (4.0) (225.5) Income Tax (Expense) Benefit (46.6) 0.1 (0.8) (47.3) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (175.8) 0.8 (3.2) (178.2) Net Current Period Other Comprehensive Income (Loss) (81.5) 8.2 (3.2) (76.5) Balance in AOCI as of September 30, 2022 $ 452.1 $ (2.6) $ 25.4 $ 474.9 Cash Flow Hedges Pension Three Months Ended September 30, 2021 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2021 $ 110.3 $ (32.2) $ 18.9 $ 97.0 Change in Fair Value Recognized in AOCI 220.8 4.9 (a) — 225.7 Amount of (Gain) Loss Reclassified from AOCI Purchased Electricity for Resale (b) (59.7) — — (59.7) Interest Expense (b) — 1.5 — 1.5 Amortization of Prior Service Cost (Credit) — — (4.8) (4.8) Amortization of Actuarial (Gains) Losses — — 2.3 2.3 Reclassifications from AOCI, before Income Tax (Expense) Benefit (59.7) 1.5 (2.5) (60.7) Income Tax (Expense) Benefit (12.5) 0.3 (0.5) (12.7) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (47.2) 1.2 (2.0) (48.0) Net Current Period Other Comprehensive Income (Loss) 173.6 6.1 (2.0) 177.7 Balance in AOCI as of September 30, 2021 $ 283.9 $ (26.1) $ 16.9 $ 274.7 AEP Cash Flow Hedges Pension Nine Months Ended September 30, 2022 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2021 $ 163.7 $ (21.3) $ 42.4 $ 184.8 Change in Fair Value Recognized in AOCI 629.8 16.2 (a) — 646.0 Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (b) 0.2 — — 0.2 Purchased Electricity for Resale (b) (432.3) — — (432.3) Interest Expense (b) — 3.1 — 3.1 Amortization of Prior Service Cost (Credit) — — (16.5) (16.5) Amortization of Actuarial (Gains) Losses — — 6.4 6.4 Reclassifications from AOCI, before Income Tax (Expense) Benefit (432.1) 3.1 (10.1) (439.1) Income Tax (Expense) Benefit (90.7) 0.6 (2.1) (92.2) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (341.4) 2.5 (8.0) (346.9) Reclassifications of KPCo Pension and OPEB Regulatory Assets to AOCI — — (11.4) (11.4) Income Tax (Expense) Benefit — — (2.4) (2.4) Reclassifications of KPCo Pension and OPEB Regulatory Assets to AOCI, Net of Income Tax (Expense) Benefit — — (9.0) (9.0) Net Current Period Other Comprehensive Income (Loss) 288.4 18.7 (17.0) 290.1 Balance in AOCI as of September 30, 2022 $ 452.1 $ (2.6) $ 25.4 $ 474.9 Cash Flow Hedges Pension Nine Months Ended September 30, 2021 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2020 $ (60.6) $ (47.5) $ 23.0 $ (85.1) Change in Fair Value Recognized in AOCI 534.5 17.6 (a) — 552.1 Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (b) 0.7 — — 0.7 Purchased Electricity for Resale (b) (241.2) — — (241.2) Interest Expense (b) — 4.8 — 4.8 Amortization of Prior Service Cost (Credit) — — (14.5) (14.5) Amortization of Actuarial (Gains) Losses — — 6.8 6.8 Reclassifications from AOCI, before Income Tax (Expense) Benefit (240.5) 4.8 (7.7) (243.4) Income Tax (Expense) Benefit (50.5) 1.0 (1.6) (51.1) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (190.0) 3.8 (6.1) (192.3) Net Current Period Other Comprehensive Income (Loss) 344.5 21.4 (6.1) 359.8 Balance in AOCI as of September 30, 2021 $ 283.9 $ (26.1) $ 16.9 $ 274.7 AEP Texas Cash Flow Hedge – Pension Three Months Ended September 30, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2022 $ (0.8) $ (5.2) $ (6.0) Change in Fair Value Recognized in AOCI 0.1 — 0.1 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.3 — 0.3 Amortization of Prior Service Cost (Credit) — (0.1) (0.1) Amortization of Actuarial (Gains) Losses — 0.1 0.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.3 — 0.3 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.2 — 0.2 Net Current Period Other Comprehensive Income (Loss) 0.3 — 0.3 Balance in AOCI as of September 30, 2022 $ (0.5) $ (5.2) $ (5.7) Cash Flow Hedge – Pension Three Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2021 $ (1.8) $ (6.5) $ (8.3) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.4 — 0.4 Amortization of Prior Service Cost (Credit) — (0.1) (0.1) Amortization of Actuarial (Gains) Losses — 0.1 0.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.4 — 0.4 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.3 — 0.3 Net Current Period Other Comprehensive Income (Loss) 0.3 — 0.3 Balance in AOCI as of September 30, 2021 $ (1.5) $ (6.5) $ (8.0) AEP Texas Cash Flow Hedge – Pension Nine Months Ended September 30, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2021 $ (1.3) $ (5.2) $ (6.5) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.0 — 1.0 Amortization of Prior Service Cost (Credit) — (0.1) (0.1) Amortization of Actuarial (Gains) Losses — 0.1 0.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.0 — 1.0 Income Tax (Expense) Benefit 0.2 — 0.2 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.8 — 0.8 Net Current Period Other Comprehensive Income (Loss) 0.8 — 0.8 Balance in AOCI as of September 30, 2022 $ (0.5) $ (5.2) $ (5.7) Cash Flow Hedge – Pension Nine Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2020 $ (2.3) $ (6.6) $ (8.9) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.0 — 1.0 Amortization of Prior Service Cost (Credit) — (0.1) (0.1) Amortization of Actuarial (Gains) Losses — 0.2 0.2 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.0 0.1 1.1 Income Tax (Expense) Benefit 0.2 — 0.2 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.8 0.1 0.9 Net Current Period Other Comprehensive Income (Loss) 0.8 0.1 0.9 Balance in AOCI as of September 30, 2021 $ (1.5) $ (6.5) $ (8.0) APCo Cash Flow Hedge – Pension Three Months Ended September 30, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2022 $ 7.1 $ 14.8 $ 21.9 Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (0.3) — (0.3) Amortization of Prior Service Cost (Credit) — (1.4) (1.4) Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.3) (1.4) (1.7) Income Tax (Expense) Benefit (0.1) (0.3) (0.4) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.2) (1.1) (1.3) Net Current Period Other Comprehensive Income (Loss) (0.2) (1.1) (1.3) Balance in AOCI as of September 30, 2022 $ 6.9 $ 13.7 $ 20.6 Cash Flow Hedge – Pension Three Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2021 $ 8.0 $ 5.9 $ 13.9 Change in Fair Value Recognized in AOCI 0.2 — 0.2 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (0.6) — (0.6) Amortization of Prior Service Cost (Credit) — (1.2) (1.2) Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.6) (1.2) (1.8) Income Tax (Expense) Benefit (0.1) (0.2) (0.3) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.5) (1.0) (1.5) Net Current Period Other Comprehensive Income (Loss) (0.3) (1.0) (1.3) Balance in AOCI as of September 30, 2021 $ 7.7 $ 4.9 $ 12.6 APCo Cash Flow Hedge – Pension Nine Months Ended September 30, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2021 $ 7.5 $ 16.9 $ 24.4 Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (0.8) — (0.8) Amortization of Prior Service Cost (Credit) — (4.1) (4.1) Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.8) (4.1) (4.9) Income Tax (Expense) Benefit (0.2) (0.9) (1.1) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.6) (3.2) (3.8) Net Current Period Other Comprehensive Income (Loss) (0.6) (3.2) (3.8) Balance in AOCI as of September 30, 2022 $ 6.9 $ 13.7 $ 20.6 Cash Flow Hedge – Pension Nine Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2020 $ (0.8) $ 8.0 $ 7.2 Change in Fair Value Recognized in AOCI 9.3 — 9.3 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (1.0) — (1.0) Amortization of Prior Service Cost (Credit) — (3.9) (3.9) Reclassifications from AOCI, before Income Tax (Expense) Benefit (1.0) (3.9) (4.9) Income Tax (Expense) Benefit (0.2) (0.8) (1.0) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.8) (3.1) (3.9) Net Current Period Other Comprehensive Income (Loss) 8.5 (3.1) 5.4 Balance in AOCI as of September 30, 2021 $ 7.7 $ 4.9 $ 12.6 I&M Cash Flow Hedge – Pension Three Months Ended September 30, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2022 $ (5.9) $ 5.2 $ (0.7) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.5 — 0.5 Amortization of Prior Service Cost (Credit) — (0.3) (0.3) Amortization of Actuarial (Gains) Losses — 0.1 0.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.5 (0.2) 0.3 Income Tax (Expense) Benefit 0.1 (0.1) — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.4 (0.1) 0.3 Net Current Period Other Comprehensive Income (Loss) 0.4 (0.1) 0.3 Balance in AOCI as of September 30, 2022 $ (5.5) $ 5.1 $ (0.4) Cash Flow Hedge – Pension Three Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2021 $ (7.4) $ 1.2 $ (6.2) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.5 — 0.5 Amortization of Prior Service Cost (Credit) — (0.2) (0.2) Amortization of Actuarial (Gains) Losses — 0.2 0.2 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.5 — 0.5 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.4 — 0.4 Net Current Period Other Comprehensive Income (Loss) 0.4 — 0.4 Balance in AOCI as of September 30, 2021 $ (7.0) $ 1.2 $ (5.8) I&M Cash Flow Hedge – Pension Nine Months Ended September 30, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2021 $ (6.7) $ 5.4 $ (1.3) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.5 — 1.5 Amortization of Prior Service Cost (Credit) — (0.7) (0.7) Amortization of Actuarial (Gains) Losses — 0.3 0.3 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.5 (0.4) 1.1 Income Tax (Expense) Benefit 0.3 (0.1) 0.2 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.2 (0.3) 0.9 Net Current Period Other Comprehensive Income (Loss) 1.2 (0.3) 0.9 Balance in AOCI as of September 30, 2022 $ (5.5) $ 5.1 $ (0.4) Cash Flow Hedge – Pension Nine Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2020 $ (8.3) $ 1.3 $ (7.0) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.6 — 1.6 Amortization of Prior Service Cost (Credit) — (0.6) (0.6) Amortization of Actuarial (Gains) Losses — 0.5 0.5 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.6 (0.1) 1.5 Income Tax (Expense) Benefit 0.3 — 0.3 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.3 (0.1) 1.2 Net Current Period Other Comprehensive Income (Loss) 1.3 (0.1) 1.2 Balance in AOCI as of September 30, 2021 $ (7.0) $ 1.2 $ (5.8) PSO Cash Flow Hedge – Three Months Ended September 30, 2022 Interest Rate (in millions) Balance in AOCI as of June 30, 2022 $ — 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 September 30, 2022 $ — Cash Flow Hedge – Three Months Ended September 30, 2021 Interest Rate (in millions) Balance in AOCI as of June 30, 2021 $ — 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 September 30, 2021 $ — Cash Flow Hedge – Nine Months Ended September 30, 2022 Interest Rate (in millions) Balance in AOCI as of December 31, 2021 $ — 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 September 30, 2022 $ — Cash Flow Hedge – Nine Months Ended September 30, 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 September 30, 2021 $ — SWEPCo Cash Flow Hedge – Pension Three Months Ended September 30, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2022 $ 1.2 $ 4.7 $ 5.9 Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Amortization of Prior Service Cost (Credit) — (0.5) (0.5) Reclassifications from AOCI, before Income Tax (Expense) Benefit — (0.5) (0.5) Income Tax (Expense) Benefit — (0.1) (0.1) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit — (0.4) (0.4) Net Current Period Other Comprehensive Income (Loss) — (0.4) (0.4) Balance in AOCI as of September 30, 2022 $ 1.2 $ 4.3 $ 5.5 Cash Flow Hedge – Pension Three Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2021 $ 0.5 $ 1.4 $ 1.9 Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.4 — 0.4 Amortization of Prior Service Cost (Credit) — (0.5) (0.5) Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.4 (0.5) (0.1) Income Tax (Expense) Benefit 0.1 (0.1) — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.3 (0.4) (0.1) Net Current Period Other Comprehensive Income (Loss) 0.3 (0.4) (0.1) Balance in AOCI as of September 30, 2021 $ 0.8 $ 1.0 $ 1.8 SWEPCo Cash Flow Hedge – Pension Nine Months Ended September 30, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2021 $ 1.2 $ 5.5 $ 6.7 Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Amortization of Prior Service Cost (Credit) — (1.5) (1.5) Reclassifications from AOCI, before Income Tax (Expense) Benefit — (1.5) (1.5) Income Tax (Expense) Benefit — (0.3) (0.3) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit — (1.2) (1.2) Net Current Period Other Comprehensive Income (Loss) — (1.2) (1.2) Balance in AOCI as of September 30, 2022 $ 1.2 $ 4.3 $ 5.5 Cash Flow Hedge – Pension Nine Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2020 $ (0.3) $ 2.2 $ 1.9 Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.4 — 1.4 Amortization of Prior Service Cost (Credit) — (1.5) (1.5) Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.4 (1.5) (0.1) Income Tax (Expense) Benefit 0.3 (0.3) — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.1 (1.2) (0.1) Net Current Period Other Comprehensive Income (Loss) 1.1 (1.2) (0.1) Balance in AOCI as of September 30, 2021 $ 0.8 $ 1.0 $ 1.8 (a) The change in fair value includes $(4) million and $(1) million, respectively, for the three months ended September 30, 2022 and 2021 and $(9) million and $(5) million, respectively, for the nine months ended September 30, 2022 and 2021 related to AEP's investment in joint venture wind farms acquired as part of the purchase of Sempra Renewables LLC. (b) Amounts reclassified to the referenced line item on the statements of income.

Rate Matters (Tables)

Rate Matters (Tables)	9 Months Ended
Rate Matters (Tables)	Sep. 30, 2022
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 $ 143.7 $ 141.4 $ 20.2 (b) 2026 (c) $ 14.9 Pirkey Plant 65.0 150.7 39.6 2023 (d) 12.5 Welsh Plant, Units 1 and 3 432.3 75.7 58.2 (e) 2028 (f) 39.8 (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 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 Pending Final Regulatory Approval	AEP September 30, December 31, 2022 2021 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Pirkey Plant Accelerated Depreciation $ 150.7 $ 87.0 Unrecovered Winter Storm Fuel Costs (a) 126.1 430.2 Welsh Plant, Units 1 and 3 Accelerated Depreciation 75.7 45.9 Dolet Hills Power Station Accelerated Depreciation 54.7 72.3 Plant Retirement Costs – Unrecovered Plant, Louisiana 35.2 35.2 Dolet Hills Power Station Fuel Costs - Louisiana 31.8 30.9 Other Regulatory Assets Pending Final Regulatory Approval 21.2 9.2 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 306.5 241.8 2017-2019 Virginia Triennial Under-Earnings 37.0 — Plant Retirement Costs – Asset Retirement Obligation Costs 25.9 25.9 2020-2022 Virginia Triennial Under-Earnings 25.3 15.1 COVID-19 8.7 11.2 Renewable Energy Portfolio Standards Costs - Virginia — 2.1 Other Regulatory Assets Pending Final Regulatory Approval 42.4 41.8 Total Regulatory Assets Pending Final Regulatory Approval $ 941.2 $ 1,048.6 (a) Includes $37 million and $63 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of September 30, 2022 and December 31, 2021, respectively. AEP Texas September 30, December 31, 2022 2021 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Mobile Generation Lease Payments $ 9.2 $ — Regulatory Assets Currently Not Earning a Return Storm-Related Costs 27.0 22.4 Vegetation Management Program 5.2 5.2 Texas Retail Electric Provider Bad Debt Expense 4.1 4.1 COVID-19 3.8 2.1 Other Regulatory Assets Pending Final Regulatory Approval 8.2 7.4 Total Regulatory Assets Pending Final Regulatory Approval $ 57.5 $ 41.2 APCo September 30, December 31, 2022 2021 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return COVID-19 – Virginia $ 7.0 $ 6.8 Regulatory Assets Currently Not Earning a Return Storm-Related Costs - West Virginia 69.9 53.7 2017-2019 Virginia Triennial Under-Earnings 37.0 — Plant Retirement Costs – Asset Retirement Obligation Costs 25.9 25.9 2020-2022 Virginia Triennial Under-Earnings 25.3 15.1 Renewable Energy Portfolio Standards Costs - Virginia — 2.1 Other Regulatory Assets Pending Final Regulatory Approval 1.6 1.5 Total Regulatory Assets Pending Final Regulatory Approval $ 166.7 $ 105.1 I&M September 30, December 31, 2022 2021 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Other Regulatory Assets Pending Final Regulatory Approval $ 0.1 $ 0.1 Regulatory Assets Currently Not Earning a Return COVID-19 0.1 1.7 Other Regulatory Assets Pending Final Regulatory Approval 1.7 1.9 Total Regulatory Assets Pending Final Regulatory Approval $ 1.9 $ 3.7 OPCo September 30, December 31, 2022 2021 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Not Earning a Return Storm-Related Costs $ 32.5 $ 3.8 Other Regulatory Assets Pending Final Regulatory Approval 0.1 — Total Regulatory Assets Pending Final Regulatory Approval $ 32.6 $ 3.8 PSO September 30, December 31, 2022 2021 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Not Earning a Return Storm-Related Costs $ 24.3 $ 13.9 Other Regulatory Assets Pending Final Regulatory Approval 0.1 0.3 Total Regulatory Assets Pending Final Regulatory Approval $ 24.4 $ 14.2 . SWEPCo September 30, December 31, 2022 2021 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Pirkey Plant Accelerated Depreciation $ 150.7 $ 87.0 Unrecovered Winter Storm Fuel Costs (a) 126.1 430.2 Welsh Plant, Units 1 and 3 Accelerated Depreciation 75.7 45.9 Dolet Hills Power Station Accelerated Depreciation 54.7 72.3 Plant Retirement Costs – Unrecovered Plant, Louisiana 35.2 35.2 Dolet Hills Power Station Fuel Costs- Louisiana 31.8 30.9 Other Regulatory Assets Pending Final Regulatory Approval 4.9 2.4 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 151.3 148.0 Asset Retirement Obligation - Louisiana 11.3 10.3 Other Regulatory Assets Pending Final Regulatory Approval 14.9 18.4 Total Regulatory Assets Pending Final Regulatory Approval $ 656.6 $ 880.6 (a) Includes $37 million and $63 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of September 30, 2022 and December 31, 2021, respectively.

Commitments, Guarantees and C_2

Commitments, Guarantees and Contingencies (Tables)	9 Months Ended
Commitments, Guarantees and Contingencies (Tables)	Sep. 30, 2022
Maximum Future Payments for Letters of Credit Uncommitted Facilities	Company Amount Maturity (in millions) AEP $ 309.9 October 2022 to August 2023 AEP Texas 1.8 July 2023
Max Potential Loss on Master Lease Agreements	Company Maximum (in millions) AEP $ 45.9 AEP Texas 10.9 APCo 6.3 I&M 4.3 OPCo 7.4 PSO 4.8 SWEPCo 5.4
Future Minimum Lease Payments for Sale and Leaseback	Future Minimum Lease Payments AEP (a) I&M (in millions) 2022 $ 174.9 $ 87.4 Total Future Minimum Lease Payments $ 174.9 $ 87.4 (a) AEP’s future minimum lease payments include equal shares from AEGCo and I&M.

Discontinued Operations and Dis

Discontinued Operations and Disposal Groups (Tables)	9 Months Ended
Discontinued Operations and Disposal Groups (Tables)	Sep. 30, 2022
Discontinued Operations and Disposal Groups [Abstract]
Lease, Cost	PSO SWEPCo September 30, 2022 December 31, 2021 September 30, 2022 December 31, 2021 (in millions) Project Sundance $ 12.6 $ 12.6 $ 15.0 $ 15.1 Maverick 18.0 18.0 21.6 21.6 Traverse 39.7 — 47.7 — Total $ 70.3 $ 30.6 $ 84.3 $ 36.7
Assets and Liabilities Held for Sale	AEP AEPTCo September 30, 2022 December 31, 2021 September 30, 2022 December 31, 2021 (in millions) ASSETS Accounts Receivable and Accrued Unbilled Revenues $ 77.8 $ 33.2 $ 1.7 $ 1.5 Fuel, Materials and Supplies 36.7 30.6 — — Property, Plant and Equipment, Net 2,387.4 2,302.7 167.0 165.3 Regulatory Assets 508.6 484.7 — — Other Classes of Assets that are not Major 38.1 68.5 5.0 1.1 Total Major Classes of Assets Held for Sale 3,048.6 2,919.7 173.7 167.9 Loss on the Expected Sale of Kentucky Operations (net of $45 million of Income Taxes) (218.0) — — — Assets Held for Sale $ 2,830.6 $ 2,919.7 $ 173.7 $ 167.9 LIABILITIES Accounts Payable $ 62.4 $ 53.4 $ 0.7 $ 1.1 Long-term Debt Due Within One Year 215.0 200.0 — — Customer Deposits 38.0 32.4 — — Deferred Income Taxes 497.8 441.6 16.4 15.4 Long-term Debt 963.4 903.1 — — Regulatory Liabilities and Deferred Investment Tax Credits 138.1 148.1 8.0 7.6 Other Classes of Liabilities that are not Major 77.3 102.3 2.5 3.5 Liabilities Held for Sale $ 1,992.0 $ 1,880.9 $ 27.6 $ 27.6

Benefit Plans (Tables)

Benefit Plans (Tables)	9 Months Ended
Benefit Plans (Tables)	Sep. 30, 2022
Components of Net Periodic Benefit Cost	AEP Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 30.7 $ 32.3 $ 1.8 $ 2.4 Interest Cost 37.1 34.3 7.3 7.7 Expected Return on Plan Assets (63.4) (57.4) (27.5) (22.8) Amortization of Prior Service Credit — — (17.9) (17.8) Amortization of Net Actuarial Loss 15.8 25.3 — — Net Periodic Benefit Cost (Credit) $ 20.2 $ 34.5 $ (36.3) $ (30.5) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 92.3 $ 96.9 $ 5.5 $ 7.2 Interest Cost 111.2 102.9 21.9 22.9 Expected Return on Plan Assets (190.1) (172.3) (82.5) (68.4) Amortization of Prior Service Credit — — (53.6) (53.2) Amortization of Net Actuarial Loss 47.3 76.1 — — Net Periodic Benefit Cost (Credit) $ 60.7 $ 103.6 $ (108.7) $ (91.5) AEP Texas Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 2.8 $ 3.0 $ 0.1 $ 0.2 Interest Cost 3.1 2.8 0.6 0.6 Expected Return on Plan Assets (5.3) (4.9) (2.3) (1.9) Amortization of Prior Service Credit — — (1.5) (1.5) Amortization of Net Actuarial Loss 1.2 2.1 — — Net Periodic Benefit Cost (Credit) $ 1.8 $ 3.0 $ (3.1) $ (2.6) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 8.4 $ 8.9 $ 0.3 $ 0.5 Interest Cost 9.1 8.4 1.7 1.8 Expected Return on Plan Assets (15.8) (14.6) (6.8) (5.6) Amortization of Prior Service Credit — — (4.5) (4.5) Amortization of Net Actuarial Loss 3.8 6.2 — — Net Periodic Benefit Cost (Credit) $ 5.5 $ 8.9 $ (9.3) $ (7.8) APCo Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 2.9 $ 3.0 $ 0.2 $ 0.3 Interest Cost 4.3 4.1 1.2 1.3 Expected Return on Plan Assets (8.1) (7.3) (4.1) (3.4) Amortization of Prior Service Credit — — (2.6) (2.6) Amortization of Net Actuarial Loss 1.9 3.0 — — Net Periodic Benefit Cost (Credit) $ 1.0 $ 2.8 $ (5.3) $ (4.4) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 8.6 $ 8.9 $ 0.6 $ 0.8 Interest Cost 13.1 12.3 3.5 3.7 Expected Return on Plan Assets (24.3) (21.8) (12.2) (10.1) Amortization of Prior Service Credit — — (7.8) (7.8) Amortization of Net Actuarial Loss 5.5 9.0 — — Net Periodic Benefit Cost (Credit) $ 2.9 $ 8.4 $ (15.9) $ (13.4) I&M Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 4.0 $ 4.4 $ 0.2 $ 0.4 Interest Cost 4.3 4.0 0.8 0.8 Expected Return on Plan Assets (8.1) (7.2) (3.3) (2.7) Amortization of Prior Service Credit — — (2.4) (2.5) Amortization of Net Actuarial Loss 1.8 2.9 — — Net Periodic Benefit Cost (Credit) $ 2.0 $ 4.1 $ (4.7) $ (4.0) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 12.1 $ 13.1 $ 0.7 $ 1.0 Interest Cost 12.7 12.1 2.5 2.6 Expected Return on Plan Assets (24.2) (21.6) (10.2) (8.3) Amortization of Prior Service Credit — — (7.3) (7.3) Amortization of Net Actuarial Loss 5.3 8.8 — — Net Periodic Benefit Cost (Credit) $ 5.9 $ 12.4 $ (14.3) $ (12.0) OPCo Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 2.8 $ 2.9 $ 0.2 $ 0.2 Interest Cost 3.4 3.1 0.7 0.7 Expected Return on Plan Assets (6.2) (5.7) (3.0) (2.4) Amortization of Prior Service Credit — — (1.8) (1.7) Amortization of Net Actuarial Loss 1.3 2.3 — — Net Periodic Benefit Cost (Credit) $ 1.3 $ 2.6 $ (3.9) $ (3.2) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 8.4 $ 8.6 $ 0.5 $ 0.6 Interest Cost 10.0 9.3 2.2 2.3 Expected Return on Plan Assets (18.6) (16.8) (8.9) (7.3) Amortization of Prior Service Credit — — (5.4) (5.3) Amortization of Net Actuarial Loss 4.1 6.8 — — Net Periodic Benefit Cost (Credit) $ 3.9 $ 7.9 $ (11.6) $ (9.7) PSO Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 1.8 $ 2.0 $ 0.2 $ 0.1 Interest Cost 1.8 1.7 0.4 0.4 Expected Return on Plan Assets (3.3) (3.0) (1.6) (1.3) Amortization of Prior Service Credit — — (1.1) (1.1) Amortization of Net Actuarial Loss 0.7 1.2 — — Net Periodic Benefit Cost (Credit) $ 1.0 $ 1.9 $ (2.1) $ (1.9) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 5.5 $ 6.0 $ 0.4 $ 0.4 Interest Cost 5.3 5.0 1.1 1.2 Expected Return on Plan Assets (10.1) (9.2) (4.6) (3.8) Amortization of Prior Service Credit — — (3.3) (3.3) Amortization of Net Actuarial Loss 2.2 3.7 — — Net Periodic Benefit Cost (Credit) $ 2.9 $ 5.5 $ (6.4) $ (5.5) SWEPCo Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 2.7 $ 2.7 $ 0.1 $ 0.3 Interest Cost 2.2 2.2 0.5 0.4 Expected Return on Plan Assets (3.6) (3.3) (1.8) (1.5) Amortization of Prior Service Credit — — (1.4) (1.4) Amortization of Net Actuarial Loss 0.9 1.5 — — Net Periodic Benefit Cost (Credit) $ 2.2 $ 3.1 $ (2.6) $ (2.2) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (in millions) Service Cost $ 8.0 $ 8.4 $ 0.4 $ 0.6 Interest Cost 6.8 6.4 1.4 1.4 Expected Return on Plan Assets (10.9) (10.1) (5.5) (4.5) Amortization of Prior Service Credit — — (4.0) (4.0) Amortization of Net Actuarial Loss 2.8 4.6 — — Net Periodic Benefit Cost (Credit) $ 6.7 $ 9.3 $ (7.7) $ (6.5)

Business Segments (Tables)

Business Segments (Tables)	9 Months Ended
Business Segments (Tables)	Sep. 30, 2022
Segment Reporting Information [Line Items]
Reportable Segment Information	Three Months Ended September 30, 2022 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) Revenues from: External Customers $ 3,174.6 $ 1,525.5 $ 81.9 $ 733.1 $ 11.0 $ — $ 5,526.1 Other Operating Segments 51.7 4.7 349.0 2.3 17.3 (425.0) — Total Revenues $ 3,226.3 $ 1,530.2 $ 430.9 $ 735.4 $ 28.3 $ (425.0) $ 5,526.1 Net Income (Loss) $ 476.9 $ 165.5 $ 171.4 $ 96.2 $ (226.7) $ — $ 683.3 Three Months Ended September 30, 2021 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) Revenues from: External Customers $ 2,716.8 $ 1,195.0 $ 90.3 $ 617.4 $ 3.5 $ — $ 4,623.0 Other Operating Segments 42.5 5.3 301.3 3.7 23.2 (376.0) — Total Revenues $ 2,759.3 $ 1,200.3 $ 391.6 $ 621.1 $ 26.7 $ (376.0) $ 4,623.0 Net Income (Loss) $ 438.7 $ 155.9 $ 167.9 $ 99.5 $ (65.1) $ — $ 796.9 Nine Months Ended September 30, 2022 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) Revenues from: External Customers $ 8,416.4 $ 4,064.5 $ 244.4 $ 1,997.0 $ 36.1 $ — $ 14,758.4 Other Operating Segments 145.8 14.1 976.7 17.3 36.6 (1,190.5) — Total Revenues $ 8,562.2 $ 4,078.6 $ 1,221.1 $ 2,014.3 $ 72.7 $ (1,190.5) $ 14,758.4 Net Income (Loss) $ 1,079.4 $ 483.1 $ 487.8 $ 278.1 $ (406.2) $ — $ 1,922.2 Nine Months Ended September 30, 2021 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) Revenues from: External Customers $ 7,445.9 $ 3,366.9 $ 264.6 $ 1,641.6 $ 11.6 $ — $ 12,730.6 Other Operating Segments 111.3 24.9 882.2 50.3 43.5 (1,112.2) — Total Revenues $ 7,557.2 $ 3,391.8 $ 1,146.8 $ 1,691.9 $ 55.1 $ (1,112.2) $ 12,730.6 Net Income (Loss) $ 938.9 $ 424.0 $ 510.7 $ 184.2 $ (108.3) $ — $ 1,949.5 September 30, 2022 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Consolidated (in millions) Total Assets (d) $ 49,056.9 $ 22,139.7 $ 14,708.9 $ 5,376.3 $ 6,278.3 (b) $ (6,310.7) (c) $ 91,249.4 December 31, 2021 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Consolidated (in millions) Total Assets (d) $ 46,974.2 $ 21,120.2 $ 13,873.3 $ 4,263.6 $ 5,846.5 (b) $ (4,409.1) (c) $ 87,668.7 (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) Amount includes Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 6 for additional information. Three Months Ended September 30, 2022 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Revenues from: External Customers $ 87.2 $ — $ — $ 87.2 Sales to AEP Affiliates 331.3 — — 331.3 Total Revenues $ 418.5 $ — $ — $ 418.5 Net Income $ 152.6 $ 0.1 (a) $ — $ 152.7 Three Months Ended September 30, 2021 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Revenues from: External Customers $ 79.2 $ — $ — $ 79.2 Sales to AEP Affiliates 297.6 — — 297.6 Other Revenues 0.2 — — 0.2 Total Revenues $ 377.0 $ — $ — $ 377.0 Net Income $ 145.3 $ 0.1 (a) $ — $ 145.4 Nine Months Ended September 30, 2022 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo Consolidated (in millions) Revenues from: External Customers $ 249.5 $ — $ — $ 249.5 Sales to AEP Affiliates 933.8 — — 933.8 Total Revenues $ 1,183.3 $ — $ — $ 1,183.3 Net Income $ 426.4 $ 0.2 (a) $ — $ 426.6 Nine Months Ended September 30, 2021 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo Consolidated (in millions) Revenues from: External Customers $ 239.3 $ — $ — $ 239.3 Sales to AEP Affiliates 864.6 — — 864.6 Other Revenues 0.3 — — 0.3 Total Revenues $ 1,104.2 $ — $ — $ 1,104.2 Net Income $ 445.5 $ 0.2 (a) $ — $ 445.7 September 30, 2022 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Total Assets (d) $ 13,359.9 $ 4,972.4 (b) $ (5,013.1) (c) $ 13,319.2 December 31, 2021 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Total Assets (d) $ 12,564.3 $ 4,389.5 (b) $ (4,429.4) (c) $ 12,524.4 (a) Includes the elimination of AEPTCo Parent’s equity earnings in the State Transcos. (b) Includes the elimination of AEPTCo Parent’s investments in State Transcos. (c) Primarily relates to the elimination of Notes Receivable from the State Transcos. (d) Amount includes Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.

Derivatives and Hedging (Tables

Derivatives and Hedging (Tables)	9 Months Ended
Derivatives and Hedging (Tables)	Sep. 30, 2022
Notional Volume of Derivative Instruments	Notional Volume of Derivative Instruments September 30, 2022 Primary Risk Unit of AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power MWhs 260.6 — 29.0 6.2 2.6 5.7 4.3 Natural Gas MMBtus 80.3 — — — — — 1.8 Heating Oil and Gasoline Gallons 6.4 1.7 0.9 0.6 1.3 0.7 0.9 Interest Rate USD $ 99.9 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt USD $ 1,150.0 $ — $ — $ — $ — $ — $ — 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 $ — $ — $ — $ — $ — $ —
Fair Value of Derivative Instruments	AEP September 30, 2022 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) $ 1,482.1 $ 411.1 $ 8.8 $ 1,902.0 $ (1,331.8) $ 570.2 Long-term Risk Management Assets 686.6 177.4 — 864.0 (598.2) 265.8 Total Assets 2,168.7 588.5 8.8 2,766.0 (1,930.0) 836.0 Current Risk Management Liabilities (e) 1,005.7 10.9 21.3 1,037.9 (850.6) 187.3 Long-term Risk Management Liabilities 501.6 4.9 114.1 620.6 (232.4) 388.2 Total Liabilities 1,507.3 15.8 135.4 1,658.5 (1,083.0) 575.5 Total MTM Derivative Contract Net Assets (Liabilities) (f) $ 661.4 $ 572.7 $ (126.6) $ 1,107.5 $ (847.0) $ 260.5 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 AEP Texas September 30, 2022 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 0.1 $ 0.1 $ 0.2 Long-term Risk Management Assets (0.1) 0.2 0.1 Total Assets — 0.3 0.3 Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — 0.1 0.1 Total Liabilities — 0.1 0.1 Total MTM Derivative Contract Net Assets $ — $ 0.2 $ 0.2 December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) 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 Contract Net Assets (Liabilities) $ 0.6 $ (0.6) $ — APCo September 30, 2022 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 106.8 $ — $ 106.8 Long-term Risk Management Assets 0.7 (0.6) 0.1 Total Assets 107.5 (0.6) 106.9 Current Risk Management Liabilities — — — Long-term Risk Management Liabilities 0.7 (0.7) — Total Liabilities 0.7 (0.7) — Total MTM Derivative Contract Net Assets (f) $ 106.8 $ 0.1 $ 106.9 December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 47.5 $ (5.5) $ 42.0 Long-term Risk Management Assets 0.2 (0.2) — Total Assets 47.7 (5.7) 42.0 Current Risk Management Liabilities 7.2 (6.4) 0.8 Long-term Risk Management Liabilities 0.2 (0.2) — Total Liabilities 7.4 (6.6) 0.8 Total MTM Derivative Contract Net Assets $ 40.3 $ 0.9 $ 41.2 I&M September 30, 2022 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 12.3 $ (0.9) $ 11.4 Long-term Risk Management Assets 0.6 (0.4) 0.2 Total Assets 12.9 (1.3) 11.6 Current Risk Management Liabilities 0.9 (0.9) — Long-term Risk Management Liabilities 0.5 (0.5) — Total Liabilities 1.4 (1.4) — Total MTM Derivative Contract Net Assets (f) $ 11.5 $ 0.1 $ 11.6 December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 11.1 $ (7.8) $ 3.3 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 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) OPCo September 30, 2022 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 2.0 $ 0.1 $ 2.1 Long-term Risk Management Assets (0.1) 0.1 — Total Assets 1.9 0.2 2.1 Current Risk Management Liabilities — — — Long-term Risk Management Liabilities 45.1 — 45.1 Total Liabilities 45.1 — 45.1 Total MTM Derivative Contract Net Assets (Liabilities) (f) $ (43.2) $ 0.2 $ (43.0) December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) 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) PSO September 30, 2022 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 44.4 $ 0.1 $ 44.5 Long-term Risk Management Assets — — — Total Assets 44.4 0.1 44.5 Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — — — Total Liabilities — — — Total MTM Derivative Contract Net Assets (f) $ 44.4 $ 0.1 $ 44.5 December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) 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 Contract Net Assets (Liabilities) $ 8.7 $ (0.3) $ 8.4 SWEPCo September 30, 2022 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 37.2 $ (0.8) $ 36.4 Long-term Risk Management Assets — 0.1 0.1 Total Assets 37.2 (0.7) 36.5 Current Risk Management Liabilities 0.8 (0.8) — Long-term Risk Management Liabilities — — — Total Liabilities 0.8 (0.8) — Total MTM Derivative Contract Net Assets (f) $ 36.4 $ 0.1 $ 36.5 December 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 10.1 $ (0.3) $ 9.8 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 Long-term Risk Management Liabilities — — — Total Liabilities 2.1 — 2.1 Total MTM Derivative Contract Net Assets (Liabilities) $ 9.1 $ (0.3) $ 8.8 (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 $14.4 million and $6 million as of September 30, 2022 and December 31, 2021, respectively, classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 for additional information. (e) Amount excludes Risk Management Liabilities of $0 and $0.1 million as of September 30, 2022 and December 31, 2021, respectively, classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 for additional information. (f) Increase in amounts as of September 30, 2022 are primarily due to increases in commodity prices for power and natural gas and an increase in value of FTRs.
Amount of Gain (Loss) Recognized on Risk Management Contracts	Amount of Gain (Loss) Recognized on Risk Management Contracts Three Months Ended September 30, 2022 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 2.1 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 116.7 — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.3 — — — — Other Revenues - Nonaffiliated — — — 1.9 — — — Purchased Electricity for Resale 0.9 — 0.9 0.1 — — — Other Operation 1.4 0.4 0.1 0.1 0.2 0.2 0.2 Maintenance 2.0 0.5 0.2 0.2 0.4 0.2 0.3 Regulatory Assets (a) 4.3 — — 0.1 4.1 — 0.1 Regulatory Liabilities (a) 103.2 (1.5) 59.7 3.8 0.9 19.7 7.0 Total Gain (Loss) on Risk Management Contracts (b) $ 230.6 $ (0.6) $ 61.2 $ 6.2 $ 5.6 $ 20.1 $ 7.6 Three Months Ended September 30, 2021 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ (0.9) $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 128.8 — — — — — — Electric Generation, Transmission and Distribution Revenues — — (0.9) — — — — Purchased Electricity for Resale 0.2 — 0.1 — — — — Other Operation 0.9 0.3 0.1 0.1 0.1 0.1 0.2 Maintenance 1.1 0.2 0.2 0.1 0.2 0.1 0.1 Regulatory Assets (a) (7.2) — (2.9) (16.9) 14.9 — 0.1 Regulatory Liabilities (a) 46.5 (0.1) 14.2 1.7 0.8 14.0 12.7 Total Gain (Loss) on Risk Management Contracts $ 169.4 $ 0.4 $ 10.8 $ (15.0) $ 16.0 $ 14.2 $ 13.1 Nine Months Ended September 30, 2022 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 2.2 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 390.0 — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.4 (0.1) — — — Other Revenues - Nonaffiliated — — — 1.9 — — — Purchased Electricity for Resale 3.3 — 3.0 0.1 — 0.1 — Other Operation 3.7 1.1 0.3 0.4 0.6 0.5 0.6 Maintenance 5.2 1.4 0.7 0.5 0.9 0.6 0.8 Regulatory Assets (a) 49.3 0.1 — (1.2) 49.0 3.6 (2.1) Regulatory Liabilities (a) 250.1 (0.6) 79.9 7.0 2.5 71.4 64.8 Total Gain on Risk Management Contracts (b) $ 703.8 $ 2.0 $ 84.3 $ 8.6 $ 53.0 $ 76.2 $ 64.1 Nine Months Ended September 30, 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 144.9 — — — — — — Electric Generation, Transmission and Distribution Revenues — — (0.6) — — — — Purchased Electricity for Resale 1.2 — 1.0 0.1 — — — Other Operation 1.9 0.6 0.2 0.2 0.3 0.2 0.3 Maintenance 2.4 0.6 0.4 0.2 0.4 0.2 0.3 Regulatory Assets (a) (7.9) — (2.9) (22.9) 20.3 — 1.4 Regulatory Liabilities (a) 123.6 0.5 28.9 1.9 5.9 40.2 38.5 Total Gain (Loss) on Risk Management Contracts $ 265.5 $ 1.7 $ 27.0 $ (20.5) $ 26.9 $ 40.6 $ 40.5 (a) Represents realized and unrealized gains and losses subject to regulatory accounting treatment recorded as either current or noncurrent on the balance sheets. (b) Increase in amounts for the three and nine months ended September 30, 2022 are primarily due to increases in commodity prices for power and natural gas and an increase in value of FTRs.
Impact of Fair Value Hedges on the Condensed Balance Sheet	Carrying Amount of the Hedged Liabilities Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of the Hedged Liabilities September 30, 2022 December 31, 2021 September 30, 2022 December 31, 2021 (in millions) Long-term Debt (a) (b) $ (849.1) $ (952.3) $ 95.7 $ (8.5) (a) Amounts included on the Balance Sheet within Current and Noncurrent Liabilities line items Long-term Debt Due within One Year and Long-term Debt, respectively.
Gain (Loss) on Hedging Instruments	Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (in millions) Gain (Loss) on Interest Rate Contracts: Fair Value Hedging Instruments (a) $ (36.0) $ (0.1) $ (98.4) $ (23.8) Fair Value Portion of Long-term Debt (a) 36.0 0.1 98.4 23.8 (a) Gain (Loss) is included in Interest Expense on the statements of income.
Impact of Cash Flow Hedges on the Condensed Balance Sheet	Impact of Cash Flow Hedges on AEP’s Balance Sheets September 30, 2022 December 31, 2021 Commodity Interest Rate Commodity Interest Rate (in millions) AOCI Gain (Loss) Net of Tax $ 452.1 $ (2.6) $ 163.7 $ (21.3) Portion Expected to be Reclassed to Net Income During the Next Twelve Months 316.2 (1.5) 106.7 (3.3) Impact of Cash Flow Hedges on the Registrant Subsidiaries’ Balance Sheets September 30, 2022 December 31, 2021 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 $ (0.5) $ (0.4) $ (1.3) $ (1.1) APCo 6.9 0.8 7.5 0.8 I&M (5.5) (1.0) (6.7) (1.6) SWEPCo 1.2 0.2 1.2 0.1

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
Fair Value Measurements (Tables)	Sep. 30, 2022
Book Values and Fair Values of Long-term Debt	September 30, 2022 December 31, 2021 Company Book Value Fair Value Book Value Fair Value (in millions) AEP (a)(b)(c) $ 35,050.1 $ 30,352.7 $ 33,454.5 $ 37,564.7 AEP Texas 5,693.9 4,889.7 5,180.8 5,663.8 AEPTCo 4,886.6 3,926.3 4,343.9 4,968.2 APCo 5,509.8 4,994.1 4,938.9 6,037.1 I&M 3,206.7 2,846.2 3,195.0 3,748.0 OPCo 2,969.9 2,442.0 2,968.5 3,437.5 PSO 1,913.6 1,616.9 1,913.5 2,163.7 SWEPCo 3,392.4 2,797.3 3,395.2 3,792.9 (a) The fair value amounts include debt related to AEP’s Equity Units and had a fair value of $842 million and $1.7 billion as of September 30, 2022 and December 31, 2021, respectively. See “Equity Units” section of Note 12 for additional information. (b) The book value amounts exclude Long-term Debt of $1.2 billion and $1.1 billion as of September 30, 2022 and December 31, 2021, respectively, classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.
Other Temporary Investments	September 30, 2022 Gross Gross Unrealized Unrealized Fair Other Temporary Investments and Restricted Cash Cost Gains Losses Value (in millions) Restricted Cash (a) $ 55.1 $ — $ — $ 55.1 Other Cash Deposits 18.1 — — 18.1 Fixed Income Securities – Mutual Funds (b) 155.1 — (9.7) 145.4 Equity Securities – Mutual Funds 20.4 18.6 (0.3) 38.7 Total Other Temporary Investments and Restricted Cash $ 248.7 $ 18.6 $ (10.0) $ 257.3 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 (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	Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (in millions) Proceeds from Investment Sales $ — $ 6.0 $ 15.0 $ 15.1 Purchases of Investments 11.8 12.9 13.4 26.0 Gross Realized Gains on Investment Sales — 2.4 3.6 3.6 Gross Realized Losses on Investment Sales — — 0.5 —
Nuclear Trust Fund Investments	September 30, 2022 December 31, 2021 Gross Other-Than- Gross Other-Than- Fair Unrealized Temporary Fair Unrealized Temporary Value Gains Impairments Value Gains Impairments (in millions) Cash and Cash Equivalents $ 20.8 $ — $ — $ 84.7 $ — $ — Fixed Income Securities: United States Government 1,115.2 (26.2) (39.8) 1,156.4 66.3 (7.9) Corporate Debt 60.9 (7.7) (1.2) 76.7 6.7 (2.1) State and Local Government 7.0 — (0.1) 7.3 0.4 (0.1) Subtotal Fixed Income Securities 1,183.1 (33.9) (41.1) 1,240.4 73.4 (10.1) Equity Securities - Domestic (a) 1,926.6 1,279.1 — 2,541.9 1,901.3 — Spent Nuclear Fuel and Decommissioning Trusts $ 3,130.5 $ 1,245.2 $ (41.1) $ 3,867.0 $ 1,974.7 $ (10.1)
Securities Activity Within the Decommissioning and SNF Trusts	Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (in millions) Proceeds from Investment Sales $ 588.5 $ 433.9 $ 1,818.4 $ 1,556.6 Purchases of Investments 601.6 436.6 1,854.8 1,586.3 Gross Realized Gains on Investment Sales 24.6 9.6 41.3 98.3 Gross Realized Losses on Investment Sales 8.4 7.0 33.5 12.5
Contractual Maturities, Fair Value of Debt Securities in Nuclear Trusts	Fair Value of Fixed Income Securities (in millions) Within 1 year $ 369.4 After 1 year through 5 years 393.8 After 5 years through 10 years 229.0 After 10 years 190.9 Total $ 1,183.1
Fair Value, Assets and Liabilities Measured on Recurring Basis	AEP Assets and Liabilities Measured at Fair Value on a Recurring Basis September 30, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments and Restricted Cash Restricted Cash $ 55.1 $ — $ — $ — $ 55.1 Other Cash Deposits (a) — — — 18.1 18.1 Fixed Income Securities – Mutual Funds 145.4 — — — 145.4 Equity Securities – Mutual Funds (b) 38.7 — — — 38.7 Total Other Temporary Investments and Restricted Cash 239.2 — — 18.1 257.3 Risk Management Assets Risk Management Commodity Contracts (c) (d) (i) 31.7 1,650.1 467.7 (1,910.8) 238.7 Cash Flow Hedges: Commodity Hedges (c) — 612.1 45.3 (68.9) 588.5 Interest Rate Hedges — 9.3 — (0.5) 8.8 Total Risk Management Assets 31.7 2,271.5 513.0 (1,980.2) 836.0 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 10.4 — — 10.4 20.8 Fixed Income Securities: United States Government — 1,115.2 — — 1,115.2 Corporate Debt — 60.9 — — 60.9 State and Local Government — 7.0 — — 7.0 Subtotal Fixed Income Securities — 1,183.1 — — 1,183.1 Equity Securities – Domestic (b) 1,926.6 — — — 1,926.6 Total Spent Nuclear Fuel and Decommissioning Trusts 1,937.0 1,183.1 — 10.4 3,130.5 Total Assets $ 2,207.9 $ 3,454.6 $ 513.0 $ (1,951.7) $ 4,223.8 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (d) (j) $ 20.1 $ 1,227.7 $ 240.5 $ (1,063.9) $ 424.4 Cash Flow Hedges: Commodity Hedges (c) — 83.7 0.9 (68.9) 15.7 Interest Rate Hedges — 0.5 — (0.5) — Fair Value Hedges — 135.4 — — 135.4 Total Risk Management Liabilities $ 20.1 $ 1,447.3 $ 241.4 $ (1,133.3) $ 575.5 AEP Assets and Liabilities Measured at Fair Value on a Recurring Basis 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) (f) (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) (f) (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 Texas Assets and Liabilities Measured at Fair Value on a Recurring Basis September 30, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 47.7 $ — $ — $ — $ 47.7 Risk Management Assets Risk Management Commodity Contracts (c) — 0.1 — 0.2 0.3 Total Assets $ 47.7 $ 0.1 $ — $ 0.2 $ 48.0 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 0.1 $ — $ — $ 0.1 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 APCo Assets and Liabilities Measured at Fair Value on a Recurring Basis September 30, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 7.4 $ — $ — $ — $ 7.4 Risk Management Assets Risk Management Commodity Contracts (c) (g) — 0.9 106.7 (0.8) 106.8 Total Assets $ 7.4 $ 0.9 $ 106.7 $ (0.8) $ 114.2 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 0.7 $ 0.1 $ (0.8) $ — 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 I&M Assets and Liabilities Measured at Fair Value on a Recurring Basis September 30, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 2.4 $ 10.3 $ (1.1) $ 11.6 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 10.4 — — 10.4 20.8 Fixed Income Securities: United States Government — 1,115.2 — — 1,115.2 Corporate Debt — 60.9 — — 60.9 State and Local Government — 7.0 — — 7.0 Subtotal Fixed Income Securities — 1,183.1 — — 1,183.1 Equity Securities - Domestic (b) 1,926.6 — — — 1,926.6 Total Spent Nuclear Fuel and Decommissioning Trusts 1,937.0 1,183.1 — 10.4 3,130.5 Total Assets $ 1,937.0 $ 1,185.5 $ 10.3 $ 9.3 $ 3,142.1 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 0.5 $ 0.7 $ (1.2) $ — 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 OPCo Assets and Liabilities Measured at Fair Value on a Recurring Basis September 30, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.1 $ — $ 2.0 $ 2.1 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 0.1 $ 43.2 $ 1.8 $ 45.1 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 (g) $ — $ — $ 92.5 $ — $ 92.5 PSO Assets and Liabilities Measured at Fair Value on a Recurring Basis September 30, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ — $ 45.2 $ (0.7) $ 44.5 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 0.8 $ (0.8) $ — 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 SWEPCo Assets and Liabilities Measured at Fair Value on a Recurring Basis September 30, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.1 $ 37.0 $ (0.7) $ 36.4 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 0.8 $ (0.8) $ — 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 (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 September 30, 2022 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $2 million in 2022 and $9 million in periods 2023-2025; Level 2 matures $47 million in 2022, $363 million in periods 2023-2025, $10 million in periods 2026-2027 and $3 million in periods 2028-2033; Level 3 matures $87 million in 2022, $139 million in periods 2023-2025, $18 million in periods 2026-2027 and $(2) 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, 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. (g) Substantially comprised of power contracts for the Registrant Subsidiaries. (h) See “Warrants Held in Investee” section of Note 10 in the 2021 Annual Report for additional information. (i) Amount excludes Risk Management Assets of $14.4 million and $6 million as of September 30, 2022 and December 31, 2021, respectively, classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 for additional information. (j) Amount excludes Risk Management Liabilities of $0 and $0.1 million as of September 30, 2022 and December 31, 2021, respectively, classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.
Changes in Fair Value of Net Trading Derivatives and Other Investments	Three Months Ended September 30, 2022 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of June 30, 2022 $ 270.4 $ 79.6 $ 9.8 $ (48.4) $ 64.5 $ 45.4 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 64.3 20.1 2.1 0.3 23.8 15.4 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (12.6) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 13.1 — — — — — Settlements (138.3) (34.6) (4.8) (1.1) (49.1) (31.6) Transfers into Level 3 (d) (e) (0.5) — — — — — Transfers out of Level 3 (e) 3.5 — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 72.5 41.5 2.5 6.0 5.2 7.0 Assets and Liabilities Held for Sale related to KPCo (g) (0.8) — — — — — Balance as of September 30, 2022 $ 271.6 $ 106.6 $ 9.6 $ (43.2) $ 44.4 $ 36.2 Three Months Ended September 30, 2021 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of June 30, 2021 $ 101.2 $ 36.6 $ 7.3 $ (105.4) $ 22.9 $ 14.6 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 27.5 4.0 0.1 0.1 13.5 5.8 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) 2.9 — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 17.8 — — — — — Settlements (54.5) (10.5) (3.8) 0.9 (20.6) (9.8) Transfers into Level 3 (d) (e) (5.8) — — — — — Transfers out of Level 3 (e) (4.1) 0.1 — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 44.0 15.7 (0.3) 14.0 2.7 9.0 Balance as of September 30, 2021 $ 129.0 $ 45.9 $ 3.3 $ (90.4) $ 18.5 $ 19.6 Nine Months Ended September 30, 2022 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of December 31, 2021 $ 97.3 $ 41.7 $ (0.7) $ (92.5) $ 12.1 $ 10.9 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 69.3 3.0 3.7 4.6 24.2 35.8 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (44.6) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 29.4 — — — — — Settlements (153.8) (44.7) (3.0) 0.2 (36.3) (45.0) Transfers into Level 3 (d) (e) 1.7 — — — — — Transfers out of Level 3 (e) 13.2 — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 267.6 106.6 9.6 44.5 44.4 34.5 Assets and Liabilities Held for Sale related to KPCo (g) (8.5) — — — — — Balance as of September 30, 2022 $ 271.6 $ 106.6 $ 9.6 $ (43.2) $ 44.4 $ 36.2 Nine Months Ended September 30, 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) 68.9 38.8 0.4 0.4 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) (64.1) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 35.5 — — — — — Settlements (113.3) (58.2) (2.5) 5.8 (26.4) (13.0) Transfers into Level 3 (d) (e) (0.2) — — — — — Transfers out of Level 3 (e) (26.2) — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 115.1 46.0 3.3 13.7 18.5 21.5 Balance as of September 30, 2021 $ 129.0 $ 45.9 $ 3.3 $ (90.4) $ 18.5 $ 19.6 (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 represents Risk Management Assets classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.
Significant Unobservable Inputs for Level 3	AEP Significant Unobservable Inputs September 30, 2022 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (c) (in millions) Energy Contracts $ 292.7 $ 230.6 Discounted Cash Flow Forward Market Price (a) $ (4.31) $ 172.05 $ 49.58 Natural Gas Contracts 6.9 — Discounted Cash Flow Forward Market Price (b) 3.22 7.37 5.92 FTRs (d) (e) 213.4 10.8 Discounted Cash Flow Forward Market Price (a) (37.97) 27.55 0.99 Total $ 513.0 $ 241.4 December 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (c) (in millions) Energy Contracts (f) $ 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 (g) (h) 77.5 13.0 Discounted Cash Flow Forward Market Price (a) (23.93) 26.38 0.86 Total $ 245.5 $ 148.2 APCo Significant Unobservable Inputs September 30, 2022 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) FTRs $ 106.7 $ 0.1 Discounted Cash Flow Forward Market Price $ (2.01) $ 20.64 $ 3.75 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 I&M Significant Unobservable Inputs September 30, 2022 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) FTRs $ 10.3 $ 0.7 Discounted Cash Flow Forward Market Price $ 0.21 $ 17.73 $ 1.61 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 OPCo Significant Unobservable Inputs September 30, 2022 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ — $ 43.2 Discounted Cash Flow Forward Market Price $ 1.65 $ 143.38 $ 47.12 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 PSO Significant Unobservable Inputs September 30, 2022 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) FTRs $ 45.2 $ 0.8 Discounted Cash Flow Forward Market Price $ (36.83) $ 5.65 $ (7.55) 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) SWEPCo Significant Unobservable Inputs September 30, 2022 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (c) (in millions) Natural Gas Contracts $ 6.9 $ — Discounted Cash Flow Forward Market Price (b) $ 6.15 $ 7.37 $ 6.94 FTRs 30.1 0.8 Discounted Cash Flow Forward Market Price (a) (36.83) 5.65 (7.55) Total $ 37.0 $ 0.8 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 (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) Amount excludes Risk Management Assets of $14.4 million classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 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 6 for additional information . (f) 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 6 for additional information . (g) 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 6 for additional information . (h) 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 6 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)

Income Taxes (Tables)

Income Taxes (Tables)	9 Months Ended
Income Taxes (Tables)	Sep. 30, 2022
Schedule of Effective Income Tax Rate Reconciliation	Three Months Ended September 30, 2022 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo U.S. Federal Statutory Rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % Increase (decrease) due to: State Income Tax, net of Federal Benefit (0.8) % 0.5 % 2.6 % (6.2) % 2.7 % 0.7 % 3.0 % (5.3) % Tax Reform Excess ADIT Reversal (9.7) % (2.0) % 0.3 % (8.6) % (13.3) % (6.2) % (21.9) % (4.6) % Production and Investment Tax Credits (12.0) % (0.4) % — % — % — % — % (43.7) % (24.1) % Flow Through (0.3) % 0.2 % 0.3 % (0.7) % (1.5) % 0.4 % 0.4 % (1.3) % AFUDC Equity (1.4) % (1.2) % (1.9) % (0.4) % (0.6) % (0.8) % (0.4) % (0.2) % Discrete Tax Adjustments (0.2) % — % — % — % — % — % — % — % Other 1.0 % 0.2 % 0.2 % — % (0.5) % 0.2 % 0.2 % (0.2) % Effective Income Tax Rate (2.4) % 18.3 % 22.5 % 5.1 % 7.8 % 15.3 % (41.4) % (14.7) % Three Months Ended September 30, 2021 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo U.S. Federal Statutory Rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % Increase (decrease) due to: State Income Tax, net of Federal Benefit 0.6 % 0.3 % 3.0 % (0.3) % 1.9 % 1.2 % 5.0 % (6.9) % Tax Reform Excess ADIT Reversal (8.5) % (6.3) % 0.3 % (14.2) % (16.1) % (8.9) % (19.8) % (4.2) % Production and Investment Tax Credits (4.7) % (0.3) % — % (0.2) % (2.0) % — % (8.9) % (5.4) % Flow Through — % 0.3 % 0.3 % 0.4 % (2.8) % 0.6 % 0.7 % (0.2) % AFUDC Equity (1.2) % (1.0) % (2.2) % (1.8) % (1.0) % (0.3) % (0.2) % (0.5) % Parent Company Loss Benefit — % (1.1) % (2.3) % (1.2) % (3.6) % — % — % 0.7 % Discrete Tax Adjustments 0.2 % — % — % — % — % — % — % 1.2 % Other 0.7 % (0.1) % 0.1 % 0.3 % 0.8 % — % (0.1) % (0.2) % Effective Income Tax Rate 8.1 % 12.8 % 20.2 % 4.0 % (1.8) % 13.6 % (2.3) % 5.5 % Nine Months Ended September 30, 2022 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo U.S. Federal Statutory Rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % Increase (decrease) due to: State Income Tax, net of Federal Benefit 0.7 % 0.5 % 2.7 % (0.8) % 1.3 % 0.8 % 3.2 % (1.5) % Tax Reform Excess ADIT Reversal (7.8) % (2.0) % 0.3 % (10.3) % (15.7) % (7.3) % (20.8) % (4.8) % Production and Investment Tax Credits (8.7) % (0.4) % — % — % (1.4) % — % (39.5) % (22.5) % Flow Through — % 0.2 % 0.3 % 0.2 % (1.6) % 0.5 % 0.3 % (0.8) % AFUDC Equity (1.1) % (1.2) % (1.9) % (0.8) % (0.8) % (0.7) % (0.4) % (0.4) % Discrete Tax Adjustments (0.2) % — % — % (1.8) % — % — % — % 0.3 % Other 0.6 % 0.1 % 0.1 % — % 0.2 % 0.1 % 0.2 % — % Effective Income Tax Rate 4.5 % 18.2 % 22.5 % 7.5 % 3.0 % 14.4 % (36.0) % (8.7) % Nine Months Ended September 30, 2021 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo U.S. Federal Statutory Rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % Increase (decrease) due to: State Income Tax, net of Federal Benefit 1.2 % 0.3 % 2.8 % 1.5 % 1.6 % 0.8 % 4.8 % (3.4) % Tax Reform Excess ADIT Reversal (8.9) % (7.2) % 0.3 % (15.2) % (17.7) % (9.1) % (19.8) % (4.3) % Production and Investment Tax Credits (4.9) % (0.3) % — % — % (2.2) % — % (8.1) % (4.6) % Flow Through 0.2 % 0.3 % 0.3 % 1.7 % (3.0) % 0.9 % 0.7 % (0.2) % AFUDC Equity (1.1) % (1.1) % (1.9) % (1.2) % (1.0) % (0.8) % (0.3) % (0.6) % Parent Company Loss Benefit — % (0.7) % (1.9) % (1.3) % (2.8) % — % — % — % Discrete Tax Adjustments 1.1 % — % — % — % — % (1.3) % (0.9) % 0.6 % Other 0.1 % — % — % 0.1 % 0.4 % 0.2 % (0.2) % (0.1) % Effective Income Tax Rate 8.7 % 12.3 % 20.6 % 6.6 % (3.7) % 11.7 % (2.8) % 8.4 %

Financing Activities (Tables)

Financing Activities (Tables)	9 Months Ended
Financing Activities (Tables)	Sep. 30, 2022
Long-term Debt	Type of Debt September 30, 2022 December 31, 2021 (in millions) Senior Unsecured Notes $ 28,892.7 $ 27,497.3 Pollution Control Bonds 1,804.9 1,804.5 Notes Payable 218.0 211.3 Securitization Bonds 524.8 603.5 Spent Nuclear Fuel Obligation (a) 283.2 281.3 Junior Subordinated Notes (b) 2,377.3 2,373.0 Other Long-term Debt 949.2 683.6 Total Long-term Debt Outstanding 35,050.1 33,454.5 Long-term Debt Due Within One Year (c) 1,403.5 2,153.8 Long-term Debt (d) $ 33,646.6 $ 31,300.7 (a) Pursuant to the Nuclear Waste Policy Act of 1982, I&M, a nuclear licensee, has an obligation to the United States Department of Energy for SNF disposal. The obligation includes a one-time fee for nuclear fuel consumed prior to April 7, 1983. Trust fund assets related to this obligation were $326 million and $329 million as of September 30, 2022 and December 31, 2021, respectively, and are included in Spent Nuclear Fuel and Decommissioning Trusts on the balance sheets. (b) See “Equity Units” section below for additional information. (c) Amount excludes $215 million and $200 million as of September 30, 2022 and December 31, 2021, respectively, of Long-term Debt Due Within One Year classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 6 for additional information. (d) Amount excludes $963 million and $903 million as of September 30, 2022 and December 31, 2021, respectively, of Long-term Debt classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.
Long-term Debt Issuances	Principal Interest Company Type of Debt Amount (a) Rate Due Date Issuances: (in millions) (%) AEP Texas Other Long-term Debt $ 200.0 Variable 2025 AEP Texas Senior Unsecured Notes 500.0 4.70 2032 AEP Texas Senior Unsecured Notes 500.0 5.25 2052 AEPTCo Senior Unsecured Notes 550.0 4.50 2052 APCo Other Long-term Debt 100.0 Variable 2023 APCo Pollution Control Bonds 104.4 3.75 2025 APCo Senior Unsecured Notes 500.0 4.50 2032 I&M Notes Payable 72.8 3.44 2026 PSO Other Long-term Debt 500.0 Variable 2022 Non-Registrant: AEGCo Pollution Control Bonds 45.0 3.13 2025 KPCo Other Long-term Debt 150.0 Variable 2023 Transource Energy Other Long-term Debt 5.0 Variable 2023 WPCo Other Long-term Debt 165.0 Variable 2024 WPCo Pollution Control Bonds 65.0 3.00 2027 Total Issuances $ 3,457.2 (a) Amounts indicated on the statements of cash flows are net of issuance costs and premium or discount and will not tie to the issuance amounts.
Retirements and Principal Payments	Principal Interest Company Type of Debt Amount Paid Rate Due Date Retirements and Principal Payments: (in millions) (%) AEP Texas Other Long-term Debt $ 200.0 Variable 2022 AEP Texas Senior Unsecured Notes 400.0 2.40 2022 AEP Texas Senior Unsecured Notes 25.0 3.27 2022 AEP Texas Securitization Bonds 30.6 2.85 2024 AEP Texas Securitization Bonds 23.0 2.06 2025 APCo Pollution Control Bonds 104.4 2.63 2022 APCo Securitization Bonds 25.9 2.01 2023 APCo Other Long-term Debt 0.1 13.72 2026 I&M Notes Payable 3.4 Variable 2022 I&M Notes Payable 1.3 Variable 2022 I&M Notes Payable 6.7 Variable 2023 I&M Notes Payable 10.8 Variable 2024 I&M Notes Payable 18.9 0.93 2025 I&M Notes Payable 13.7 Variable 2025 I&M Notes Payable 8.0 3.44 2026 I&M Other Long-term Debt 1.7 6.00 2025 OPCo Other Long-term Debt 0.1 1.15 2028 PSO Other Long-term Debt 500.0 Variable 2022 PSO Other Long-term Debt 0.4 3.00 2027 SWEPCo Other Long-term Debt 1.5 4.68 2028 SWEPCo Notes Payable 3.2 4.58 2032 Non-Registrant: AEGCo Pollution Control Bonds 45.0 1.35 2022 KPCo Other Long-term Debt 75.0 Variable 2022 Transource Energy Senior Unsecured Notes 2.4 2.75 2050 WPCo Pollution Control Bonds 65.0 3.00 2022 WPCo Senior Unsecured Notes 113.0 3.36 2022 Total Retirements and Principal Payments $ 1,679.1
Utility Money Pool Participants' Money Pool Activity and Authorized Borrowing Limits	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 September 30, 2022 Limit (in millions) AEP Texas $ 348.8 $ 652.3 $ 208.1 $ 319.8 $ 129.5 $ 500.0 AEPTCo 480.2 137.0 197.4 31.3 78.7 (a) 820.0 (b) APCo 438.4 214.2 180.9 52.8 182.1 500.0 I&M 159.1 22.6 86.0 22.1 (82.3) 500.0 OPCo 147.2 246.1 59.9 86.9 (68.8) 500.0 PSO 338.3 432.5 200.9 402.8 (223.5) 400.0 SWEPCo 261.6 156.6 191.0 109.7 (156.3) 400.0 (a) Amount excludes $5 million of Advances to Affiliates classified as Assets Held for Sale on the AEPTCo balance sheet. See “Dispositions of KPCo and KTCo” section of Note 6 for additional information. (b) Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions.
Nonutility Money Pool Activity	Maximum Loans Average Loans Loans to the Nonutility to the Nonutility to the Nonutility Money Pool as of Company Money Pool Money Pool September 30, 2022 (in millions) AEP Texas $ 6.9 $ 6.8 $ 6.8 SWEPCo 2.1 2.1 2.1
Direct Borrowing Activity	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 September 30, 2022 September 30, 2022 Borrowing Limit (in millions) $ 52.4 $ 141.8 $ 7.1 $ 59.6 $ 33.0 $ — $ 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	Nine Months Ended September 30, 2022 2021 Maximum Interest Rate 3.39 % 0.40 % Minimum Interest Rate 0.10 % 0.02 %
Average Interest Rates for Funds Borrowed from and Loaned to Utility Money Pool	Average Interest Rate for Funds Average Interest Rate for Funds Borrowed from the Utility Money Pool Loaned to the Utility Money Pool for Nine Months Ended September 30, for Nine Months Ended September 30, Company 2022 2021 2022 2021 AEP Texas 0.90 % 0.33 % 1.82 % 0.27 % AEPTCo 1.03 % 0.32 % 2.14 % 0.07 % APCo 1.39 % 0.28 % 2.13 % 0.28 % I&M 1.38 % 0.32 % 1.46 % 0.25 % OPCo 1.81 % 0.27 % 1.22 % 0.15 % PSO 1.70 % 0.34 % 0.75 % 0.06 % SWEPCo 1.67 % 0.28 % 0.55 % 0.38 %
Maximum Minimum Average Interest Rates for Funds Borrowed from Loaned to Nonutility Money Pool	Nine Months Ended September 30, 2022 Nine Months Ended September 30, 2021 Maximum Minimum Average Maximum Minimum 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 Loaned to Loaned to Loaned to Loaned to Loaned to Loaned to the Nonutility the Nonutility the Nonutility the Nonutility the Nonutility the Nonutility Company Money Pool Money Pool Money Pool Money Pool Money Pool Money Pool AEP Texas 3.39 % 0.46 % 1.51 % 0.41 % 0.21 % 0.34 % SWEPCo 3.39 % 0.46 % 1.52 % 0.41 % 0.21 % 0.34 %
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 Nine Months for Funds for Funds for Funds for Funds for Funds for Funds Ended Borrowed Borrowed Loaned Loaned Borrowed Loaned September 30, from AEP from AEP to AEP to AEP from AEP to AEP 2022 3.39 % 0.46 % 3.37 % 0.46 % 1.56 % 1.38 % 2021 0.86 % 0.25 % 0.86 % 0.25 % 0.35 % 0.34 %
Short Term Debt	September 30, 2022 December 31, 2021 Outstanding Interest Outstanding Interest Company Type of Debt Amount Rate (a) Amount Rate (a) (dollars in millions) AEP Securitized Debt for Receivables (b) $ 750.0 1.16 % $ 750.0 0.19 % AEP Commercial Paper 1,952.3 3.38 % 1,364.0 0.34 % AEP Term Loan — — % 500.0 0.81 % Total Short-term Debt $ 2,702.3 $ 2,614.0 (a) Weighted-average rate. (b) Amount of securitized debt for receivables as accounted for under the “Transfers and Servicing” accounting guidance.
Comparative Accounts Receivable Information	Three Months Ended September 30, Nine Months Ended September 30, 2022 2021 2022 2021 (dollars in millions) Effective Interest Rates on Securitization of Accounts Receivable 2.25 % 0.18 % 1.16 % 0.19 % Net Uncollectible Accounts Receivable Written-Off $ 9.5 $ 7.5 $ 23.1 $ 22.6
Customer Accounts Receivable Managed Portfolio	September 30, 2022 December 31, 2021 (in millions) Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts $ 1,172.5 $ 995.2 Short-term – Securitized Debt of Receivables 750.0 750.0 Delinquent Securitized Accounts Receivable 57.4 57.9 Bad Debt Reserves Related to Securitization 39.4 42.8 Unbilled Receivables Related to Securitization 252.3 307.1
Accounts Receivable and Accrued Unbilled Revenues	Company September 30, 2022 December 31, 2021 (in millions) APCo $ 127.5 $ 153.1 I&M 187.8 156.9 OPCo 476.7 392.7 PSO 188.4 114.5 SWEPCo 217.0 153.0
Fees Paid to AEP Credit for Customer Accounts Receivable Sold	Three Months Ended September 30, Nine Months Ended September 30, Company 2022 2021 (a) 2022 2021 (a) (in millions) APCo $ 2.8 $ 1.3 $ 5.6 $ 3.7 I&M 2.8 2.1 6.5 5.3 OPCo 7.3 4.6 22.2 3.5 PSO 2.4 1.1 4.6 2.4 SWEPCo 3.2 1.3 6.0 4.1 (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.
Proceeds on Sale of Receivables to AEP Credit	Three Months Ended September 30, Nine Months Ended September 30, Company 2022 2021 2022 2021 (in millions) APCo $ 360.4 $ 342.2 $ 1,114.9 $ 980.6 I&M 558.5 536.8 1,574.3 1,478.9 OPCo 874.1 668.4 2,284.0 1,867.5 PSO 588.5 460.1 1,380.4 1,068.8 SWEPCo 593.6 488.5 1,425.3 1,265.5

Property, Plant and Equipment_2

Property, Plant and Equipment (Tables)	9 Months Ended
Property, Plant and Equipment (Tables)	Sep. 30, 2022
Asset Retirement Obligation (ARO)	Company ARO as of December 31, 2021 Accretion Liabilities Liabilities Revisions in ARO as of September 30, 2022 (in millions) AEP (a)(b)(c)(d)(e) $ 2,741.7 $ 82.1 $ 37.4 $ (29.4) $ 90.9 $ 2,922.7 PSO (a)(d) 57.6 3.0 12.8 (0.6) 1.9 74.7 SWEPCo (a)(c)(d) 222.7 8.3 15.4 (16.9) 48.0 277.5 (a) Includes ARO related to ash disposal facilities. (b) Includes ARO related to nuclear decommissioning costs for the Cook Plant of $1.98 billion and $1.93 billion as of September 30, 2022 and December 31, 2021, respectively. (c) Includes ARO related to Sabine and DHLC. (d) Includes ARO related to asbestos removal. (e) Includes $18 million and $18 million as of September 30, 2022 and December 31, 2021, respectively, of ARO classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	9 Months Ended
Revenue from Contracts with Customers (Tables)	Sep. 30, 2022
Disaggregated Revenues from Contracts with Customers	Three Months Ended September 30, 2022 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 $ 1,298.0 $ 721.9 $ — $ — $ — $ — $ 2,019.9 Commercial Revenues 725.1 373.0 — — — — 1,098.1 Industrial Revenues 658.5 191.5 — — — (0.3) 849.7 Other Retail Revenues 54.3 15.0 — — — — 69.3 Total Retail Revenues 2,735.9 1,301.4 — — — (0.3) 4,037.0 Wholesale and Competitive Retail Revenues: Generation Revenues 299.3 — — 83.7 — (0.2) 382.8 Transmission Revenues (a) 120.3 162.3 424.9 — — (392.7) 314.8 Renewable Generation Revenues (b) — — — 44.3 — (2.5) 41.8 Retail, Trading and Marketing Revenues — — — 482.9 2.2 0.2 485.3 Total Wholesale and Competitive Retail Revenues 419.6 162.3 424.9 610.9 2.2 (395.2) 1,224.7 Other Revenues from Contracts with Customers (c) 69.7 74.5 (0.3) 1.7 24.3 (31.9) 138.0 Total Revenues from Contracts with Customers 3,225.2 1,538.2 424.6 612.6 26.5 (427.4) 5,399.7 Other Revenues: Alternative Revenues (b) 0.9 (13.5) 6.3 — — 4.4 (1.9) Other Revenues (b) (d) 0.2 5.5 — 122.8 1.8 (2.0) 128.3 Total Other Revenues 1.1 (8.0) 6.3 122.8 1.8 2.4 126.4 Total Revenues $ 3,226.3 $ 1,530.2 $ 430.9 $ 735.4 $ 28.3 $ (425.0) $ 5,526.1 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $342 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 Corporate and Other was $18 million. The remaining affiliated amounts were immaterial. (d) Generation & Marketing includes economic hedge activity. Three Months Ended September 30, 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 $ 1,144.3 $ 598.0 $ — $ — $ — $ — $ 1,742.3 Commercial Revenues 618.9 279.9 — — — — 898.8 Industrial Revenues 566.0 95.2 — — — (0.1) 661.1 Other Retail Revenues 47.5 11.1 — — — — 58.6 Total Retail Revenues 2,376.7 984.2 — — — (0.1) 3,360.8 Wholesale and Competitive Retail Revenues: Generation Revenues 233.8 — — 47.8 — — 281.6 Transmission Revenues (a) 99.8 150.6 375.8 — — (317.4) 308.8 Renewable Generation Revenues (b) — — — 24.1 — (0.6) 23.5 Retail, Trading and Marketing Revenues (c) — — — 397.1 0.1 (3.1) 394.1 Total Wholesale and Competitive Retail Revenues 333.6 150.6 375.8 469.0 0.1 (321.1) 1,008.0 Other Revenues from Contracts with Customers (b) 49.4 54.2 5.1 1.4 23.5 (40.1) 93.5 Total Revenues from Contracts with Customers 2,759.7 1,189.0 380.9 470.4 23.6 (361.3) 4,462.3 Other Revenues: Alternative Revenues (b) 0.5 6.4 10.7 — — (11.7) 5.9 Other Revenues (b) (d) (0.9) 4.9 — 150.7 3.1 (3.0) 154.8 Total Other Revenues (0.4) 11.3 10.7 150.7 3.1 (14.7) 160.7 Total Revenues $ 2,759.3 $ 1,200.3 $ 391.6 $ 621.1 $ 26.7 $ (376.0) $ 4,623.0 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $286 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 $4 million. The remaining affiliated amounts were immaterial. (d) Generation & Marketing includes economic hedge activity. Three Months Ended September 30, 2022 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 204.0 $ — $ 360.5 $ 238.6 $ 517.9 $ 299.6 $ 285.5 Commercial Revenues 107.1 — 161.1 154.3 266.1 153.4 182.3 Industrial Revenues 35.4 — 163.3 155.6 156.1 98.9 108.3 Other Retail Revenues 11.5 — 20.6 1.2 3.5 30.1 0.6 Total Retail Revenues 358.0 — 705.5 549.7 943.6 582.0 576.7 Wholesale Revenues: Generation Revenues (a) — — 107.9 126.3 — 9.4 87.6 Transmission Revenues (b) 140.8 411.7 41.5 8.8 21.5 10.2 42.3 Total Wholesale Revenues 140.8 411.7 149.4 135.1 21.5 19.6 129.9 Other Revenues from Contracts with Customers (c) 9.5 (0.3) 33.7 30.6 64.8 6.4 7.6 Total Revenues from Contracts with Customers 508.3 411.4 888.6 715.4 1,029.9 608.0 714.2 Other Revenues: Alternative Revenues (d) 0.6 7.1 — — (14.1) 0.2 3.3 Other Revenues (d) — — 0.3 — 5.5 — — Total Other Revenues 0.6 7.1 0.3 — (8.6) 0.2 3.3 Total Revenues $ 508.9 $ 418.5 $ 888.9 $ 715.4 $ 1,021.3 $ 608.2 $ 717.5 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $44 million primarily related to the PPA with KGPCo. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $339 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $15 million primarily related to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. Three Months Ended September 30, 2021 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 172.5 $ — $ 340.1 $ 231.7 $ 425.4 $ 236.8 $ 230.9 Commercial Revenues 89.1 — 146.9 143.9 190.8 120.9 145.4 Industrial Revenues 25.4 — 154.8 146.8 69.8 77.1 85.4 Other Retail Revenues 8.2 — 18.6 1.3 3.1 23.4 2.3 Total Retail Revenues 295.2 — 660.4 523.7 689.1 458.2 464.0 Wholesale Revenues: Generation Revenues (a) — — 83.7 80.2 — 7.2 77.1 Transmission Revenues (b) 131.5 360.1 35.2 8.7 19.1 10.6 37.1 Total Wholesale Revenues 131.5 360.1 118.9 88.9 19.1 17.8 114.2 Other Revenues from Contracts with Customers (c) 6.8 5.0 22.5 24.2 47.3 8.3 6.1 Total Revenues from Contracts with Customers 433.5 365.1 801.8 636.8 755.5 484.3 584.3 Other Revenues: Alternative Revenues (d) (0.9) 11.9 2.2 (1.1) 7.3 (0.5) (0.2) Other Revenues (d) — — — — 4.9 — — Total Other Revenues (0.9) 11.9 2.2 (1.1) 12.2 (0.5) (0.2) Total Revenues $ 432.6 $ 377.0 $ 804.0 $ 635.7 $ 767.7 $ 483.8 $ 584.1 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $30 million primarily related to the PPA with KGPCo. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $281 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $17 million primarily related to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. Nine Months Ended September 30, 2022 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 $ 3,428.1 $ 1,884.1 $ — $ — $ — $ — $ 5,312.2 Commercial Revenues 1,922.8 994.4 — — — — 2,917.2 Industrial Revenues (b) 1,863.3 487.3 — — — (0.7) 2,349.9 Other Retail Revenues 154.6 39.4 — — — — 194.0 Total Retail Revenues 7,368.8 3,405.2 — — — (0.7) 10,773.3 Wholesale and Competitive Retail Revenues: Generation Revenues (b) 674.8 — — 207.0 — (0.1) 881.7 Transmission Revenues (a) 334.4 482.1 1,261.0 — — (1,086.5) 991.0 Renewable Generation Revenues (b) — — — 104.9 — (6.2) 98.7 Retail, Trading and Marketing Revenues (c) — — — 1,280.0 6.7 (11.1) 1,275.6 Total Wholesale and Competitive Retail Revenues 1,009.2 482.1 1,261.0 1,591.9 6.7 (1,103.9) 3,247.0 Other Revenues from Contracts with Customers (d) 180.5 194.2 (0.3) 11.9 59.1 (71.6) 373.8 Total Revenues from Contracts with Customers 8,558.5 4,081.5 1,260.7 1,603.8 65.8 (1,176.2) 14,394.1 Other Revenues: Alternative Revenues (b) 3.4 (21.5) (39.6) — — (7.4) (65.1) Other Revenues (b) (e) 0.3 18.6 — 410.5 6.9 (6.9) 429.4 Total Other Revenues 3.7 (2.9) (39.6) 410.5 6.9 (14.3) 364.3 Total Revenues $ 8,562.2 $ 4,078.6 $ 1,221.1 $ 2,014.3 $ 72.7 $ (1,190.5) $ 14,758.4 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $1 billion. The affiliated revenue for Vertically Integrated Utilities was $120 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 $11 million. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $36 million. The remaining affiliated amounts were immaterial. (e) Generation & Marketing includes economic hedge activity. Nine Months Ended September 30, 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 $ 3,016.2 $ 1,641.2 $ — $ — $ — $ — $ 4,657.4 Commercial Revenues 1,642.0 804.1 — — — — 2,446.1 Industrial Revenues 1,602.5 283.8 — — — (0.5) 1,885.8 Other Retail Revenues 125.9 32.4 — — — — 158.3 Total Retail Revenues 6,386.6 2,761.5 — — — (0.5) 9,147.6 Wholesale and Competitive Retail Revenues: Generation Revenues 757.1 — — 119.4 — — 876.5 Transmission Revenues (a) 267.3 420.7 1,092.1 — — (901.5) 878.6 Renewable Generation Revenues (b) — — — 66.7 — (1.7) 65.0 Retail, Trading and Marketing Revenues (c) — — — 1,325.6 0.6 (48.5) 1,277.7 Total Wholesale and Competitive Retail Revenues 1,024.4 420.7 1,092.1 1,511.7 0.6 (951.7) 3,097.8 Other Revenues from Contracts with Customers (b) 136.1 149.3 12.5 4.9 46.1 (87.9) 261.0 Total Revenues from Contracts with Customers 7,547.1 3,331.5 1,104.6 1,516.6 46.7 (1,040.1) 12,506.4 Other Revenues: Alternative Revenues (b) 10.7 46.1 42.2 — — (63.5) 35.5 Other Revenues (b) (d) (0.6) 14.2 — 175.3 8.4 (8.6) 188.7 Total Other Revenues 10.1 60.3 42.2 175.3 8.4 (72.1) 224.2 Total Revenues $ 7,557.2 $ 3,391.8 $ 1,146.8 $ 1,691.9 $ 55.1 $ (1,112.2) $ 12,730.6 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $835 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 $49 million. The remaining affiliated amounts were immaterial. (d) Generation & Marketing includes economic hedge activity. Nine Months Ended September 30, 2022 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 520.8 $ — $ 1,131.7 $ 665.6 $ 1,363.3 $ 650.7 $ 650.0 Commercial Revenues 312.6 — 467.6 419.5 681.9 372.1 458.8 Industrial Revenues (d) 102.6 — 479.0 452.1 384.8 270.0 290.1 Other Retail Revenues 29.2 — 61.4 3.7 10.2 77.1 7.4 Total Retail Revenues 965.2 — 2,139.7 1,540.9 2,440.2 1,369.9 1,406.3 Wholesale Revenues: Generation Revenues (a) — — 227.6 310.9 — 19.2 206.2 Transmission Revenues (b) 417.7 1,218.1 123.4 26.3 64.4 28.9 116.8 Total Wholesale Revenues 417.7 1,218.1 351.0 337.2 64.4 48.1 323.0 Other Revenues from Contracts with Customers (c) 24.4 (0.4) 78.6 86.3 169.6 21.4 18.9 Total Revenues from Contracts with Customers 1,407.3 1,217.7 2,569.3 1,964.4 2,674.2 1,439.4 1,748.2 Other Revenues: Alternative Revenues (d) (2.9) (34.4) 0.1 7.3 (18.6) (0.7) 0.7 Other Revenues (d) — — 0.4 (0.1) 18.6 — — Total Other Revenues (2.9) (34.4) 0.5 7.2 — (0.7) 0.7 Total Revenues $ 1,404.4 $ 1,183.3 $ 2,569.8 $ 1,971.6 $ 2,674.2 $ 1,438.7 $ 1,748.9 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $122 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 $992 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $44 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. Nine Months Ended September 30, 2021 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 423.7 $ — $ 1,025.0 $ 624.4 $ 1,217.5 $ 516.4 $ 547.1 Commercial Revenues 265.2 — 409.5 384.5 538.9 286.8 385.4 Industrial Revenues 81.6 — 433.4 418.9 202.2 202.1 247.1 Other Retail Revenues 23.1 — 51.7 3.9 9.4 58.2 7.2 Total Retail Revenues 793.6 — 1,919.6 1,431.7 1,968.0 1,063.5 1,186.8 Wholesale Revenues: Generation Revenues (a) — — 231.2 248.1 — 6.8 326.2 Transmission Revenues (b) 364.5 1,045.2 94.1 25.3 56.2 28.8 94.5 Total Wholesale Revenues 364.5 1,045.2 325.3 273.4 56.2 35.6 420.7 Other Revenues from Contracts with Customers (c) 35.4 12.5 43.6 81.9 113.8 24.8 17.7 Total Revenues from Contracts with Customers 1,193.5 1,057.7 2,288.5 1,787.0 2,138.0 1,123.9 1,625.2 Other Revenues: Alternative Revenues (d) 1.8 46.5 9.5 (3.0) 44.3 0.5 5.1 Other Revenues (d) — — — — 14.2 — — Total Other Revenues 1.8 46.5 9.5 (3.0) 58.5 0.5 5.1 Total Revenues $ 1,195.3 $ 1,104.2 $ 2,298.0 $ 1,784.0 $ 2,196.5 $ 1,124.4 $ 1,630.3 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $90 million primarily relating to the PPA with KGPCo. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $823 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $46 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 $ 318.7 $ 172.1 $ 157.8 $ 96.9 $ 745.5 AEP Texas 145.8 — — — 145.8 AEPTCo 369.4 — — — 369.4 APCo 50.1 33.7 26.6 11.5 121.9 I&M 9.7 13.6 9.2 4.5 37.0 OPCo 19.2 3.4 — — 22.6 PSO 3.4 — — — 3.4 SWEPCo 10.9 — — — 10.9
Affiliated Accounts Receivable Contracts with Customers	Company September 30, 2022 December 31, 2021 (in millions) AEP Texas $ — $ 0.4 AEPTCo 110.6 95.5 APCo 65.8 117.8 I&M 51.1 61.2 OPCo 61.5 51.7 PSO 36.8 18.8 SWEPCo 20.2 24.7

Significant Accounting Matter_3

Significant Accounting Matters (Details) - USD ($) $ / shares in Units, $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021	Dec. 31, 2020
Amounts Attributable to AEP Common Shareholders
Earnings Attributable to Common Shareholders		$ 683,700	$ 796,000	$ 1,922,900	$ 1,949,200
Total Basic Earnings Per Share Attributable to AEP Common Shareholders		$ 1.33	$ 1.59	$ 3.76	$ 3.90
Weighted Average Dilutive Effect of:
Total Diluted Earnings Per Share Attributable to AEP Common Shareholders		$ 1.33	$ 1.58	$ 3.75	$ 3.89
Organization and Summary of Significant Accounting Policies (Textuals)
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount				0	377,000
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		$ 522,200		$ 522,200		$ 403,400
Restricted Cash		55,100		55,100		48,000
Total Cash, Cash Equivalents and Restricted Cash		577,300	$ 1,426,700	577,300	$ 1,426,700	451,400	$ 438,300
Proceeds from Issuance of Debt	[1]			3,457,200
Securities Received as Collateral		847,000		847,000		263,000
Obligation to Return Securities Received as Collateral		$ 0		$ 0		3,000
Weighted Average Number of Diluted AEP Common Shares Outstanding		515,315,994	502,606,836	512,714,006	500,600,237
Weighted Average Number of Basic AEP Common Shares Outstanding		513,730,196	501,233,680	511,162,723	499,418,278
AEP Texas Inc. [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		$ 100		$ 100		100
Restricted Cash		47,700		47,700		30,400
Total Cash, Cash Equivalents and Restricted Cash		47,800	$ 44,000	47,800	$ 44,000	30,500	28,800
AEP Transmission Co [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		0	0	0	0	0	0
Appalachian Power Co [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		6,700		6,700		2,500
Restricted Cash		7,400		7,400		17,600
Total Cash, Cash Equivalents and Restricted Cash		14,100	15,100	14,100	15,100	20,100	22,700
Indiana Michigan Power Co [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		25,800	3,200	25,800	3,200	1,300	3,300
Ohio Power Co [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		10,200		10,200		3,000
Total Cash, Cash Equivalents and Restricted Cash		10,200	6,800	10,200	6,800	3,000	7,400
Public Service Co Of Oklahoma [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		5,500	3,600	5,500	3,600	1,300	2,600
Southwestern Electric Power Co [Member]
Amounts Attributable to AEP Common Shareholders
Earnings Attributable to Common Shareholders		139,400	108,900	260,200	208,100
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		$ 84,400	$ 45,000	$ 84,400	$ 45,000	$ 51,200	$ 13,200
Restricted Stock Units and Performance Share Units [Member]
Weighted Average Dilutive Effect of:
Weighted Average Dilutive Effect of Shares		1,600,000	1,400,000	1,500,000	1,200,000
Dilutive Securities, Effect on Basic Earnings Per Share		$ 0	$ (0.01)	$ (0.01)	$ (0.01)

[1]Amounts indicated on the statements of cash flows are net of issuance costs and premium or discount and will not tie to the issuance amounts.

Comprehensive Income (Details)

Comprehensive Income (Details) - USD ($) $ in Millions		3 Months Ended						9 Months Ended
Comprehensive Income (Details) - USD ($) $ in Millions		Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Sep. 30, 2022	Sep. 30, 2021
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		$ 551.4		$ 184.8	$ 97		$ (85.1)	$ 184.8	$ (85.1)
Change in Fair Value Recognized in AOCI		101.7			225.7			646	552.1
Commodity
Generation & Marketing Revenues		5,526.1			4,623			14,758.4	12,730.6
Interest Rate
Interest Expense		360.7			303.7			1,001.7	895.5
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(225.5)			(60.7)			(439.1)	(243.4)
Income Tax (Expense) Benefit		(16.1)			69.8			90.7	185.5
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(178.2)			(48)			(346.9)	(192.3)
Net Current Period Other Comprehensive Income (Loss)		(76.5)	$ 120.8	245.8	177.7	$ 127.8	54.3	290.1	359.8
Ending Balance in AOCI		474.9	551.4		274.7	97		474.9	274.7
Cash Flow Hedges [Member] \| Interest Rate [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(10.8)		(21.3)	(32.2)		(47.5)	(21.3)	(47.5)
Change in Fair Value Recognized in AOCI	[1]	7.4			4.9			16.2	17.6
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0.9			1.5			3.1	4.8
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0.8			1.2			2.5	3.8
Net Current Period Other Comprehensive Income (Loss)		8.2			6.1			18.7	21.4
Ending Balance in AOCI		(2.6)	(10.8)		(26.1)	(32.2)		(2.6)	(26.1)
Cash Flow Hedges [Member] \| Commodity [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		533.6		163.7	110.3		(60.6)	163.7	(60.6)
Change in Fair Value Recognized in AOCI		94.3			220.8			629.8	534.5
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(222.4)			(59.7)			(432.1)	(240.5)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(175.8)			(47.2)			(341.4)	(190)
Net Current Period Other Comprehensive Income (Loss)		(81.5)			173.6			288.4	344.5
Ending Balance in AOCI		452.1	533.6		283.9	110.3		452.1	283.9
Pension and OPEB [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		28.6		42.4	18.9		23	42.4	23
Change in Fair Value Recognized in AOCI		0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(4)			(2.5)			(10.1)	(7.7)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(3.2)			(2)			(8)	(6.1)
Net Current Period Other Comprehensive Income (Loss)		(3.2)			(2)			(17)	(6.1)
Ending Balance in AOCI		25.4	28.6		16.9	18.9		25.4	16.9
Accumulated Other Comprehensive Income [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Net Current Period Other Comprehensive Income (Loss)		(76.5)	120.8	245.8	177.7	127.8	54.3
Generation and Marketing [Member]
Commodity
Generation & Marketing Revenues		733.1			617.4			1,997	1,641.6
Reclassifications To Accumulated Other Comprehensive Income [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit								(2.4)
Reclassifications to AOCI, Current Period, before Tax, Attributable to Parent								(11.4)
Reclassifications to AOCI, Current Period, Net of Tax, Attributable to Parent								(9)
Reclassifications To Accumulated Other Comprehensive Income [Member] \| Cash Flow Hedges [Member] \| Interest Rate [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit								0
Reclassifications to AOCI, Current Period, before Tax, Attributable to Parent								0
Reclassifications to AOCI, Current Period, Net of Tax, Attributable to Parent								0
Reclassifications To Accumulated Other Comprehensive Income [Member] \| Cash Flow Hedges [Member] \| Commodity [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit								0
Reclassifications to AOCI, Current Period, before Tax, Attributable to Parent								0
Reclassifications to AOCI, Current Period, Net of Tax, Attributable to Parent								0
Reclassifications To Accumulated Other Comprehensive Income [Member] \| Pension and OPEB [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit								(2.4)
Reclassifications To Accumulated Other Comprehensive Income [Member] \| Pension and OPEB [Member] \| Pension Costs
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassifications to AOCI, Current Period, before Tax, Attributable to Parent								(11.4)
Reclassifications to AOCI, Current Period, Net of Tax, Attributable to Parent								(9)
Reclassifications from Accumulated Other Comprehensive Income [Member]
Interest Rate
Interest Expense	[2]	0.9			1.5			3.1	4.8
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(6.2)			(4.8)			(16.5)	(14.5)
Amortization of Actuarial (Gains) Losses		2.2			2.3			6.4	6.8
Income Tax (Expense) Benefit		(47.3)			(12.7)			(92.2)	(51.1)
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Cash Flow Hedges [Member] \| Interest Rate [Member]
Interest Rate
Interest Expense	[2]	0.9			1.5			3.1	4.8
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		0			0			0	0
Amortization of Actuarial (Gains) Losses		0			0			0	0
Income Tax (Expense) Benefit		0.1			0.3			0.6	1
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Cash Flow Hedges [Member] \| Commodity [Member]
Interest Rate
Interest Expense	[2]	0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		0			0			0	0
Amortization of Actuarial (Gains) Losses		0			0			0	0
Income Tax (Expense) Benefit		(46.6)			(12.5)			(90.7)	(50.5)
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Pension and OPEB [Member]
Interest Rate
Interest Expense	[2]	0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(6.2)			(4.8)			(16.5)	(14.5)
Amortization of Actuarial (Gains) Losses		2.2			2.3			6.4	6.8
Income Tax (Expense) Benefit		(0.8)			(0.5)			(2.1)	(1.6)
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Generation and Marketing [Member]
Commodity
Generation & Marketing Revenues	[2]	0.2						0.2	0.7
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Generation and Marketing [Member] \| Cash Flow Hedges [Member] \| Interest Rate [Member]
Commodity
Generation & Marketing Revenues	[2]	0						0	0
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Generation and Marketing [Member] \| Cash Flow Hedges [Member] \| Commodity [Member]
Commodity
Generation & Marketing Revenues	[2]	0.2						0.2	0.7
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Generation and Marketing [Member] \| Pension and OPEB [Member]
Commodity
Generation & Marketing Revenues	[2]	0						0	0
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Purchased Electricity for Resale [Member]
Commodity
Purchased Electricity for Resale	[2]	(222.6)			(59.7)			(432.3)	(241.2)
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Purchased Electricity for Resale [Member] \| Cash Flow Hedges [Member] \| Interest Rate [Member]
Commodity
Purchased Electricity for Resale	[2]	0			0			0	0
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Purchased Electricity for Resale [Member] \| Cash Flow Hedges [Member] \| Commodity [Member]
Commodity
Purchased Electricity for Resale	[2]	(222.6)			(59.7)			(432.3)	(241.2)
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Purchased Electricity for Resale [Member] \| Pension and OPEB [Member]
Commodity
Purchased Electricity for Resale	[2]	0			0			0	0
Apple Blossom and Black Oak [Member] \| Cash Flow Hedges [Member] \| Interest Rate [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Change in Fair Value Recognized in AOCI		(4)			(1)			(9)	(5)
AEP Texas Inc. [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(6)		(6.5)	(8.3)		(8.9)	(6.5)	(8.9)
Change in Fair Value Recognized in AOCI		0.1			0			0	0
Interest Rate
Interest Expense		55.4			44.2			153.2	132.5
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0.3			0.4			1	1.1
Income Tax (Expense) Benefit		20.9			14.6			56.2	31.6
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0.2			0.3			0.8	0.9
Net Current Period Other Comprehensive Income (Loss)		0.3	0.2	0.3	0.3	0.3	0.3	0.8	0.9
Ending Balance in AOCI		(5.7)	(6)		(8)	(8.3)		(5.7)	(8)
AEP Texas Inc. [Member] \| Cash Flow Hedges [Member] \| Interest Rate [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(0.8)		(1.3)	(1.8)		(2.3)	(1.3)	(2.3)
Change in Fair Value Recognized in AOCI		0.1			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0.3			0.4			1	1
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0.2			0.3			0.8	0.8
Net Current Period Other Comprehensive Income (Loss)		0.3			0.3			0.8	0.8
Ending Balance in AOCI		(0.5)	(0.8)		(1.5)	(1.8)		(0.5)	(1.5)
AEP Texas Inc. [Member] \| Pension and OPEB [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(5.2)		(5.2)	(6.5)		(6.6)	(5.2)	(6.6)
Change in Fair Value Recognized in AOCI		0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0			0			0	0.1
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0			0			0	0.1
Net Current Period Other Comprehensive Income (Loss)		0			0			0	0.1
Ending Balance in AOCI		(5.2)	(5.2)		(6.5)	(6.5)		(5.2)	(6.5)
AEP Texas Inc. [Member] \| Accumulated Other Comprehensive Income [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Net Current Period Other Comprehensive Income (Loss)		0.3	0.2	0.3	0.3	0.3	0.3
AEP Texas Inc. [Member] \| Reclassifications from Accumulated Other Comprehensive Income [Member]
Interest Rate
Interest Expense	[2]	0.3			0.4			1	1
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(0.1)			(0.1)			(0.1)	(0.1)
Amortization of Actuarial (Gains) Losses		0.1			0.1			0.1	0.2
Income Tax (Expense) Benefit		0.1			0.1			0.2	0.2
AEP Texas Inc. [Member] \| Reclassifications from Accumulated Other Comprehensive Income [Member] \| Cash Flow Hedges [Member] \| Interest Rate [Member]
Interest Rate
Interest Expense	[2]	0.3			0.4			1	1
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		0			0			0	0
Amortization of Actuarial (Gains) Losses		0			0			0	0
Income Tax (Expense) Benefit		0.1			0.1			0.2	0.2
AEP Texas Inc. [Member] \| Reclassifications from Accumulated Other Comprehensive Income [Member] \| Pension and OPEB [Member]
Interest Rate
Interest Expense	[2]	0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(0.1)			(0.1)			(0.1)	(0.1)
Amortization of Actuarial (Gains) Losses		0.1			0.1			0.1	0.2
Income Tax (Expense) Benefit		0			0			0	0
Appalachian Power Co [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		21.9		24.4	13.9		7.2	24.4	7.2
Change in Fair Value Recognized in AOCI		0			0.2			0	9.3
Interest Rate
Interest Expense		61.7			52.8			171.1	160.6
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(1.7)			(1.8)			(4.9)	(4.9)
Income Tax (Expense) Benefit		5			3.6			24.5	19.3
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(1.3)			(1.5)			(3.8)	(3.9)
Net Current Period Other Comprehensive Income (Loss)		(1.3)	(1.2)	(1.3)	(1.3)	(1.2)	7.9	(3.8)	5.4
Ending Balance in AOCI		20.6	21.9		12.6	13.9		20.6	12.6
Appalachian Power Co [Member] \| Cash Flow Hedges [Member] \| Interest Rate [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		7.1		7.5	8		(0.8)	7.5	(0.8)
Change in Fair Value Recognized in AOCI		0			0.2			0	9.3
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(0.3)			(0.6)			(0.8)	(1)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(0.2)			(0.5)			(0.6)	(0.8)
Net Current Period Other Comprehensive Income (Loss)		(0.2)			(0.3)			(0.6)	8.5
Ending Balance in AOCI		6.9	7.1		7.7	8		6.9	7.7
Appalachian Power Co [Member] \| Pension and OPEB [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		14.8		16.9	5.9		8	16.9	8
Change in Fair Value Recognized in AOCI		0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(1.4)			(1.2)			(4.1)	(3.9)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(1.1)			(1)			(3.2)	(3.1)
Net Current Period Other Comprehensive Income (Loss)		(1.1)			(1)			(3.2)	(3.1)
Ending Balance in AOCI		13.7	14.8		4.9	5.9		13.7	4.9
Appalachian Power Co [Member] \| Accumulated Other Comprehensive Income [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Net Current Period Other Comprehensive Income (Loss)		(1.3)	(1.2)	(1.3)	(1.3)	(1.2)	7.9
Appalachian Power Co [Member] \| Reclassifications from Accumulated Other Comprehensive Income [Member]
Interest Rate
Interest Expense	[2]	(0.3)			(0.6)			(0.8)	(1)
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(1.4)			(1.2)			(4.1)	(3.9)
Income Tax (Expense) Benefit		(0.4)			(0.3)			(1.1)	(1)
Appalachian Power Co [Member] \| Reclassifications from Accumulated Other Comprehensive Income [Member] \| Cash Flow Hedges [Member] \| Interest Rate [Member]
Interest Rate
Interest Expense	[2]	(0.3)			(0.6)			(0.8)	(1)
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		0			0			0	0
Income Tax (Expense) Benefit		(0.1)			(0.1)			(0.2)	(0.2)
Appalachian Power Co [Member] \| Reclassifications from Accumulated Other Comprehensive Income [Member] \| Pension and OPEB [Member]
Interest Rate
Interest Expense	[2]	0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(1.4)			(1.2)			(4.1)	(3.9)
Income Tax (Expense) Benefit		(0.3)			(0.2)			(0.9)	(0.8)
Indiana Michigan Power Co [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(0.7)		(1.3)	(6.2)		(7)	(1.3)	(7)
Change in Fair Value Recognized in AOCI		0			0			0	0
Interest Rate
Interest Expense		31.2			30.2			92.5	86.6
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0.3			0.5			1.1	1.5
Income Tax (Expense) Benefit		8			(1.8)			7.7	(8.3)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0.3			0.4			0.9	1.2
Net Current Period Other Comprehensive Income (Loss)		0.3	0.3	0.3	0.4	0.3	0.5	0.9	1.2
Ending Balance in AOCI		(0.4)	(0.7)		(5.8)	(6.2)		(0.4)	(5.8)
Indiana Michigan Power Co [Member] \| Cash Flow Hedges [Member] \| Interest Rate [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(5.9)		(6.7)	(7.4)		(8.3)	(6.7)	(8.3)
Change in Fair Value Recognized in AOCI		0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0.5			0.5			1.5	1.6
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0.4			0.4			1.2	1.3
Net Current Period Other Comprehensive Income (Loss)		0.4			0.4			1.2	1.3
Ending Balance in AOCI		(5.5)	(5.9)		(7)	(7.4)		(5.5)	(7)
Indiana Michigan Power Co [Member] \| Pension and OPEB [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		5.2		5.4	1.2		1.3	5.4	1.3
Change in Fair Value Recognized in AOCI		0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(0.2)			0			(0.4)	(0.1)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(0.1)			0			(0.3)	(0.1)
Net Current Period Other Comprehensive Income (Loss)		(0.1)			0			(0.3)	(0.1)
Ending Balance in AOCI		5.1	5.2		1.2	1.2		5.1	1.2
Indiana Michigan Power Co [Member] \| Accumulated Other Comprehensive Income [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Net Current Period Other Comprehensive Income (Loss)		0.3	0.3	0.3	0.4	0.3	0.5
Indiana Michigan Power Co [Member] \| Reclassifications from Accumulated Other Comprehensive Income [Member]
Interest Rate
Interest Expense	[2]	0.5			0.5			1.5	1.6
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(0.3)			(0.2)			(0.7)	(0.6)
Amortization of Actuarial (Gains) Losses		0.1			0.2			0.3	0.5
Income Tax (Expense) Benefit		0			0.1			0.2	0.3
Indiana Michigan Power Co [Member] \| Reclassifications from Accumulated Other Comprehensive Income [Member] \| Cash Flow Hedges [Member] \| Interest Rate [Member]
Interest Rate
Interest Expense	[2]	0.5			0.5			1.5	1.6
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		0			0			0	0
Amortization of Actuarial (Gains) Losses		0			0			0	0
Income Tax (Expense) Benefit		0.1			0.1			0.3	0.3
Indiana Michigan Power Co [Member] \| Reclassifications from Accumulated Other Comprehensive Income [Member] \| Pension and OPEB [Member]
Interest Rate
Interest Expense	[2]	0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(0.3)			(0.2)			(0.7)	(0.6)
Amortization of Actuarial (Gains) Losses		0.1			0.2			0.3	0.5
Income Tax (Expense) Benefit		(0.1)			0			(0.1)	0
Public Service Co Of Oklahoma [Member]
Interest Rate
Interest Expense		22.4			16.2			62.6	44.7
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit		(31.3)			(2.1)			(41.2)	(3.7)
Net Current Period Other Comprehensive Income (Loss)							(0.1)
Public Service Co Of Oklahoma [Member] \| Cash Flow Hedges [Member] \| Interest Rate [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		0		0	0		0.1	0	0.1
Change in Fair Value Recognized in AOCI		0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0			0			0	(0.1)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0			0			0	(0.1)
Net Current Period Other Comprehensive Income (Loss)		0			0			0	(0.1)
Ending Balance in AOCI		0	0		0	0		0	0
Public Service Co Of Oklahoma [Member] \| Accumulated Other Comprehensive Income [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Net Current Period Other Comprehensive Income (Loss)							(0.1)
Public Service Co Of Oklahoma [Member] \| Reclassifications from Accumulated Other Comprehensive Income [Member] \| Cash Flow Hedges [Member] \| Interest Rate [Member]
Interest Rate
Interest Expense	[2]	0			0			0	(0.1)
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit		0			0			0	0
Southwestern Electric Power Co [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		5.9		6.7	1.9		1.9	6.7	1.9
Change in Fair Value Recognized in AOCI		0			0			0	0
Interest Rate
Interest Expense		35.2			31.7			102	92.4
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(0.5)			(0.1)			(1.5)	(0.1)
Income Tax (Expense) Benefit		(17.8)			6.3			(21)	19
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(0.4)			(0.1)			(1.2)	(0.1)
Regulatory Assets, Noncurrent								(3.1)	91.5
Net Current Period Other Comprehensive Income (Loss)		(0.4)	(0.5)	(0.3)	(0.1)			(1.2)	(0.1)
Ending Balance in AOCI		5.5	5.9		1.8	1.9		5.5	1.8
Southwestern Electric Power Co [Member] \| Cash Flow Hedges [Member] \| Interest Rate [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		1.2		1.2	0.5		(0.3)	1.2	(0.3)
Change in Fair Value Recognized in AOCI		0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0			0.4			0	1.4
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0			0.3			0	1.1
Net Current Period Other Comprehensive Income (Loss)		0			0.3			0	1.1
Ending Balance in AOCI		1.2	1.2		0.8	0.5		1.2	0.8
Southwestern Electric Power Co [Member] \| Pension and OPEB [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		4.7		5.5	1.4		$ 2.2	5.5	2.2
Change in Fair Value Recognized in AOCI		0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(0.5)			(0.5)			(1.5)	(1.5)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(0.4)			(0.4)			(1.2)	(1.2)
Net Current Period Other Comprehensive Income (Loss)		(0.4)			(0.4)			(1.2)	(1.2)
Ending Balance in AOCI		4.3	4.7		1	$ 1.4		4.3	1
Southwestern Electric Power Co [Member] \| Accumulated Other Comprehensive Income [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Net Current Period Other Comprehensive Income (Loss)		(0.4)	$ (0.5)	$ (0.3)	(0.1)
Southwestern Electric Power Co [Member] \| Reclassifications from Accumulated Other Comprehensive Income [Member]
Interest Rate
Interest Expense	[2]				0.4				1.4
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(0.5)			(0.5)			(1.5)	(1.5)
Income Tax (Expense) Benefit		(0.1)			0			(0.3)	0
Southwestern Electric Power Co [Member] \| Reclassifications from Accumulated Other Comprehensive Income [Member] \| Cash Flow Hedges [Member] \| Interest Rate [Member]
Interest Rate
Interest Expense	[2]				0.4				1.4
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		0			0			0	0
Income Tax (Expense) Benefit		0			0.1			0	0.3
Southwestern Electric Power Co [Member] \| Reclassifications from Accumulated Other Comprehensive Income [Member] \| Pension and OPEB [Member]
Interest Rate
Interest Expense	[2]				0				0
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(0.5)			(0.5)			(1.5)	(1.5)
Income Tax (Expense) Benefit		$ (0.1)			$ (0.1)			$ (0.3)	$ (0.3)

[1]The change in fair value includes $(4) million and $(1) million, respectively, for the three months ended September 30, 2022 and 2021 and $(9) million and $(5) million, respectively, for the nine months ended September 30, 2022 and 2021 related to AEP's investment in joint venture wind farms acquired as part of the purchase of Sempra Renewables LLC.[2]Amounts reclassified to the referenced line item on the statements of income.

Rate Matters Regulated Operatio

Rate Matters Regulated Operations (Details) - USD ($) $ in Millions		9 Months Ended
		Sep. 30, 2022	Sep. 30, 2021	Dec. 31, 2021
Public Utilities, General Disclosures [Line Items]
Net Investment		$ 69,813.1		$ 66,001.3
Regulatory Assets, Noncurrent		3,877.5		4,142.3
Other Asset Impairment Charges		24.9	$ 0
Regulatory Assets, Current		1,137.1		647.8
AEP Texas Inc. [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		11,311.7		10,635.4
Regulatory Assets, Noncurrent		243.9		275.2
AEP Transmission Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		12,742.6		11,935.7
Regulatory Assets, Noncurrent		2.6		8.5
Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		12,163.6		11,804.3
Regulatory Assets, Noncurrent		970.3		757.6
Other Asset Impairment Charges		24.9	$ 0
Regulatory Assets, Current		404		201.3
Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		7,389.4		7,310.9
Regulatory Assets, Noncurrent		422.5		410.9
Regulatory Assets, Current		25.4		6.4
Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		8,396		7,963
Regulatory Assets, Noncurrent		270.8		293
Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		5,534.2		4,802.8
Regulatory Assets, Noncurrent		606.2		1,037.4
Regulatory Assets, Current		178.7		194.6
Public Service Co Of Oklahoma [Member] \| Northeastern Plant, Unit 3 \| Generating Units Probable of Abandonment [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		143.7
Accelerated Depreciation Regulatory Asset		141.4
Cost of Removal Regulatory Liability	[1]	$ 20.2
Expected Retirement Date	[2]	2026
Depreciation	[3]	$ 14.9
Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		8,159.9		7,400.1
Regulatory Assets, Noncurrent		992.4		1,005.3
Net Under-Recovered Fuel Costs		236
Regulatory Assets, Current		333.8		143.9
Southwestern Electric Power Co [Member] \| Dolet Hills Power Station and Related Fuel Operations
Public Utilities, General Disclosures [Line Items]
Share of Net Investment in Dolet Hills Power Station		113
Southwestern Electric Power Co [Member] \| Dolet Hills Power Station and Related Fuel Operations \| Arkansas
Public Utilities, General Disclosures [Line Items]
Recovery of 2021 Dolet Hills Fuel Costs		20
Southwestern Electric Power Co [Member] \| Dolet Hills Power Station and Related Fuel Operations \| Louisiana Jurisdiction [Member]
Public Utilities, General Disclosures [Line Items]
Recovery of 2021 Dolet Hills Fuel Costs		20
Approved Deferral of Dolet Hills Fuel Costs		30
Recommended Disallowance from Staff or Intervenors		72
Southwestern Electric Power Co [Member] \| Pirkey Power Plant and Related Fuel Operations
Public Utilities, General Disclosures [Line Items]
Share of Net Investment in Pirkey Power Plant		216
Pirkey Power Plant and Sabine Unbilled Fixed Costs		49
Southwestern Electric Power Co [Member] \| Pirkey Generating Station (Unit No. 1) \| Generating Units Probable of Abandonment [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		65
Accelerated Depreciation Regulatory Asset		150.7
Cost of Removal Regulatory Liability		$ 39.6
Expected Retirement Date	[4]	2023
Depreciation	[3]	$ 12.5
Southwestern Electric Power Co [Member] \| Welsh Plant Unit 1 and 3 \| Generating Units Probable of Abandonment [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		432.3
Accelerated Depreciation Regulatory Asset		75.7
Cost of Removal Regulatory Liability	[5]	$ 58.2
Expected Retirement Date	[6]	2028
Depreciation	[3]	$ 39.8
Southwestern Electric Power Co [Member] \| Welsh Plant Unit 2
Public Utilities, General Disclosures [Line Items]
Impairment Charge Welsh Plant, Unit 2		7
Southwestern Electric Power Co [Member] \| Dolet Hills Power Station \| Arkansas
Public Utilities, General Disclosures [Line Items]
Other Asset Impairment Charges		2
Southwestern Electric Power Co [Member] \| Dolet Hills Power Station \| Texas
Public Utilities, General Disclosures [Line Items]
Other Asset Impairment Charges		12
Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		941.2		1,048.6
Regulatory Assets Pending Final Regulatory Approval [Member] \| AEP Texas Inc. [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		57.5		41.2
Regulatory Assets Pending Final Regulatory Approval [Member] \| Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		166.7		105.1
Regulatory Assets Pending Final Regulatory Approval [Member] \| Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		1.9		3.7
Regulatory Assets Pending Final Regulatory Approval [Member] \| Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		32.6		3.8
Regulatory Assets Pending Final Regulatory Approval [Member] \| Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		24.4		14.2
Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		656.6		880.6
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Plant Retirement Costs - Unrecovered Plant [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		35.2		35.2
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Dolet Hills Power Station Accelerated Depreciation [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		54.7		72.3
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		21.2		9.2
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| February 2021 Severe Storm Fuel Costs
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	[7]	126.1		430.2
Regulatory Assets, Current		37		63
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Pirkey Power Plant Accelerated Depreciation
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		150.7		87
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Welsh Unit 1 and 3 Accelerated Depreciation
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		75.7		45.9
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Dolet Hills Power Station Fuel Costs - Louisiana
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		31.8		30.9
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| AEP Texas Inc. [Member] \| Mobile Generation Lease Payments
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		9.2		0
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Appalachian Power Co [Member] \| COVID-19 - Virginia
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		7		6.8
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Indiana Michigan Power Co [Member] \| Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		0.1		0.1
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member] \| Dolet Hills Power Station Accelerated Depreciation [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		54.7		72.3
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member] \| Plant Retirement Costs - Unrecovered Plant, Louisiana
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		35.2		35.2
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member] \| Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		4.9		2.4
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member] \| February 2021 Severe Storm Fuel Costs
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	[8]	126.1		430.2
Regulatory Assets, Current		37		63
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member] \| Pirkey Power Plant Accelerated Depreciation
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		150.7		87
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member] \| Welsh Unit 1 and 3 Accelerated Depreciation
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		75.7		45.9
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member] \| Dolet Hills Power Station Fuel Costs - Louisiana
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		31.8		30.9
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member] \| Dolet Hills Power Station
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		55
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| COVID-19
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		8.7		11.2
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Plant Retirement Costs - Asset Retirement Obligation Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		25.9		25.9
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Storm Related Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		306.5		241.8
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		42.4		41.8
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Renewable Energy Portfolio Standards Costs
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		0		2.1
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| 2017-2019 Virginia Triennial Under-Earnings [Domain]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		37		0
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| 2020-2022 Virginia Triennial Under-Earnings [Domain]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		25.3		15.1
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| AEP Texas Inc. [Member] \| COVID-19
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		3.8		2.1
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| AEP Texas Inc. [Member] \| Storm Related Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		27		22.4
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| AEP Texas Inc. [Member] \| Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		8.2		7.4
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| AEP Texas Inc. [Member] \| Texas Retail Electric Provider Bad Debt Expense
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		4.1		4.1
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| AEP Texas Inc. [Member] \| Vegetation Management Programs
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		5.2		5.2
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Appalachian Power Co [Member] \| Plant Retirement Costs - Asset Retirement Obligation Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		25.9		25.9
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Appalachian Power Co [Member] \| Storm Related Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		69.9		53.7
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Appalachian Power Co [Member] \| Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		1.6		1.5
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Appalachian Power Co [Member] \| Renewable Energy Portfolio Standards Costs
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		0		2.1
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Appalachian Power Co [Member] \| 2017-2019 Virginia Triennial Under-Earnings [Domain]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		37		0
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Appalachian Power Co [Member] \| 2020-2022 Virginia Triennial Under-Earnings [Domain]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		25.3		15.1
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Indiana Michigan Power Co [Member] \| COVID-19
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		0.1		1.7
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Indiana Michigan Power Co [Member] \| Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		1.7		1.9
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Ohio Power Co [Member] \| Storm Related Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		32.5		3.8
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Ohio Power Co [Member] \| Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		0.1		0
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Public Service Co Of Oklahoma [Member] \| Storm Related Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		24.3		13.9
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Public Service Co Of Oklahoma [Member] \| Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		0.1		0.3
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member] \| Asset Retirement Obligation - Louisiana [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		11.3		10.3
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member] \| Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		14.9		18.4
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member] \| Storm Related Costs - Louisiana
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		$ 151.3		$ 148

[1]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.[2]Northeastern Plant, Unit 3 is currently being recovered through 2040.[3]Represents the amount of annual depreciation that has been collected from customers over the prior 12-month period.[4]Pirkey Plant is currently being recovered through 2025 in the Louisiana jurisdiction and through 2045 in the Arkansas and Texas jurisdictions[5]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.[6]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.[7]Includes $37 million and $63 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of September 30, 2022 and December 31, 2021, respectively.[8]Includes $37 million and $63 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of September 30, 2022 and December 31, 2021, respectively.

Rate Matters East Companies (De

Rate Matters East Companies (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2022	Dec. 31, 2021
Public Utilities, General Disclosures [Line Items]
Property, Plant and Equipment, Net	$ 69,813.1	$ 66,001.3
AEP Transmission Co [Member]
Public Utilities, General Disclosures [Line Items]
Property, Plant and Equipment, Net	12,742.6	11,935.7
Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Property, Plant and Equipment, Net	12,163.6	11,804.3
Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Property, Plant and Equipment, Net	7,389.4	7,310.9
Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Property, Plant and Equipment, Net	$ 8,396	$ 7,963
Kentucky Power Co [Member] \| Mitchell Power Plant
Public Utilities, General Disclosures [Line Items]
Ownership Interest in Mitchell Power Plant	50%
Wheeling Power Company \| Mitchell Power Plant
Public Utilities, General Disclosures [Line Items]
Ownership Interest in Mitchell Power Plant	50%
2017-2019 Virginia Triennial Review [Member] \| Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Approved Return on Common Equity	9.20%
Total Basis Point Band for Authorized Return on Equity	14,000%
Proposed Previously Incurred Costs Expected to Recover	$ 37
Requested Annual Base Rate Increase	41
Requested Rider to Recover October 2022 thru January 2024	72
Costs Below Authorized ROE Band in Base Rate Increase Request	12
Expensed Remaining Closed Coal Plant	25
CCR/ELG Filings \| Mitchell Power Plant
Public Utilities, General Disclosures [Line Items]
Investment in CCR/ELG	132
Estimated alternative CCR Investment	25
CCR/ELG Filings \| Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
ELG Investment	62
Net Book Value of Amos and Mountaineer Plants - Virginia	1,500
Estimated ELG Costs	162
CCR/ELG Filings \| Kentucky Power Co [Member] \| Mitchell Power Plant
Public Utilities, General Disclosures [Line Items]
Property, Plant and Equipment, Net	576
Indiana Earnings Test Filings \| Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
FAC Credit to Customers	14
2021 and 2021 ENEC Filing \| Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
2021 Requested Increase in ENEC Revenues	73
2021 Cumulative ENEC Under Recovery	55
2021 Projected ENEC Cost Incease	18
2021 Approved ENEC Rate Increase	7
2021 Approved Reduction in ENEC Projected Costs	48
2022 Requested Increase in ENEC Rates	155
Current Cumulative ENEC Under Recovery	430
2022 Requested Increase in ENEC Rates Second Filing	297
2022 Approved Projected ENEC Rate Increase	31
2022 Approved Overall ENEC Rate Increase	93
2022 Recommended ENEC Under-Recovery Disallowance	83
2022 Recommended Increase in ENEC Rates	13
Michigan Power Supply Cost Recovery Reconciliation \| Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
ALJ Recommended Disallowance	8
June 2022 Storm Costs \| Appalachian Power Co [Member] \| West Virginia
Public Utilities, General Disclosures [Line Items]
Storm Expenses to be Requested in Separate Filing	15
June 2022 Storm Costs \| Ohio Power Co [Member] \| Ohio
Public Utilities, General Disclosures [Line Items]
Storm Expenses to be Requested in Separate Filing	19
2022 Michigan Integrated Resource Plan Filing \| Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Rockport U2 Leasehold Improvements Net Book Value	102
2020-2022 Virginia Triennial Review [Member] \| Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Previously Incurred Costs Deferral Below Authorized ROE Band	$ 25
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%

Rate Matters West Companies (De

Rate Matters West Companies (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2022	Dec. 31, 2021
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	$ 3,877.5	$ 4,142.3
AEP Share of Independence Energy Connection Capital Costs	83
Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	941.2	1,048.6
Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	606.2	1,037.4
Public Service Co Of Oklahoma [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	24.4	14.2
Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	992.4	1,005.3
Southwestern Electric Power Co [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	656.6	880.6
AEP Texas Inc. [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	243.9	275.2
AEP Texas Inc. [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	$ 57.5	$ 41.2
ETT Interim Transmission Rates [Member]
Public Utilities, General Disclosures [Line Items]
Parent Ownership Interest In ETT	50%
AEP Share Of ETT Cumulative Revenues Subject To Review	$ 1,500
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%
Proceeds For Securitzation Bonds	$ 687
February 2021 Severe Storm Fuel Costs \| Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	349
February 2021 Severe Storm Fuel Costs \| Southwestern Electric Power Co [Member] \| Arkansas
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	$ 85
Requested Weighted Average Cost of Capital	6.05%
February 2021 Severe Storm Fuel Costs \| Southwestern Electric Power Co [Member] \| Louisiana Jurisdiction [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	$ 126
Interim WACC	3.25%
February 2021 Severe Storm Fuel Costs \| Southwestern Electric Power Co [Member] \| Texas
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	$ 138
Approved Carrying Charge	1.65%
Requested Weighted Average Cost of Capital	7.18%
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
2012 Texas Base Rate Case [Member] \| Southwestern Electric Power Co [Member] \| Minimum [Member]
Public Utilities, General Disclosures [Line Items]
Estimated Turk AFUDC Disallowance	80
Estimated Turk AFUDC Refunds	0
2012 Texas Base Rate Case [Member] \| Southwestern Electric Power Co [Member] \| Maximum [Member]
Public Utilities, General Disclosures [Line Items]
Estimated Turk AFUDC Disallowance	90
Estimated Turk AFUDC Refunds	180
2016 Texas Base Rate Case [Member] \| Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Net Increase in Texas Annual Revenues	$ 69
Requested Return on Equity	10%
Approved Net Increase in Texas Annual Revenues	$ 50
Approved Return on Common Equity	9.60%
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]
Approved Return on Common Equity	9.25%
Impairment Charge Total	$ 12
Requested Annual Increase	$ 105
Requested Return on Equity	10.35%
Requested Net Annual Increase	$ 90
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
2020 Louisiana Base Rate Case \| Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Annual Increase	$ 134
Requested Return on Equity	10.35%
Amount of Increase Related to Annual Depreciation Expense	$ 32
Revised Requested Annual Increase	114
Staff Recommended Annual Rate Increase	$ 6
Staff Recommended Return on Common Equity	9.10%
Requested Annual Increase in Rebuttal	$ 95
2020 Louisiana Base Rate Case \| Southwestern Electric Power Co [Member] \| Minimum [Member]
Public Utilities, General Disclosures [Line Items]
Intervenor Recommended Return on Common Equity	9.35%
2020 Louisiana Base Rate Case \| Southwestern Electric Power Co [Member] \| Maximum [Member]
Public Utilities, General Disclosures [Line Items]
Intervenor Recommended Return on Common Equity	9.80%
2021 Arkansas Rate Case \| Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Approved Return on Common Equity	9.50%
Requested Annual Increase	$ 85
Requested Return on Equity	10.35%
Amount of Increase Related to Annual Depreciation Expense	$ 14
Revised Requested Annual Increase	$ 81
Requested Debt Capital Structure	48.70%
Requested Equity Capital Structure	51.30%
Amount of Increase Related to North Central Wind Facilities	$ 41
Amount of Increase Related to SPP Expenses	$ 6
Public Utilities, Approved Debt Capital Structure, Percentage	55%
Public Utilities, Approved Rate Increase (Decrease), Amount	$ 49
Public Utilities, Approved Equity Capital Structure, Percentage	45%
2021 Louisiana Storm Cost Filing \| Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Deferred Storm Costs	$ 145
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	$ 524

Commitments, Guarantees and C_3

Commitments, Guarantees and Contingencies (Details)	9 Months Ended
Commitments, Guarantees and Contingencies (Details)	Sep. 30, 2022 USD ($)
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	$ 45,900,000
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Rockport Plant, Unit 2 Acquisition Price	116,000,000
AEP Wind Holdings LLC [Member] \| Generation And Marketing [Member]
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Maximum Potential Amount of Future Payments Associated with Guarantee	120,000,000
Guarantor Obligations, Current Carrying Value	5,000,000
Guarantor Obligations, Current Carrying Value, Contingent Portion	395,000
AEP Texas Inc. [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	10,900,000
Appalachian Power Co [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	6,300,000
Indiana Michigan Power Co [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	4,300,000
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Rockport Plant, Unit 2 Acquisition Price	116,000,000
Ohio Power Co [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	7,400,000
Public Service Co Of Oklahoma [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	4,800,000
Southwestern Electric Power Co [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	5,400,000
Rockport Lease [Member]
Present Value of Future Minimum Lease Payments, Sale Leaseback Transactions, Fiscal Year Maturity [Abstract]
Minimum Lease Payments, Sale Leaseback Transactions, Next Twelve Months	174,900,000	[1]
Minimum Lease Payments, Sale Leaseback Transactions	174,900,000	[1]
Rockport Lease [Member] \| Indiana Michigan Power Co [Member]
Present Value of Future Minimum Lease Payments, Sale Leaseback Transactions, Fiscal Year Maturity [Abstract]
Minimum Lease Payments, Sale Leaseback Transactions, Next Twelve Months	87,400,000
Minimum Lease Payments, Sale Leaseback Transactions	87,400,000
Boat and Barge Leases [Member]
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Guarantor Obligations, Current Carrying Value	2,000,000
Maximum Potential Lease Payments, AEPRO Barge and Boat Leases	36,000,000
Guarantee Obligations Current Carrying Value Other Liabilities Current	1,000,000
Guarantee Obligations Current Carrying Value Other Liabilities Noncurrent	1,000,000
Letters of Credit [Member]
Maximum Future Payments for Letters of Credit [Abstract]
Maximum Future Payments for Letters of Credit Issued Under the Uncommitted Facility	309,900,000
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Letters of Credit Limit	1,200,000,000
Uncommitted Facility	400,000,000
Letters of Credit [Member] \| AEP Texas Inc. [Member]
Maximum Future Payments for Letters of Credit [Abstract]
Maximum Future Payments for Letters of Credit Issued Under the Uncommitted Facility	1,800,000
March 2027 \| Letters of Credit [Member]
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Revolving Credit Facilities	4,000,000,000
March 2024 \| Letters of Credit [Member]
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Revolving Credit Facilities	$ 1,000,000,000

[1]AEP’s future minimum lease payments include equal shares from AEGCo and I&M.

Acquisitions and Dispositions (

Acquisitions and Dispositions (Details)		3 Months Ended				9 Months Ended
Acquisitions and Dispositions (Details)		Sep. 30, 2022 USD ($) MW	Jun. 30, 2022 USD ($)	Sep. 30, 2021 USD ($)	Mar. 31, 2021 USD ($)	Sep. 30, 2022 USD ($) MW	Sep. 30, 2021 USD ($)	Dec. 31, 2021 USD ($)
Obligations Under Operating Leases		$ 540,000,000				$ 540,000,000		$ 492,800,000
Asset Retirement Obligation, Liabilities Settled	[1],[2],[3],[4],[5]					29,400,000
Additional Paid in Capital		8,001,000,000				8,001,000,000		7,172,600,000
Property, Plant and Equipment		24,590,700,000				24,590,700,000		23,088,100,000
Noncontrolling Interests		234,100,000				234,100,000		247,000,000
Customers		885,600,000				885,600,000		720,900,000
Materials and Supplies		801,900,000				801,900,000		681,300,000
Property, Plant and Equipment, Net		69,813,100,000				69,813,100,000		66,001,300,000
Regulatory Assets, Noncurrent		3,877,500,000				3,877,500,000		4,142,300,000
Assets Held for Sale		2,830,600,000				2,830,600,000		2,919,700,000
Accounts Payable, Current		2,240,200,000				2,240,200,000		2,054,600,000
Long-term Debt Due Within One Year	[6]	1,403,500,000				1,403,500,000		2,153,800,000
Customer Deposits, Current		375,500,000				375,500,000		321,600,000
Long-term Debt	[7]	33,646,600,000				33,646,600,000		31,300,700,000
Regulatory Liabilities and Deferred Investment Tax Credits		7,934,100,000				7,934,100,000		8,686,300,000
Liabilities Held for Sale		1,992,000,000				1,992,000,000		1,880,900,000
Proceeds from Sale of Property, Plant, and Equipment						215,700,000	$ 17,400,000
Gain (Loss) on Disposition of Assets		$ 0		$ 0		(116,300,000)	0
Proceeds of Mineral Rights Sale
Proceeds from Sale of Property, Plant, and Equipment						120,000,000
Gain (Loss) on Disposition of Other Assets						$ 116,000,000
BP Wind Energy
Wind Generation MWs \| MW						724
Equity Method Investment, Ownership Percentage		50%				50%
Impairment of Equity Method Investment		$ 2,000,000	$ 186,000,000			$ 188,000,000
Dry Lake Solar Project
Payments to Acquire Property, Plant, and Equipment						0	114,400,000
North Central Wind Energy Facilities
Payments to Acquire Property, Plant, and Equipment						$ 1,207,300,000	652,800,000
Mitchell Power Plant
Approximate OVEC Generating Capacity (MWs) \| MW		1,560				1,560
NBV Mitchell Including CWIP and Inventory		$ 576,000,000				$ 576,000,000
Dry Lake Solar Project
Percentage of an Asset Acquired		75%				75%
Noncash or Part Noncash Acquisition, Other Assets Acquired					$ 18,900,000
Dry Lake Solar Project \| Noncontrolling Interest [Member]
Noncash or Part Noncash Acquisition, Other Assets Acquired					$ 18,900,000
North Central Wind Energy Facilities
Payments to Acquire Property, Plant, and Equipment						$ 2,000,000,000
Transmission Operations [Member]
Enterprise Value		$ 2,850,000,000				2,850,000,000
Transmission Operations [Member] \| Proceeds for KY Operations
Enterprise Value		2,646,000,000				2,646,000,000
Transmission Operations [Member] \| Kentucky Transmission Company
Customers		1,700,000				1,700,000		1,500,000
Materials and Supplies		0				0		0
Property, Plant and Equipment, Net		167,000,000				167,000,000		165,300,000
Regulatory Assets, Noncurrent		0				0		0
Disposal Group, Including Discontinued Operation, Other Assets		5,000,000				5,000,000		1,100,000
Disposal Group, Including Discontinued Operation, Assets		173,700,000				173,700,000		167,900,000
Assets Held for Sale		173,700,000				173,700,000		167,900,000
Accounts Payable, Current		700,000				700,000		1,100,000
Long-term Debt Due Within One Year		0				0		0
Customer Deposits, Current		0				0		0
Disposal Group, Including Discontinued Operation, Deferred Tax Liabilities		16,400,000				16,400,000		15,400,000
Long-term Debt		0				0		0
Regulatory Liabilities and Deferred Investment Tax Credits		8,000,000				8,000,000		7,600,000
Disposal Group, Including Discontinued Operation, Other Liabilities, Current		2,500,000				2,500,000		3,500,000
Liabilities Held for Sale		$ 27,600,000				$ 27,600,000		27,600,000
Gain (Loss) on Disposition of Business				0
Generation And Marketing [Member]
Coal Generation MWs \| MW		595				595
Generation And Marketing [Member] \| Dry Lake Solar Project
Payments to Acquire Property, Plant, and Equipment						$ 114,000,000
Generation And Marketing [Member] \| Dry Lake Solar Project \| Payment at Closing
Payments to Acquire Property, Plant, and Equipment						103,000,000
Generation And Marketing [Member] \| Dry Lake Solar Project \| Payment When Put in Service
Payments to Acquire Property, Plant, and Equipment						11,000,000
Generation And Marketing [Member] \| Dry Lake Solar Project
Property, Plant and Equipment		$ 143,000,000				143,000,000
Noncontrolling Interests		34,000,000				$ 34,000,000
Solar Generation MWs \| MW						100
Generation And Marketing [Member] \| Dry Lake Solar Project \| Noncontrolling Interest [Member]
Noncash or Part Noncash Acquisition, Other Assets Acquired						$ 16,000,000
Vertically Integrated Utilities [Member]
Enterprise Value		2,850,000,000				2,850,000,000
Vertically Integrated Utilities [Member] \| Proceeds for KY Operations
Enterprise Value		2,646,000,000				2,646,000,000
Vertically Integrated Utilities [Member] \| Kentucky Power Company and Kentucky Transmission Company
Customers		77,800,000				77,800,000		33,200,000
Materials and Supplies		36,700,000				36,700,000		30,600,000
Property, Plant and Equipment, Net		2,387,400,000				2,387,400,000		2,302,700,000
Regulatory Assets, Noncurrent		508,600,000				508,600,000		484,700,000
Disposal Group, Including Discontinued Operation, Other Assets		38,100,000				38,100,000		68,500,000
Disposal Group, Including Discontinued Operation, Assets		3,048,600,000				3,048,600,000		2,919,700,000
Assets Held for Sale		2,830,600,000				2,830,600,000		2,919,700,000
Accounts Payable, Current		62,400,000				62,400,000		53,400,000
Long-term Debt Due Within One Year		215,000,000				215,000,000		200,000,000
Customer Deposits, Current		38,000,000				38,000,000		32,400,000
Disposal Group, Including Discontinued Operation, Deferred Tax Liabilities		497,800,000				497,800,000		441,600,000
Long-term Debt		963,400,000				963,400,000		903,100,000
Regulatory Liabilities and Deferred Investment Tax Credits		138,100,000				138,100,000		148,100,000
Disposal Group, Including Discontinued Operation, Other Liabilities, Current		77,300,000				77,300,000		102,300,000
Liabilities Held for Sale		1,992,000,000				1,992,000,000		1,880,900,000
Gain (Loss) on Disposition of Business				$ 0
gain (loss) on Disposition of Business net of Tax		(218,000,000)
Deferred Tax Assets, Gross		$ 45,000,000				$ 45,000,000
Vertically Integrated Utilities [Member] \| Sundance [Member]
Wind Generation MWs \| MW						199
Vertically Integrated Utilities [Member] \| Sundance [Member] \| North Central Wind Energy Facilities
Payments to Acquire Property, Plant, and Equipment						$ 270,000,000
Vertically Integrated Utilities [Member] \| Maverick [Member]
Wind Generation MWs \| MW						287
Vertically Integrated Utilities [Member] \| Maverick [Member] \| North Central Wind Energy Facilities
Payments to Acquire Property, Plant, and Equipment						$ 383,000,000
Vertically Integrated Utilities [Member] \| Traverse [Member]
Wind Generation MWs \| MW						998
Vertically Integrated Utilities [Member] \| Traverse [Member] \| North Central Wind Energy Facilities
Payments to Acquire Property, Plant, and Equipment						$ 1,200,000,000
Vertically Integrated Utilities [Member] \| North Central Wind Energy Facilities
Wind Generation MWs \| MW						1,484
Public Service Co Of Oklahoma [Member]
Percentage of an Asset Acquired		45.50%				45.50%
Obligations Under Operating Leases		$ 100,300,000				$ 100,300,000		62,200,000
Asset Retirement Obligation, Liabilities Settled	[3],[4]					600,000
Additional Paid in Capital		1,042,300,000				1,042,300,000		1,039,000,000
Property, Plant and Equipment		2,386,000,000				2,386,000,000		1,802,400,000
Payments to Acquire Property, Plant, and Equipment						(549,300,000)	(297,000,000)
Customers		44,200,000				44,200,000		41,500,000
Materials and Supplies		89,000,000				89,000,000		56,200,000
Property, Plant and Equipment, Net		5,534,200,000				5,534,200,000		4,802,800,000
Regulatory Assets, Noncurrent		606,200,000				606,200,000		1,037,400,000
Accounts Payable, Current		249,000,000				249,000,000		157,400,000
Long-term Debt Due Within One Year		500,000				500,000		125,500,000
Customer Deposits, Current		60,500,000				60,500,000		56,200,000
Long-term Debt		1,913,100,000				1,913,100,000		1,788,000,000
Regulatory Liabilities and Deferred Investment Tax Credits		827,900,000				827,900,000		835,300,000
Public Service Co Of Oklahoma [Member] \| Vertically Integrated Utilities [Member] \| North Central Wind Energy Facilities
Obligations Under Operating Leases		70,300,000				70,300,000		30,600,000
Property, Plant and Equipment		894,000,000				894,000,000
Public Service Co Of Oklahoma [Member] \| Vertically Integrated Utilities [Member] \| North Central Wind Energy Facilities \| Sundance [Member]
Obligations Under Operating Leases		12,600,000				12,600,000		12,600,000
Public Service Co Of Oklahoma [Member] \| Vertically Integrated Utilities [Member] \| North Central Wind Energy Facilities \| Maverick [Member]
Obligations Under Operating Leases		18,000,000				18,000,000		18,000,000
Public Service Co Of Oklahoma [Member] \| Vertically Integrated Utilities [Member] \| North Central Wind Energy Facilities \| Traverse [Member]
Obligations Under Operating Leases		$ 39,700,000				$ 39,700,000		0
Southwestern Electric Power Co [Member]
Percentage of an Asset Acquired		54.50%				54.50%
Obligations Under Operating Leases		$ 122,500,000				$ 122,500,000		77,700,000
Asset Retirement Obligation, Liabilities Settled	[2],[3],[4]					16,900,000
Additional Paid in Capital		1,445,500,000				1,445,500,000		1,092,200,000
Property, Plant and Equipment		5,454,600,000				5,454,600,000		4,734,500,000
Noncontrolling Interests		400,000				400,000		(100,000)
Payments to Acquire Property, Plant, and Equipment						(658,000,000)	$ (355,800,000)
Customers		31,900,000				31,900,000		35,800,000
Materials and Supplies		85,300,000				85,300,000		81,900,000
Property, Plant and Equipment, Net		8,159,900,000				8,159,900,000		7,400,100,000
Regulatory Assets, Noncurrent		992,400,000				992,400,000		1,005,300,000
Accounts Payable, Current		206,200,000				206,200,000		163,600,000
Long-term Debt Due Within One Year		6,200,000				6,200,000		6,200,000
Customer Deposits, Current		65,300,000				65,300,000		62,400,000
Long-term Debt		3,386,200,000				3,386,200,000		3,389,000,000
Regulatory Liabilities and Deferred Investment Tax Credits		818,200,000				818,200,000		806,900,000
Southwestern Electric Power Co [Member] \| Vertically Integrated Utilities [Member] \| North Central Wind Energy Facilities
Obligations Under Operating Leases		84,300,000				84,300,000		36,700,000
Property, Plant and Equipment		1,100,000,000				1,100,000,000
Southwestern Electric Power Co [Member] \| Vertically Integrated Utilities [Member] \| North Central Wind Energy Facilities \| Sundance [Member]
Obligations Under Operating Leases		15,000,000				15,000,000		15,100,000
Southwestern Electric Power Co [Member] \| Vertically Integrated Utilities [Member] \| North Central Wind Energy Facilities \| Maverick [Member]
Obligations Under Operating Leases		21,600,000				21,600,000		21,600,000
Southwestern Electric Power Co [Member] \| Vertically Integrated Utilities [Member] \| North Central Wind Energy Facilities \| Traverse [Member]
Obligations Under Operating Leases		$ 47,700,000				$ 47,700,000		0
Kentucky Power Co [Member] \| Mitchell Power Plant
Ownership Interest in Mitchell Power Plant		50%				50%
Kentucky Power Co [Member] \| Vertically Integrated Utilities [Member]
Gain (Loss) on Disposition of Business		$ 194,000,000	$ 69,000,000			$ 263,000,000
gain (loss) on Disposition of Business net of Tax		$ 149,000,000				$ 218,000,000
Wheeling Power Company \| Mitchell Power Plant
Ownership Interest in Mitchell Power Plant		50%				50%
AEP Transmission Co [Member]
Obligations Under Operating Leases		$ 1,800,000				$ 1,800,000		1,300,000
Customers		73,800,000				73,800,000		22,500,000
Materials and Supplies		11,700,000				11,700,000		9,300,000
Property, Plant and Equipment, Net		12,742,600,000				12,742,600,000		11,935,700,000
Regulatory Assets, Noncurrent		2,600,000				2,600,000		8,500,000
Assets Held for Sale		173,700,000				173,700,000		167,900,000
Accounts Payable, Current		332,100,000				332,100,000		460,100,000
Long-term Debt Due Within One Year		104,000,000				104,000,000		104,000,000
Long-term Debt		4,782,600,000				4,782,600,000		4,239,900,000
Regulatory Liabilities and Deferred Investment Tax Credits		698,200,000				698,200,000		644,100,000
Liabilities Held for Sale		$ 27,600,000				27,600,000		$ 27,600,000
AEP Transmission Co [Member] \| Transmission Operations [Member]
Proceeds from Divestiture of Businesses						$ 1,200,000,000

[1]Includes $18 million and $18 million as of September 30, 2022 and December 31, 2021, respectively, of ARO classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 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 $1.98 billion and $1.93 billion as of September 30, 2022 and December 31, 2021, respectively.[6]Amount excludes $215 million and $200 million as of September 30, 2022 and December 31, 2021, respectively, of Long-term Debt Due Within One Year classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.[7]Amount excludes $963 million and $903 million as of September 30, 2022 and December 31, 2021, respectively, of Long-term Debt classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.

Benefit Plans (Details)

Benefit Plans (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
Benefit Plans (Details) - USD ($) $ in Millions	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Pension Plans [Member]
Components of Net Periodic Benefit Cost
Service Cost	$ 30.7	$ 32.3	$ 92.3	$ 96.9
Interest Cost	37.1	34.3	111.2	102.9
Expected Return on Plan Assets	(63.4)	(57.4)	(190.1)	(172.3)
Amortization of Prior Service Cost (Credit)	0	0	0	0
Amortization of Net Actuarial Loss	15.8	25.3	47.3	76.1
Net Periodic Benefit Cost (Credit)	20.2	34.5	60.7	103.6
Pension Plans [Member] \| AEP Texas Inc. [Member]
Components of Net Periodic Benefit Cost
Service Cost	2.8	3	8.4	8.9
Interest Cost	3.1	2.8	9.1	8.4
Expected Return on Plan Assets	(5.3)	(4.9)	(15.8)	(14.6)
Amortization of Prior Service Cost (Credit)	0	0	0	0
Amortization of Net Actuarial Loss	1.2	2.1	3.8	6.2
Net Periodic Benefit Cost (Credit)	1.8	3	5.5	8.9
Pension Plans [Member] \| Appalachian Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	2.9	3	8.6	8.9
Interest Cost	4.3	4.1	13.1	12.3
Expected Return on Plan Assets	(8.1)	(7.3)	(24.3)	(21.8)
Amortization of Prior Service Cost (Credit)	0	0	0	0
Amortization of Net Actuarial Loss	1.9	3	5.5	9
Net Periodic Benefit Cost (Credit)	1	2.8	2.9	8.4
Pension Plans [Member] \| Indiana Michigan Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	4	4.4	12.1	13.1
Interest Cost	4.3	4	12.7	12.1
Expected Return on Plan Assets	(8.1)	(7.2)	(24.2)	(21.6)
Amortization of Prior Service Cost (Credit)	0	0	0	0
Amortization of Net Actuarial Loss	1.8	2.9	5.3	8.8
Net Periodic Benefit Cost (Credit)	2	4.1	5.9	12.4
Pension Plans [Member] \| Ohio Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	2.8	2.9	8.4	8.6
Interest Cost	3.4	3.1	10	9.3
Expected Return on Plan Assets	(6.2)	(5.7)	(18.6)	(16.8)
Amortization of Prior Service Cost (Credit)	0	0	0	0
Amortization of Net Actuarial Loss	1.3	2.3	4.1	6.8
Net Periodic Benefit Cost (Credit)	1.3	2.6	3.9	7.9
Pension Plans [Member] \| Public Service Co Of Oklahoma [Member]
Components of Net Periodic Benefit Cost
Service Cost	1.8	2	5.5	6
Interest Cost	1.8	1.7	5.3	5
Expected Return on Plan Assets	(3.3)	(3)	(10.1)	(9.2)
Amortization of Prior Service Cost (Credit)	0	0	0	0
Amortization of Net Actuarial Loss	0.7	1.2	2.2	3.7
Net Periodic Benefit Cost (Credit)	1	1.9	2.9	5.5
Pension Plans [Member] \| Southwestern Electric Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	2.7	2.7	8	8.4
Interest Cost	2.2	2.2	6.8	6.4
Expected Return on Plan Assets	(3.6)	(3.3)	(10.9)	(10.1)
Amortization of Prior Service Cost (Credit)	0	0	0	0
Amortization of Net Actuarial Loss	0.9	1.5	2.8	4.6
Net Periodic Benefit Cost (Credit)	2.2	3.1	6.7	9.3
Other Postretirement Benefit Plans [Member]
Components of Net Periodic Benefit Cost
Service Cost	1.8	2.4	5.5	7.2
Interest Cost	7.3	7.7	21.9	22.9
Expected Return on Plan Assets	(27.5)	(22.8)	(82.5)	(68.4)
Amortization of Prior Service Cost (Credit)	(17.9)	(17.8)	(53.6)	(53.2)
Amortization of Net Actuarial Loss	0	0	0	0
Net Periodic Benefit Cost (Credit)	(36.3)	(30.5)	(108.7)	(91.5)
Other Postretirement Benefit Plans [Member] \| AEP Texas Inc. [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.1	0.2	0.3	0.5
Interest Cost	0.6	0.6	1.7	1.8
Expected Return on Plan Assets	(2.3)	(1.9)	(6.8)	(5.6)
Amortization of Prior Service Cost (Credit)	(1.5)	(1.5)	(4.5)	(4.5)
Amortization of Net Actuarial Loss	0	0	0	0
Net Periodic Benefit Cost (Credit)	(3.1)	(2.6)	(9.3)	(7.8)
Other Postretirement Benefit Plans [Member] \| Appalachian Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.2	0.3	0.6	0.8
Interest Cost	1.2	1.3	3.5	3.7
Expected Return on Plan Assets	(4.1)	(3.4)	(12.2)	(10.1)
Amortization of Prior Service Cost (Credit)	(2.6)	(2.6)	(7.8)	(7.8)
Amortization of Net Actuarial Loss	0	0	0	0
Net Periodic Benefit Cost (Credit)	(5.3)	(4.4)	(15.9)	(13.4)
Other Postretirement Benefit Plans [Member] \| Indiana Michigan Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.2	0.4	0.7	1
Interest Cost	0.8	0.8	2.5	2.6
Expected Return on Plan Assets	(3.3)	(2.7)	(10.2)	(8.3)
Amortization of Prior Service Cost (Credit)	(2.4)	(2.5)	(7.3)	(7.3)
Amortization of Net Actuarial Loss	0	0	0	0
Net Periodic Benefit Cost (Credit)	(4.7)	(4)	(14.3)	(12)
Other Postretirement Benefit Plans [Member] \| Ohio Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.2	0.2	0.5	0.6
Interest Cost	0.7	0.7	2.2	2.3
Expected Return on Plan Assets	(3)	(2.4)	(8.9)	(7.3)
Amortization of Prior Service Cost (Credit)	(1.8)	(1.7)	(5.4)	(5.3)
Amortization of Net Actuarial Loss	0	0	0	0
Net Periodic Benefit Cost (Credit)	(3.9)	(3.2)	(11.6)	(9.7)
Other Postretirement Benefit Plans [Member] \| Public Service Co Of Oklahoma [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.2	0.1	0.4	0.4
Interest Cost	0.4	0.4	1.1	1.2
Expected Return on Plan Assets	(1.6)	(1.3)	(4.6)	(3.8)
Amortization of Prior Service Cost (Credit)	(1.1)	(1.1)	(3.3)	(3.3)
Amortization of Net Actuarial Loss	0	0	0	0
Net Periodic Benefit Cost (Credit)	(2.1)	(1.9)	(6.4)	(5.5)
Other Postretirement Benefit Plans [Member] \| Southwestern Electric Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.1	0.3	0.4	0.6
Interest Cost	0.5	0.4	1.4	1.4
Expected Return on Plan Assets	(1.8)	(1.5)	(5.5)	(4.5)
Amortization of Prior Service Cost (Credit)	(1.4)	(1.4)	(4)	(4)
Amortization of Net Actuarial Loss	0	0	0	0
Net Periodic Benefit Cost (Credit)	$ (2.6)	$ (2.2)	$ (7.7)	$ (6.5)

Business Segments (Details)

Business Segments (Details) - USD ($) $ in Millions		3 Months Ended								9 Months Ended
Business Segments (Details) - USD ($) $ in Millions		Sep. 30, 2022		Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2021		Jun. 30, 2021	Mar. 31, 2021	Sep. 30, 2022		Sep. 30, 2021		Dec. 31, 2021
Reportable Segment Information
Revenue from Contracts with Customers		$ 5,526.1				$ 4,623				$ 14,758.4		$ 12,730.6
Revenue from Related Parties		0				0				0		0
Revenues		5,526.1				4,623				14,758.4		12,730.6
Net Income (Loss)		683.3		$ 520.8	$ 718.1	796.9		$ 573.8	$ 578.8	1,922.2		1,949.5
Balance Sheet Information
Total Property, Plant and Equipment		92,105.1								92,105.1				$ 86,806.4
Accumulated Depreciation and Amortization		22,292								22,292				20,805.1
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		69,813.1								69,813.1				66,001.3
Total Assets	[1]	91,249.4								91,249.4				87,668.7
Long-term Debt Due Within One Year	[2]	1,403.5								1,403.5				2,153.8
Long-term Debt	[3]	33,646.6								33,646.6				31,300.7
Total Long-term Debt Outstanding	[4]	35,050.1								35,050.1				33,454.5
Interest Expense		360.7				303.7				1,001.7		895.5
Income Tax (Expense) Benefit		(16.1)				69.8				90.7		185.5
Reclassification out of Accumulated Other Comprehensive Income [Member]
Balance Sheet Information
Interest Expense	[5]	0.9				1.5				3.1		4.8
Income Tax (Expense) Benefit		(47.3)				(12.7)				(92.2)		(51.1)
Interest Rate [Member] \| Reclassification out of Accumulated Other Comprehensive Income [Member] \| Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Balance Sheet Information
Interest Expense	[5]	0.9				1.5				3.1		4.8
Income Tax (Expense) Benefit		0.1				0.3				0.6		1
Vertically Integrated Utilities [Member]
Reportable Segment Information
Revenue from Contracts with Customers		3,174.6				2,716.8				8,416.4		7,445.9
Transmission and Distribution Utilities Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		1,525.5				1,195				4,064.5		3,366.9
Generation and Marketing Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		733.1				617.4				1,997		1,641.6
Generation and Marketing Revenues [Member] \| Reclassification out of Accumulated Other Comprehensive Income [Member]
Reportable Segment Information
Revenue from Contracts with Customers	[5]	0.2								0.2		0.7
Generation and Marketing Revenues [Member] \| Interest Rate [Member] \| Reclassification out of Accumulated Other Comprehensive Income [Member] \| Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Reportable Segment Information
Revenue from Contracts with Customers	[5]	0								0		0
Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		92.9				93.8				280.5		276.2
Revenues		128.3	[6]			154.8	[7],[8]			429.4	[9],[10]	188.7	[11],[12]
AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Contracts with Customers												0.3
Revenues from Related Parties, Net of Provisions for Refund		331.3				297.6				933.8		864.6
Revenue from Related Parties		340.6				297.7				999.5		882.3
Revenues		418.5				377				1,183.3		1,104.2
Net Income (Loss)		152.7		$ 118.5	$ 155.4	145.4		$ 148.6	$ 151.7	426.6		445.7
Balance Sheet Information
Total Property, Plant and Equipment		13,695								13,695				12,708.5
Accumulated Depreciation and Amortization		952.4								952.4				772.8
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		12,742.6								12,742.6				11,935.7
Total Assets	[13]	13,319.2								13,319.2				12,524.4
Long-term Debt Due Within One Year		104								104				104
Long-term Debt		4,782.6								4,782.6				4,239.9
Total Long-term Debt Outstanding		4,886.6								4,886.6				4,343.9
Interest Income		0.7				0.2				1		0.4
Interest Expense		42.7				36.1				119.7		104.5
Income Tax (Expense) Benefit		44.3				36.7				124.1		115.4
AEP Transmission Co [Member] \| Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0				0.2				0		0.3
Revenues		0	[14]			0	[15]			0	[16]	0	[17]
AEP Transmission Co [Member] \| Transmission [Member]
Reportable Segment Information
Revenue from Contracts with Customers		89.1				79.2				261.7		241.6
Balance Sheet Information
Revenue from Contract with Customers, Net of Provisions for Refund, Including Assessed Tax		87.2				79.2				249.5		239.3
Reconciling Adjustments [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0				0				0		0
Revenue from Related Parties		(425)				(376)				(1,190.5)		(1,112.2)
Revenues		(425)				(376)				(1,190.5)		(1,112.2)
Net Income (Loss)		0				0				0		0
Balance Sheet Information
Total Assets	[1],[18]	(6,310.7)								(6,310.7)				(4,409.1)
Reconciling Adjustments [Member] \| Other Revenues [Member]
Reportable Segment Information
Revenues		(2)	[6]			(3)	[7],[8]			(6.9)	[9],[10]	(8.6)	[11],[12]
Reconciling Adjustments [Member] \| AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0				0				0		0
Revenue from Related Parties		0				0				0		0
Revenues		0				0				0		0
Net Income (Loss)		0				0				0		0
Balance Sheet Information
Total Assets	[13],[19]	(5,013.1)								(5,013.1)				(4,429.4)
Vertically Integrated Utilities [Member]
Reportable Segment Information
Revenue from Related Parties		51.7				42.5				145.8		111.3
Revenues		3,226.3				2,759.3				8,562.2		7,557.2
Net Income (Loss)		476.9				438.7				1,079.4		938.9
Balance Sheet Information
Total Assets	[1]	49,056.9								49,056.9				46,974.2
Vertically Integrated Utilities [Member] \| Vertically Integrated Utilities [Member]
Reportable Segment Information
Revenue from Contracts with Customers		3,174.6				2,716.8				8,416.4		7,445.9
Vertically Integrated Utilities [Member] \| Other Revenues [Member]
Reportable Segment Information
Revenues		0.2	[6]			(0.9)	[7],[8]			0.3	[9],[10]	(0.6)	[11],[12]
Transmission And Distribution Utilities [Member]
Reportable Segment Information
Revenue from Related Parties		4.7				5.3				14.1		24.9
Revenues		1,530.2				1,200.3				4,078.6		3,391.8
Net Income (Loss)		165.5				155.9				483.1		424
Balance Sheet Information
Total Assets	[1]	22,139.7								22,139.7				21,120.2
Transmission And Distribution Utilities [Member] \| Transmission and Distribution Utilities Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		1,525.5				1,195				4,064.5		3,366.9
Transmission And Distribution Utilities [Member] \| Other Revenues [Member]
Reportable Segment Information
Revenues		5.5	[6]			4.9	[7],[8]			18.6	[9],[10]	14.2	[11],[12]
AEP Transmission Holdco [Member]
Reportable Segment Information
Revenue from Related Parties		349				301.3				976.7		882.2
Revenues		430.9				391.6				1,221.1		1,146.8
Net Income (Loss)		171.4				167.9				487.8		510.7
Balance Sheet Information
Total Assets	[1]	14,708.9								14,708.9				13,873.3
AEP Transmission Holdco [Member] \| Transmission [Member]
Reportable Segment Information
Revenue from Contracts with Customers		81.9				90.3				244.4		264.6
Generation And Marketing [Member]
Reportable Segment Information
Revenue from Related Parties		2.3				3.7				17.3		50.3
Revenues		735.4				621.1				2,014.3		1,691.9
Net Income (Loss)		96.2				99.5				278.1		184.2
Balance Sheet Information
Total Assets	[1]	5,376.3								5,376.3				4,263.6
Generation And Marketing [Member] \| Generation and Marketing Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		733.1				617.4				1,997		1,641.6
Generation And Marketing [Member] \| Other Revenues [Member]
Reportable Segment Information
Revenues		122.8	[6],[20]			150.7	[7],[8]			410.5	[9],[10]	175.3	[11],[12]
All Other [Member]
Reportable Segment Information
Revenue from Related Parties	[21]	17.3				23.2				36.6		43.5
Revenues	[21]	28.3				26.7				72.7		55.1
Net Income (Loss)	[21]	(226.7)				(65.1)				(406.2)		(108.3)
Balance Sheet Information
Total Assets	[1],[21],[22]	6,278.3								6,278.3				5,846.5
All Other [Member] \| Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers	[21]	11				3.5				36.1		11.6
Revenues		1.8	[6]			3.1	[7],[8]			6.9	[9],[10]	8.4	[11],[12]
State Transcos [Member] \| AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Contracts with Customers												0.3
Revenue from Related Parties		331.3				297.6				933.8		864.6
Revenues		418.5				377				1,183.3		1,104.2
Net Income (Loss)		152.6				145.3				426.4		445.5
Balance Sheet Information
Total Assets	[13]	13,359.9								13,359.9				12,564.3
State Transcos [Member] \| AEP Transmission Co [Member] \| Transmission [Member]
Reportable Segment Information
Revenue from Contracts with Customers		87.2				79.2				249.5		239.3
AEPTCo Parent [Member] \| AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0				0				0		0
Revenue from Related Parties		0				0				0		0
Revenues		0				0				0		0
Net Income (Loss)	[23]	0.1				$ 0.1				0.2		$ 0.2
Balance Sheet Information
Total Assets	[13],[24]	$ 4,972.4								$ 4,972.4				$ 4,389.5

[1]Amount includes Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.[2]Amount excludes $215 million and $200 million as of September 30, 2022 and December 31, 2021, respectively, of Long-term Debt Due Within One Year classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.[3]Amount excludes $963 million and $903 million as of September 30, 2022 and December 31, 2021, respectively, of Long-term Debt classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.[4]The book value amounts exclude Long-term Debt of $1.2 billion and $1.1 billion as of September 30, 2022 and December 31, 2021, respectively, classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.[5]Amounts reclassified to the referenced line item on the statements of income.[6]Amounts include affiliated and nonaffiliated revenues.[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]Amount includes Assets Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.[14]Amounts include affiliated and nonaffiliated revenues.[15]Amounts include affiliated and nonaffiliated revenues.[16]Amounts include affiliated and nonaffiliated revenues.[17]Amounts include affiliated and nonaffiliated revenues.[18]Reconciling Adjustments for Total Assets primarily include elimination of intercompany advances to affiliates and intercompany accounts receivable.[19]Primarily relates to the elimination of Notes Receivable from the State Transcos.[20]Generation & Marketing includes economic hedge activity.[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]Includes the elimination of AEPTCo Parent’s equity earnings in the State Transcos.[24]Includes the elimination of AEPTCo Parent’s investments in State Transcos.

Derivatives and Hedging (Detail

Derivatives and Hedging (Details) gal in Millions, MWh in Millions, MMBTU in Millions		3 Months Ended			9 Months Ended			12 Months Ended
		Sep. 30, 2022 USD ($) MMBTU MWh gal		Sep. 30, 2021 USD ($)	Sep. 30, 2022 USD ($) MMBTU MWh gal		Sep. 30, 2021 USD ($)	Dec. 31, 2021 USD ($) MMBTU MWh gal
Cash Collateral Netting
Cash Collateral Received Netted Against Risk Management Assets		$ 847,000,000			$ 847,000,000			$ 263,000,000
Cash Collateral Paid Netted Against Risk Management Liabilities		0			0			3,000,000
Fair Value of Derivative Instruments
Current Risk Management Assets		570,200,000			570,200,000			194,400,000
Long-term Risk Management Assets		265,800,000			265,800,000			267,000,000
Total Assets		836,000,000			836,000,000			461,400,000
Current Risk Management Liabilities		187,300,000			187,300,000			75,400,000
Long-term Risk Management Liabilities		388,200,000			388,200,000			230,300,000
Total Liabilities		575,500,000			575,500,000			305,700,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		230,600,000	[1]	$ 169,400,000	703,800,000	[1]	$ 265,500,000
Carrying Amount of Hedged Asset (Liability)	[2],[3]	(849,100,000)			(849,100,000)			(952,300,000)
Cumulative Fair Value Hedging Adjustment in the Carrying Amount of the Hedged Asset (Liability)	[2],[3]	95,700,000			95,700,000			(8,500,000)
Gain (Loss) on Hedging Instruments
Gain (Loss) on Fair Value Hedging Instruments	[4]	(36,000,000)		(100,000)	(98,400,000)		(23,800,000)
Gain (Loss) on Fair Value Portion of Long Term Debt	[4]	36,000,000		100,000	98,400,000		23,800,000
Collateral Triggering Events [Abstract]
Fair Value Of Derivative Liabilities Subject To Cross Acceleration Provisions		135,000,000			135,000,000			40,000,000
Fair Value Of Derivative Liabilities Subject To Cross Default Provisions		260,000,000			260,000,000			76,000,000
Derivatives and Hedging (Textuals) [Abstract]
Hedged Liability, Discontinued Fair Value Hedge, Cumulative Increase (Decrease)		(40,000,000)			(40,000,000)			(46,000,000)
Credit Downgrade Trigger Exposure		10,000,000			10,000,000			9,000,000
Assets Held for Sale		2,830,600,000			2,830,600,000			2,919,700,000
Liabilities Held for Sale		1,992,000,000			1,992,000,000			1,880,900,000
AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		200,000			200,000			0
Long-term Risk Management Assets		100,000			100,000			0
Long-term Risk Management Liabilities		100,000			100,000			0
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(600,000)	[1]	400,000	2,000,000	[1]	1,700,000
Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		106,800,000			106,800,000			42,000,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		61,200,000	[1]	10,800,000	84,300,000	[1]	27,000,000
AEP Transmission Co [Member]
Derivatives and Hedging (Textuals) [Abstract]
Assets Held for Sale		173,700,000			173,700,000			167,900,000
Liabilities Held for Sale		27,600,000			27,600,000			27,600,000
Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		6,200,000	[1]	(15,000,000)	8,600,000	[1]	(20,500,000)
Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Liabilities		0			0			6,700,000
Long-term Risk Management Liabilities		45,100,000			45,100,000			85,800,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		5,600,000	[1]	16,000,000	53,000,000	[1]	26,900,000
Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		44,500,000			44,500,000			12,100,000
Current Risk Management Liabilities		0			0			3,700,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		20,100,000	[1]	14,200,000	76,200,000	[1]	40,600,000
Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		36,400,000			36,400,000			9,800,000
Current Risk Management Liabilities		0			0			2,100,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		7,600,000	[1]	13,100,000	64,100,000	[1]	40,500,000
Risk Management Contracts [Member]
Fair Value of Derivative Instruments
Total Assets	[5],[6]	238,700,000	[7]		238,700,000	[7]		239,800,000	[8]
Total Liabilities	[6],[9]	424,400,000	[7]		424,400,000	[7]		254,700,000	[8]
Derivatives and Hedging (Textuals) [Abstract]
Assets Held for Sale		14,400,000			14,400,000			6,000,000
Liabilities Held for Sale								100,000
Risk Management Contracts [Member] \| AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Total Assets	[6]	300,000			300,000			0
Total Liabilities	[6]	100,000			100,000
Risk Management Contracts [Member] \| Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[6],[10]	106,800,000			106,800,000			42,000,000
Total Liabilities	[6],[10]	0			0			800,000
Risk Management Contracts [Member] \| Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[6],[10]	11,600,000			11,600,000			3,300,000
Total Liabilities	[6],[10]	0			0			5,000,000
Risk Management Contracts [Member] \| Ohio Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[6],[10]	2,100,000			2,100,000			0
Total Liabilities	[10]	45,100,000			45,100,000			92,500,000
Risk Management Contracts [Member] \| Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Total Assets	[6],[10]	44,500,000			44,500,000			12,100,000
Total Liabilities	[6],[10]	0			0			3,700,000
Risk Management Contracts [Member] \| Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[6],[10]	36,400,000			36,400,000			10,900,000
Total Liabilities	[6],[10]	0			0			2,100,000
Commodity [Member]
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		452,100,000			452,100,000			163,700,000
Portion Expected to be Reclassified to Net Income During the Next Twelve Months					$ 316,200,000			106,700,000
Derivatives and Hedging (Textuals) [Abstract]
Maximum Term for Exposure to Variability of Future Cash Flows					102 months
Cross Acceleration Provisions Maximum Third Party Obligation Amount		50,000,000			$ 50,000,000
Cross Default Provisions Maximum Third Party Obligation Amount		50,000,000			50,000,000
Commodity [Member] \| Risk Management Contracts [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[11],[12]	1,482,100,000			1,482,100,000			513,400,000
Long-term Risk Management Assets	[12]	686,600,000			686,600,000			370,500,000
Total Assets	[12]	2,168,700,000			2,168,700,000			883,900,000
Current Risk Management Liabilities	[12],[13]	1,005,700,000			1,005,700,000			395,700,000
Long-term Risk Management Liabilities	[12]	501,600,000			501,600,000			243,900,000
Total Liabilities	[12]	1,507,300,000			1,507,300,000			639,600,000
Total MTM Derivative Contract Net Assets (Liabilities)	[12]	661,400,000	[14]		661,400,000	[14]		244,300,000
Commodity [Member] \| Risk Management Contracts [Member] \| AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[12]	100,000			100,000			600,000
Long-term Risk Management Assets	[12]	(100,000)			(100,000)			0
Total Assets	[12]	0			0			600,000
Current Risk Management Liabilities	[12]	0			0			0
Long-term Risk Management Liabilities	[12]	0			0			0
Total Liabilities	[12]	0			0			0
Total MTM Derivative Contract Net Assets (Liabilities)	[12]	0			0			600,000
Commodity [Member] \| Risk Management Contracts [Member] \| Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[12]	106,800,000			106,800,000			47,500,000
Long-term Risk Management Assets	[12]	700,000			700,000			200,000
Total Assets	[12]	107,500,000			107,500,000			47,700,000
Current Risk Management Liabilities	[12]	0			0			7,200,000
Long-term Risk Management Liabilities	[12]	700,000			700,000			200,000
Total Liabilities	[12]	700,000			700,000			7,400,000
Total MTM Derivative Contract Net Assets (Liabilities)	[12]	106,800,000	[14]		106,800,000	[14]		40,300,000
Commodity [Member] \| Risk Management Contracts [Member] \| Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[12]	12,300,000			12,300,000			11,100,000
Long-term Risk Management Assets	[12]	600,000			600,000			200,000
Total Assets	[12]	12,900,000			12,900,000			11,300,000
Current Risk Management Liabilities	[12]	900,000			900,000			14,800,000
Long-term Risk Management Liabilities	[12]	500,000			500,000			200,000
Total Liabilities	[12]	1,400,000			1,400,000			15,000,000
Total MTM Derivative Contract Net Assets (Liabilities)	[12]	11,500,000	[14]		11,500,000	[14]		(3,700,000)
Commodity [Member] \| Risk Management Contracts [Member] \| Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[12]	2,000,000			2,000,000			500,000
Long-term Risk Management Assets	[12]	(100,000)			(100,000)			0
Total Assets	[12]	1,900,000			1,900,000			500,000
Current Risk Management Liabilities	[12]	0			0			6,700,000
Long-term Risk Management Liabilities	[12]	45,100,000			45,100,000			85,800,000
Total Liabilities	[12]	45,100,000			45,100,000			92,500,000
Total MTM Derivative Contract Net Assets (Liabilities)	[12]	(43,200,000)	[14]		(43,200,000)	[14]		(92,000,000)
Commodity [Member] \| Risk Management Contracts [Member] \| Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[12]	44,400,000			44,400,000			12,400,000
Long-term Risk Management Assets	[12]	0			0			0
Total Assets	[12]	44,400,000			44,400,000			12,400,000
Current Risk Management Liabilities	[12]	0			0			3,700,000
Long-term Risk Management Liabilities	[12]	0			0			0
Total Liabilities	[12]	0			0			3,700,000
Total MTM Derivative Contract Net Assets (Liabilities)	[12]	44,400,000	[14]		44,400,000	[14]		8,700,000
Commodity [Member] \| Risk Management Contracts [Member] \| Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[12]	37,200,000			37,200,000			10,100,000
Long-term Risk Management Assets	[12]	0			0			1,100,000
Total Assets	[12]	37,200,000			37,200,000			11,200,000
Current Risk Management Liabilities	[12]	800,000			800,000			2,100,000
Long-term Risk Management Liabilities	[12]	0			0			0
Total Liabilities	[12]	800,000			800,000			2,100,000
Total MTM Derivative Contract Net Assets (Liabilities)	[12]	36,400,000	[14]		36,400,000	[14]		9,100,000
Commodity [Member] \| Hedging Contracts [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[12]	411,100,000			411,100,000			176,000,000
Long-term Risk Management Assets	[12]	177,400,000			177,400,000			89,100,000
Total Assets	[12]	588,500,000			588,500,000			265,100,000
Current Risk Management Liabilities	[12]	10,900,000			10,900,000			40,900,000
Long-term Risk Management Liabilities	[12]	4,900,000			4,900,000			16,700,000
Total Liabilities	[12]	15,800,000			15,800,000			57,600,000
Total MTM Derivative Contract Net Assets (Liabilities)	[12]	572,700,000	[14]		572,700,000	[14]		207,500,000
Interest Rate [Member]
Commodity:
Derivative, Notional Amount		1,150,000,000			1,150,000,000			950,000,000
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		(2,600,000)			(2,600,000)			(21,300,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months					$ (1,500,000)			(3,300,000)
Derivatives and Hedging (Textuals) [Abstract]
Maximum Term for Exposure to Variability of Future Cash Flows					99 months
Deferred (Gain) Loss on Discontinuation of Fair Value Hedge		57,000,000			$ 57,000,000
Notional Amount of a Discontinued Hedge		500,000,000			500,000,000
Interest Rate [Member] \| AEP Texas Inc. [Member]
Commodity:
Derivative, Notional Amount		0			0			0
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		(500,000)			(500,000)			(1,300,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months					(400,000)			(1,100,000)
Interest Rate [Member] \| Appalachian Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0			0
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		6,900,000			6,900,000			7,500,000
Portion Expected to be Reclassified to Net Income During the Next Twelve Months					800,000			800,000
Interest Rate [Member] \| Indiana Michigan Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0			0
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		(5,500,000)			(5,500,000)			(6,700,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months					(1,000,000)			(1,600,000)
Interest Rate [Member] \| Ohio Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0			0
Interest Rate [Member] \| Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Notional Amount		0			0			0
Interest Rate [Member] \| Southwestern Electric Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0			0
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		1,200,000			1,200,000			1,200,000
Portion Expected to be Reclassified to Net Income During the Next Twelve Months					200,000			100,000
Interest Rate [Member] \| Hedging Contracts [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[12]	8,800,000			8,800,000			1,200,000
Long-term Risk Management Assets	[12]	0			0			0
Total Assets	[12]	8,800,000			8,800,000			1,200,000
Current Risk Management Liabilities	[12]	21,300,000			21,300,000			0
Long-term Risk Management Liabilities	[12]	114,100,000			114,100,000			38,100,000
Total Liabilities	[12]	135,400,000			135,400,000			38,100,000
Total MTM Derivative Contract Net Assets (Liabilities)	[12]	(126,600,000)	[14]		(126,600,000)	[14]		(36,900,000)
Gross Amounts of Risk Management Assets/Liabilities Recognized [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[11]	1,902,000,000			1,902,000,000			690,600,000
Long-term Risk Management Assets		864,000,000			864,000,000			459,600,000
Total Assets		2,766,000,000			2,766,000,000			1,150,200,000
Current Risk Management Liabilities	[13]	1,037,900,000			1,037,900,000			436,600,000
Long-term Risk Management Liabilities		620,600,000			620,600,000			298,700,000
Total Liabilities		1,658,500,000			1,658,500,000			735,300,000
Total MTM Derivative Contract Net Assets (Liabilities)		1,107,500,000			1,107,500,000			414,900,000
Gross Amounts Offset in the Statement of Financial Position [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[11],[15]	(1,331,800,000)			(1,331,800,000)			(496,200,000)
Long-term Risk Management Assets	[15]	(598,200,000)			(598,200,000)			(192,600,000)
Total Assets	[15]	(1,930,000,000)			(1,930,000,000)			(688,800,000)
Current Risk Management Liabilities	[13],[15]	(850,600,000)			(850,600,000)			(361,200,000)
Long-term Risk Management Liabilities	[15]	(232,400,000)			(232,400,000)			(68,400,000)
Total Liabilities	[15]	(1,083,000,000)			(1,083,000,000)			(429,600,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[15]	(847,000,000)	[14]		(847,000,000)	[14]		(259,200,000)
Gross Amounts Offset in the Statement of Financial Position [Member] \| AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[15]	100,000			100,000			(600,000)
Long-term Risk Management Assets	[15]	200,000			200,000			0
Total Assets	[15]	300,000			300,000			(600,000)
Current Risk Management Liabilities	[15]	0			0			0
Long-term Risk Management Liabilities	[15]	100,000			100,000			0
Total Liabilities	[15]	100,000			100,000			0
Total MTM Derivative Contract Net Assets (Liabilities)	[15]	200,000			200,000			(600,000)
Gross Amounts Offset in the Statement of Financial Position [Member] \| Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[15]	0			0			(5,500,000)
Long-term Risk Management Assets	[15]	(600,000)			(600,000)			(200,000)
Total Assets	[15]	(600,000)			(600,000)			(5,700,000)
Current Risk Management Liabilities	[15]	0			0			(6,400,000)
Long-term Risk Management Liabilities	[15]	(700,000)			(700,000)			(200,000)
Total Liabilities	[15]	(700,000)			(700,000)			(6,600,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[15]	100,000	[14]		100,000	[14]		900,000
Gross Amounts Offset in the Statement of Financial Position [Member] \| Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[15]	(900,000)			(900,000)			(7,800,000)
Long-term Risk Management Assets	[15]	(400,000)			(400,000)			(200,000)
Total Assets	[15]	(1,300,000)			(1,300,000)			(8,000,000)
Current Risk Management Liabilities	[15]	(900,000)			(900,000)			(9,800,000)
Long-term Risk Management Liabilities	[15]	(500,000)			(500,000)			(200,000)
Total Liabilities	[15]	(1,400,000)			(1,400,000)			(10,000,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[15]	100,000	[14]		100,000	[14]		2,000,000
Gross Amounts Offset in the Statement of Financial Position [Member] \| Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[15]	100,000			100,000			(500,000)
Long-term Risk Management Assets	[15]	100,000			100,000			0
Total Assets	[15]	200,000			200,000			(500,000)
Current Risk Management Liabilities	[15]	0			0			0
Long-term Risk Management Liabilities	[15]	0			0			0
Total Liabilities	[15]	0			0			0
Total MTM Derivative Contract Net Assets (Liabilities)	[15]	200,000	[14]		200,000	[14]		(500,000)
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	[15]	100,000			100,000			(300,000)
Long-term Risk Management Assets	[15]	0			0			0
Total Assets	[15]	100,000			100,000			(300,000)
Current Risk Management Liabilities	[15]	0			0			0
Long-term Risk Management Liabilities	[15]	0			0			0
Total Liabilities	[15]	0			0			0
Total MTM Derivative Contract Net Assets (Liabilities)	[15]	100,000	[14]		100,000	[14]		(300,000)
Gross Amounts Offset in the Statement of Financial Position [Member] \| Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[15]	(800,000)			(800,000)			(300,000)
Long-term Risk Management Assets	[15]	100,000			100,000			0
Total Assets	[15]	(700,000)			(700,000)			(300,000)
Current Risk Management Liabilities	[15]	(800,000)			(800,000)			0
Long-term Risk Management Liabilities	[15]	0			0			0
Total Liabilities	[15]	(800,000)			(800,000)			0
Total MTM Derivative Contract Net Assets (Liabilities)	[15]	100,000	[14]		100,000	[14]		(300,000)
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[11],[16]	570,200,000			570,200,000			194,400,000
Long-term Risk Management Assets	[16]	265,800,000			265,800,000			267,000,000
Total Assets	[16]	836,000,000			836,000,000			461,400,000
Current Risk Management Liabilities	[13],[16]	187,300,000			187,300,000			75,400,000
Long-term Risk Management Liabilities	[16]	388,200,000			388,200,000			230,300,000
Total Liabilities	[16]	575,500,000			575,500,000			305,700,000
Total MTM Derivative Contract Net Assets (Liabilities)	[16]	260,500,000	[14]		260,500,000	[14]		155,700,000
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	[16]	200,000			200,000			0
Long-term Risk Management Assets	[16]	100,000			100,000			0
Total Assets	[16]	300,000			300,000			0
Current Risk Management Liabilities	[16]	0			0			0
Long-term Risk Management Liabilities	[16]	100,000			100,000			0
Total Liabilities	[16]	100,000			100,000			0
Total MTM Derivative Contract Net Assets (Liabilities)	[16]	200,000			200,000			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	[16]	106,800,000			106,800,000			42,000,000
Long-term Risk Management Assets	[16]	100,000			100,000			0
Total Assets	[16]	106,900,000			106,900,000			42,000,000
Current Risk Management Liabilities	[16]	0			0			800,000
Long-term Risk Management Liabilities	[16]	0			0			0
Total Liabilities	[16]	0			0			800,000
Total MTM Derivative Contract Net Assets (Liabilities)	[16]	106,900,000	[14]		106,900,000	[14]		41,200,000
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	[16]	11,400,000			11,400,000			3,300,000
Long-term Risk Management Assets	[16]	200,000			200,000			0
Total Assets	[16]	11,600,000			11,600,000			3,300,000
Current Risk Management Liabilities	[16]	0			0			5,000,000
Long-term Risk Management Liabilities	[16]	0			0			0
Total Liabilities	[16]	0			0			5,000,000
Total MTM Derivative Contract Net Assets (Liabilities)	[16]	11,600,000	[14]		11,600,000	[14]		(1,700,000)
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	[16]	2,100,000			2,100,000			0
Long-term Risk Management Assets	[16]	0			0			0
Total Assets	[16]	2,100,000			2,100,000			0
Current Risk Management Liabilities	[16]	0			0			6,700,000
Long-term Risk Management Liabilities	[16]	45,100,000			45,100,000			85,800,000
Total Liabilities	[16]	45,100,000			45,100,000			92,500,000
Total MTM Derivative Contract Net Assets (Liabilities)	[16]	(43,000,000)	[14]		(43,000,000)	[14]		(92,500,000)
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	[16]	44,500,000			44,500,000			12,100,000
Long-term Risk Management Assets	[16]	0			0			0
Total Assets	[16]	44,500,000			44,500,000			12,100,000
Current Risk Management Liabilities	[16]	0			0			3,700,000
Long-term Risk Management Liabilities	[16]	0			0			0
Total Liabilities	[16]	0			0			3,700,000
Total MTM Derivative Contract Net Assets (Liabilities)	[16]	44,500,000	[14]		44,500,000	[14]		8,400,000
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	[16]	36,400,000			36,400,000			9,800,000
Long-term Risk Management Assets	[16]	100,000			100,000			1,100,000
Total Assets	[16]	36,500,000			36,500,000			10,900,000
Current Risk Management Liabilities	[16]	0			0			2,100,000
Long-term Risk Management Liabilities	[16]	0			0			0
Total Liabilities	[16]	0			0			2,100,000
Total MTM Derivative Contract Net Assets (Liabilities)	[16]	$ 36,500,000	[14]		$ 36,500,000	[14]		$ 8,800,000
Power [Member]
Commodity:
Derivative, Energy Notional Amount \| MWh		260.6			260.6			287.9
Power [Member] \| AEP Texas Inc. [Member]
Commodity:
Derivative, Energy Notional Amount \| MWh		0			0			0
Power [Member] \| Appalachian Power Co [Member]
Commodity:
Derivative, Energy Notional Amount \| MWh		29			29			33.1
Power [Member] \| Indiana Michigan Power Co [Member]
Commodity:
Derivative, Energy Notional Amount \| MWh		6.2			6.2			13.6
Power [Member] \| Ohio Power Co [Member]
Commodity:
Derivative, Energy Notional Amount \| MWh		2.6			2.6			2.7
Power [Member] \| Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Energy Notional Amount \| MWh		5.7			5.7			11.9
Power [Member] \| Southwestern Electric Power Co [Member]
Commodity:
Derivative, Energy Notional Amount \| MWh		4.3			4.3			3.4
Natural Gas [Member]
Commodity:
Derivative, Energy Notional Amount \| MMBTU		80.3			80.3			34.1
Natural Gas [Member] \| AEP Texas Inc. [Member]
Commodity:
Derivative, Energy Notional Amount \| MMBTU		0			0			0
Natural Gas [Member] \| Appalachian Power Co [Member]
Commodity:
Derivative, Energy Notional Amount \| MMBTU		0			0			0
Natural Gas [Member] \| Indiana Michigan Power Co [Member]
Commodity:
Derivative, Energy Notional Amount \| MMBTU		0			0			0
Natural Gas [Member] \| Ohio Power Co [Member]
Commodity:
Derivative, Energy Notional Amount \| MMBTU		0			0			0
Natural Gas [Member] \| Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Energy Notional Amount \| MMBTU		0			0			1.3
Natural Gas [Member] \| Southwestern Electric Power Co [Member]
Commodity:
Derivative, Energy Notional Amount \| MMBTU		1.8			1.8			5.1
Heating Oil and Gasoline [Member]
Commodity:
Derivative, Volume Notional Amount \| gal		6.4			6.4			7.4
Heating Oil and Gasoline [Member] \| AEP Texas Inc. [Member]
Commodity:
Derivative, Volume Notional Amount \| gal		1.7			1.7			1.9
Heating Oil and Gasoline [Member] \| Appalachian Power Co [Member]
Commodity:
Derivative, Volume Notional Amount \| gal		0.9			0.9			1.1
Heating Oil and Gasoline [Member] \| Indiana Michigan Power Co [Member]
Commodity:
Derivative, Volume Notional Amount \| gal		0.6			0.6			0.7
Heating Oil and Gasoline [Member] \| Ohio Power Co [Member]
Commodity:
Derivative, Volume Notional Amount \| gal		1.3			1.3			1.5
Heating Oil and Gasoline [Member] \| Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Volume Notional Amount \| gal		0.7			0.7			0.8
Heating Oil and Gasoline [Member] \| Southwestern Electric Power Co [Member]
Commodity:
Derivative, Volume Notional Amount \| gal		0.9			0.9			1
Interest Rate Contract [Member]
Commodity:
Derivative, Notional Amount		$ 99,900,000			$ 99,900,000			$ 116,500,000
Interest Rate Contract [Member] \| AEP Texas Inc. [Member]
Commodity:
Derivative, Notional Amount		0			0			0
Interest Rate Contract [Member] \| Appalachian Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0			0
Interest Rate Contract [Member] \| Indiana Michigan Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0			0
Interest Rate Contract [Member] \| Ohio Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0			0
Interest Rate Contract [Member] \| Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Notional Amount		0			0			0
Interest Rate Contract [Member] \| Southwestern Electric Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0			0
Held For Sale
Derivatives and Hedging (Textuals) [Abstract]
Assets Held for Sale		14,400,000			14,400,000			6,000,000
Liabilities Held for Sale		0			0			$ 100,000
Vertically Integrated Utilities Revenues [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		2,100,000		(900,000)	2,200,000		(600,000)
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		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		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		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		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		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		0
Generation and Marketing Revenues [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		116,700,000		128,800,000	390,000,000		144,900,000
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		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		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		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		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		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		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		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		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		300,000		(900,000)	400,000		(600,000)
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		0		0	(100,000)		0
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		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		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		0	0		0
Other Revenues [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0			0
Other 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
Other 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
Other 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		1,900,000			1,900,000
Other 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
Other 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
Other 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
Purchased Electricity for Resale [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		900,000		200,000	3,300,000		1,200,000
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		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		900,000		100,000	3,000,000		1,000,000
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		100,000		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		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	100,000		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		0
Other Operation Expense [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		1,400,000		900,000	3,700,000		1,900,000
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		400,000		300,000	1,100,000		600,000
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		100,000		100,000	300,000		200,000
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		100,000		100,000	400,000		200,000
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		200,000		100,000	600,000		300,000
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		200,000		100,000	500,000		200,000
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		200,000		200,000	600,000		300,000
Maintenance Expense [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		2,000,000		1,100,000	5,200,000		2,400,000
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		500,000		200,000	1,400,000		600,000
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		200,000		200,000	700,000		400,000
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		200,000		100,000	500,000		200,000
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		400,000		200,000	900,000		400,000
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		200,000		100,000	600,000		200,000
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		300,000		100,000	800,000		300,000
Regulatory Assets [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[17]	4,300,000		(7,200,000)	49,300,000		(7,900,000)
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	[17]	0		0	100,000		0
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	[17]	0		(2,900,000)	0		(2,900,000)
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	[17]	100,000		(16,900,000)	(1,200,000)		(22,900,000)
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	[17]	4,100,000		14,900,000	49,000,000		20,300,000
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	[17]	0		0	3,600,000		0
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	[17]	100,000		100,000	(2,100,000)		1,400,000
Regulatory Liabilities [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[17]	103,200,000		46,500,000	250,100,000		123,600,000
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	[17]	(1,500,000)		(100,000)	(600,000)		500,000
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	[17]	59,700,000		14,200,000	79,900,000		28,900,000
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	[17]	3,800,000		1,700,000	7,000,000		1,900,000
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	[17]	900,000		800,000	2,500,000		5,900,000
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	[17]	19,700,000		14,000,000	71,400,000		40,200,000
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	[17]	$ 7,000,000		$ 12,700,000	$ 64,800,000		$ 38,500,000

[1]Increase in amounts for the three and nine months ended September 30, 2022 are primarily due to increases in commodity prices for power and natural gas and an increase in value of FTRs.[2]Amounts include $(40) million and $(46) million as of September 30, 2022 and December 31, 2021, respectively, for the fair value hedge adjustment of hedged debt obligations for which hedge accounting has been discontinued.[3]Amounts included on the Balance Sheet within Current and Noncurrent Liabilities line items Long-term Debt Due within One Year and Long-term Debt, respectively.[4]Gain (Loss) is included in Interest Expense on the statements of income.[5]Amount excludes Risk Management Assets of $14.4 million and $6 million as of September 30, 2022 and December 31, 2021, respectively, classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.[6]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.’’[7]The September 30, 2022 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $2 million in 2022 and $9 million in periods 2023-2025; Level 2 matures $47 million in 2022, $363 million in periods 2023-2025, $10 million in periods 2026-2027 and $3 million in periods 2028-2033; Level 3 matures $87 million in 2022, $139 million in periods 2023-2025, $18 million in periods 2026-2027 and $(2) million in periods 2028-2033. Risk management commodity contracts are substantially comprised of power contracts.[8]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.[9]Amount excludes Risk Management Liabilities of $0 and $0.1 million as of September 30, 2022 and December 31, 2021, respectively, classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.[10]Substantially comprised of power contracts for the Registrant Subsidiaries.[11]Amount excludes Risk Management Assets of $14.4 million and $6 million as of September 30, 2022 and December 31, 2021, respectively, classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.[12]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.”[13]Amount excludes Risk Management Liabilities of $0 and $0.1 million as of September 30, 2022 and December 31, 2021, respectively, classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.[14]Increase in amounts as of September 30, 2022 are primarily due to increases in commodity prices for power and natural gas and an increase in value of FTRs.[15]Amounts include counterparty netting of risk management and hedging contracts and associated cash collateral in accordance with the accounting guidance for “Derivatives and Hedging.”[16]All derivative contracts subject to a master netting arrangement or similar agreement are offset in the statement of financial position.[17]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 ($)		3 Months Ended		9 Months Ended			12 Months Ended
		Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022		Sep. 30, 2021	Dec. 31, 2021
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding	[1]	$ 35,050,100,000		$ 35,050,100,000			$ 33,454,500,000
Long Term Debt, Fair Value	[2],[3]	30,352,700,000		30,352,700,000			37,564,700,000
Other Temporary Investments
Cost		248,700,000		248,700,000			232,000,000
Gross Unrealized Gains		18,600,000		18,600,000			36,400,000
Gross Unrealized Losses		(10,000,000)		(10,000,000)			0
Other Short-term Investments		257,300,000		257,300,000			268,400,000
Debt and Equity Securities Within Other Temporary Investments
Proceeds from Investment Sales		0	$ 6,000,000	15,000,000		$ 15,100,000
Purchases of Investments		11,800,000	12,900,000	13,400,000		26,000,000
Gross Realized Gains on Investment Sales		0	2,400,000	3,600,000		3,600,000
Gross Realized Losses on Investment Sales		0	0	500,000		0
Nuclear Trust Fund Investments
Fair Value		3,130,500,000		3,130,500,000			3,867,000,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		3,130,500,000		3,130,500,000			3,867,000,000
Fair Value Measurements (Textuals)
Liabilities Held for Sale		1,992,000,000		1,992,000,000			1,880,900,000
Spent Nuclear Fuel and Decommissioning Trusts [Member]
Unrealized Gain on Securities				1,300,000,000			1,900,000,000
Nuclear Trust Fund Investments
Gross Unrealized Gains				1,245,200,000			1,974,700,000
Securities Activity Within Decommissioning and SNF Trusts
Proceeds from Investment Sales		588,500,000	433,900,000	1,818,400,000		1,556,600,000
Purchases of Investments		601,600,000	436,600,000	1,854,800,000		1,586,300,000
Gross Realized Gains on Investment Sales		24,600,000	9,600,000	41,300,000		98,300,000
Gross Realized Losses on Investment Sales		8,400,000	7,000,000	33,500,000		12,500,000
Contractual Maturities, Fair Value of Debt Securities
Within 1 year		369,400,000		369,400,000
After 1 year through 5 years		393,800,000		393,800,000
After 5 years through 10 years		229,000,000		229,000,000
After 10 years		190,900,000		190,900,000
Fair Value Measurements (Textuals)
Adjusted Cost of Debt Securities		1,200,000,000		1,200,000,000			1,200,000,000
Adjusted Cost of Domestic Equity Securities		647,000,000		647,000,000			641,000,000
Unrealized Loss on Securities				14,000,000			4,000,000
Other than Temporary Impairment Losses, Investments				(41,100,000)			(10,100,000)
Cash [Member]
Other Temporary Investments
Cost	[4]	55,100,000		55,100,000			48,000,000
Gross Unrealized Gains	[4]	0		0			0
Gross Unrealized Losses	[4]	0		0			0
Other Short-term Investments	[4]	55,100,000		55,100,000			48,000,000
Fixed Income Funds [Member]
Nuclear Trust Fund Investments
Fair Value		1,183,100,000		1,183,100,000			1,240,400,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,183,100,000		1,183,100,000			1,240,400,000
Fixed Income Funds [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains				(33,900,000)			73,400,000
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				(41,100,000)			(10,100,000)
Mutual Funds Fixed Income [Member]
Other Temporary Investments
Cost	[5]	155,100,000		155,100,000			154,300,000
Gross Unrealized Gains	[5]	0		0			500,000
Gross Unrealized Losses	[5]	(9,700,000)		(9,700,000)			0
Other Short-term Investments	[5]	145,400,000		145,400,000			154,800,000
Domestic [Member]
Nuclear Trust Fund Investments
Fair Value	[6]	1,926,600,000		1,926,600,000			2,541,900,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[6]	1,926,600,000		1,926,600,000			2,541,900,000
Domestic [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains	[7]			1,279,100,000			1,901,300,000
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				0			0
Mutual Funds Equity [Member]
Other Temporary Investments
Cost		20,400,000		20,400,000			19,700,000
Gross Unrealized Gains		18,600,000		18,600,000			35,900,000
Gross Unrealized Losses		(300,000)		(300,000)			0
Other Short-term Investments	[6]	38,700,000		38,700,000			55,600,000
Cash and Cash Equivalents [Member]
Nuclear Trust Fund Investments
Fair Value	[8]	20,800,000		20,800,000			84,700,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[8]	20,800,000		20,800,000			84,700,000
Cash and Cash Equivalents [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains				0			0
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				0			0
US Government Agencies Debt Securities [Member]
Nuclear Trust Fund Investments
Fair Value		1,115,200,000		1,115,200,000			1,156,400,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,115,200,000		1,115,200,000			1,156,400,000
US Government Agencies Debt Securities [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains				(26,200,000)			66,300,000
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				(39,800,000)			(7,900,000)
Corporate Debt [Member]
Nuclear Trust Fund Investments
Fair Value		60,900,000		60,900,000			76,700,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		60,900,000		60,900,000			76,700,000
Corporate Debt [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains				(7,700,000)			6,700,000
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				(1,200,000)			(2,100,000)
State and Local Jurisdiction [Member]
Nuclear Trust Fund Investments
Fair Value		7,000,000		7,000,000			7,300,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		7,000,000		7,000,000			7,300,000
State and Local Jurisdiction [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains				0			400,000
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				(100,000)			(100,000)
Other Cash Deposits [Member]
Other Temporary Investments
Cost		18,100,000		18,100,000			10,000,000
Gross Unrealized Gains		0		0			0
Gross Unrealized Losses		0		0			0
Other Short-term Investments		18,100,000		18,100,000			10,000,000
AEP Texas Inc. [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		5,693,900,000		5,693,900,000			5,180,800,000
Long Term Debt, Fair Value		4,889,700,000		4,889,700,000			5,663,800,000
AEP Transmission Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		4,886,600,000		4,886,600,000			4,343,900,000
Long Term Debt, Fair Value		3,926,300,000		3,926,300,000			4,968,200,000
Fair Value Measurements (Textuals)
Liabilities Held for Sale		27,600,000		27,600,000			27,600,000
Appalachian Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		5,509,800,000		5,509,800,000			4,938,900,000
Long Term Debt, Fair Value		4,994,100,000		4,994,100,000			6,037,100,000
Indiana Michigan Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		3,206,700,000		3,206,700,000			3,195,000,000
Long Term Debt, Fair Value		2,846,200,000		2,846,200,000			3,748,000,000
Nuclear Trust Fund Investments
Fair Value		3,130,500,000		3,130,500,000			3,867,000,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		3,130,500,000		3,130,500,000			3,867,000,000
Indiana Michigan Power Co [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Unrealized Gain on Securities				1,300,000,000			1,900,000,000
Nuclear Trust Fund Investments
Gross Unrealized Gains				1,245,200,000			1,974,700,000
Securities Activity Within Decommissioning and SNF Trusts
Proceeds from Investment Sales		588,500,000	433,900,000	1,818,400,000		1,556,600,000
Purchases of Investments		601,600,000	436,600,000	1,854,800,000		1,586,300,000
Gross Realized Gains on Investment Sales		24,600,000	9,600,000	41,300,000		98,300,000
Gross Realized Losses on Investment Sales		8,400,000	$ 7,000,000	33,500,000		$ 12,500,000
Contractual Maturities, Fair Value of Debt Securities
Within 1 year		369,400,000		369,400,000
After 1 year through 5 years		393,800,000		393,800,000
After 5 years through 10 years		229,000,000		229,000,000
After 10 years		190,900,000		190,900,000
Fair Value Measurements (Textuals)
Adjusted Cost of Debt Securities		1,200,000,000		1,200,000,000			1,200,000,000
Adjusted Cost of Domestic Equity Securities		647,000,000		647,000,000			641,000,000
Unrealized Loss on Securities				14,000,000			4,000,000
Other than Temporary Impairment Losses, Investments				(41,100,000)			(10,100,000)
Indiana Michigan Power Co [Member] \| Fixed Income Funds [Member]
Nuclear Trust Fund Investments
Fair Value		1,183,100,000		1,183,100,000			1,240,400,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,183,100,000		1,183,100,000			1,240,400,000
Indiana Michigan Power Co [Member] \| Fixed Income Funds [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains				(33,900,000)			73,400,000
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				(41,100,000)			(10,100,000)
Indiana Michigan Power Co [Member] \| Domestic [Member]
Nuclear Trust Fund Investments
Fair Value	[6]	1,926,600,000		1,926,600,000			2,541,900,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[6]	1,926,600,000		1,926,600,000			2,541,900,000
Indiana Michigan Power Co [Member] \| Domestic [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains				1,279,100,000	[7]		1,901,300,000
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				0			0
Indiana Michigan Power Co [Member] \| Cash and Cash Equivalents [Member]
Nuclear Trust Fund Investments
Fair Value	[8]	20,800,000		20,800,000			84,700,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[8]	20,800,000		20,800,000			84,700,000
Indiana Michigan Power Co [Member] \| Cash and Cash Equivalents [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains				0			0
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				0			0
Indiana Michigan Power Co [Member] \| US Government Agencies Debt Securities [Member]
Nuclear Trust Fund Investments
Fair Value		1,115,200,000		1,115,200,000			1,156,400,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,115,200,000		1,115,200,000			1,156,400,000
Indiana Michigan Power Co [Member] \| US Government Agencies Debt Securities [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains				(26,200,000)			66,300,000
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				(39,800,000)			(7,900,000)
Indiana Michigan Power Co [Member] \| Corporate Debt [Member]
Nuclear Trust Fund Investments
Fair Value		60,900,000		60,900,000			76,700,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		60,900,000		60,900,000			76,700,000
Indiana Michigan Power Co [Member] \| Corporate Debt [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains				(7,700,000)			6,700,000
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				(1,200,000)			(2,100,000)
Indiana Michigan Power Co [Member] \| State and Local Jurisdiction [Member]
Nuclear Trust Fund Investments
Fair Value		7,000,000		7,000,000			7,300,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		7,000,000		7,000,000			7,300,000
Indiana Michigan Power Co [Member] \| State and Local Jurisdiction [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains				0			400,000
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				(100,000)			(100,000)
Ohio Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		2,969,900,000		2,969,900,000			2,968,500,000
Long Term Debt, Fair Value		2,442,000,000		2,442,000,000			3,437,500,000
Public Service Co Of Oklahoma [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		1,913,600,000		1,913,600,000			1,913,500,000
Long Term Debt, Fair Value		1,616,900,000		1,616,900,000			2,163,700,000
Southwestern Electric Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		3,392,400,000		3,392,400,000			3,395,200,000
Long Term Debt, Fair Value		2,797,300,000		2,797,300,000			3,792,900,000
Risk Management Commodity Contracts [Member]
Fair Value Measurements (Textuals)
Liabilities Held for Sale							100,000
Equity Units [Member]
Book Values and Fair Values of Long - term Debt
Long Term Debt, Fair Value		842,000,000		842,000,000			1,700,000,000
Held For Sale
Fair Value Measurements (Textuals)
Liabilities Held for Sale		1,200,000,000		1,200,000,000			1,100,000,000
Fair Value Held for Sale [Member]
Fair Value Measurements (Textuals)
Liabilities Held for Sale		$ 1,100,000,000		$ 1,100,000,000			$ 1,200,000,000

[1]The book value amounts exclude Long-term Debt of $1.2 billion and $1.1 billion as of September 30, 2022 and December 31, 2021, respectively, classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.[2]The fair value amounts exclude Long-term Debt of $1.1 billion and $1.2 billion as of September 30, 2022 and December 31, 2021, respectively, related to KPCo. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.[3]The fair value amounts include debt related to AEP’s Equity Units and had a fair value of $842 million and $1.7 billion as of September 30, 2022 and December 31, 2021, respectively. See “Equity Units” section of Note 12 for additional information.[4]Primarily represents amounts held for the repayment of debt.[5]Primarily short and intermediate maturities which may be sold and do not contain maturity dates.[6]Amounts represent publicly traded equity securities and equity-based mutual funds.[7]Amount reported as Gross Unrealized Gains includes unrealized gains of $1.3 billion and $1.9 billion and unrealized losses of $14 million and $4 million as of September 30, 2022 and December 31, 2021, respectively.[8]Amounts in “Other’’ column primarily represent accrued interest receivables from financial institutions. Level 1 amounts primarily represent investments in money market funds.

Fair Value Assets and Liabiliti

Fair Value Assets and Liabilities (Details) - USD ($)		3 Months Ended			9 Months Ended
Fair Value Assets and Liabilities (Details) - USD ($)		Sep. 30, 2022		Sep. 30, 2021	Sep. 30, 2022		Sep. 30, 2021	Dec. 31, 2021
Other [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		$ 18,100,000			$ 18,100,000			$ 10,000,000
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		10,400,000			10,400,000			7,000,000
Total Assets		(1,951,700,000)			(1,951,700,000)			(667,100,000)
Risk Management Assets
Risk Management Assets		(1,980,200,000)			(1,980,200,000)			(684,100,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities		(1,133,300,000)			(1,133,300,000)			(424,900,000)
Other Short-term Investments		257,300,000			257,300,000			268,400,000
Spent Nuclear Fuel and Decommissioning Trusts		3,130,500,000			3,130,500,000			3,867,000,000
Total Assets		4,223,800,000			4,223,800,000			4,640,500,000
Risk Management Assets		836,000,000			836,000,000			461,400,000
Risk Management Liabilities		575,500,000			575,500,000			305,700,000
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		270,400,000		$ 101,200,000	97,300,000		$ 113,300,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	64,300,000		27,500,000	69,300,000		68,900,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	(12,600,000)		2,900,000	(44,600,000)		(64,100,000)
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	13,100,000		17,800,000	29,400,000		35,500,000
Settlements		(138,300,000)		(54,500,000)	(153,800,000)		(113,300,000)
Transfers into Level 3	[4],[5]	(500,000)		(5,800,000)	1,700,000		(200,000)
Transfers out of Level 3	[5]	3,500,000		(4,100,000)	13,200,000		(26,200,000)
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	72,500,000		44,000,000	267,600,000		115,100,000
Assets and Liabilities Held for Sale related to KPCo		(8,500,000)			(8,500,000)
Ending Balance		271,600,000		129,000,000	271,600,000		129,000,000
Fair Value Measurements 1 (Textuals)
Assets Held for Sale		2,830,600,000			2,830,600,000			2,919,700,000
Liabilities Held for Sale		1,992,000,000			1,992,000,000			1,880,900,000
Total Long-term Debt Outstanding	[7]	35,050,100,000			35,050,100,000			33,454,500,000
Quarter to Date
Changes in the Fair Value of Net Trading Derivatives and other investments
Assets and Liabilities Held for Sale related to KPCo	[8]	(800,000)			(800,000)
Level 1 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		239,200,000			239,200,000			258,400,000
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,937,000,000			1,937,000,000			2,619,600,000
Total Assets		2,207,900,000			2,207,900,000			2,914,200,000
Risk Management Assets
Risk Management Assets		31,700,000			31,700,000			7,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		20,100,000			20,100,000			5,300,000
Level 2 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0			0
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,183,100,000			1,183,100,000			1,240,400,000
Total Assets		3,454,600,000			3,454,600,000			2,147,900,000
Risk Management Assets
Risk Management Assets		2,271,500,000			2,271,500,000			892,600,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		1,447,300,000			1,447,300,000			577,100,000
Level 3 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0			0
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
Total Assets		513,000,000			513,000,000			245,500,000
Risk Management Assets
Risk Management Assets		513,000,000			513,000,000			245,500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		241,400,000			241,400,000			148,200,000
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		2,000,000			2,000,000			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		47,000,000			47,000,000			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		87,000,000			87,000,000			82,000,000
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		9,000,000			9,000,000			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		363,000,000			363,000,000			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		139,000,000			139,000,000			10,000,000
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			10,000,000			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		18,000,000			18,000,000			9,000,000
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			3,000,000			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		(2,000,000)			(2,000,000)			(17,000,000)
Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets
Risk Management Assets	[9],[10]	(1,910,800,000)	[11]		(1,910,800,000)	[11]		(642,400,000)	[12]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[13]	(1,063,900,000)	[11]		(1,063,900,000)	[11]		(383,200,000)	[12]
Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[9],[10]	238,700,000	[11]		238,700,000	[11]		239,800,000	[12]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[13]	424,400,000	[11]		424,400,000	[11]		254,700,000	[12]
Fair Value Measurements 1 (Textuals)
Assets Held for Sale		14,400,000			14,400,000			6,000,000
Liabilities Held for Sale								100,000
Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets
Risk Management Assets	[9],[10]	31,700,000	[11]		31,700,000	[11]		7,400,000	[12]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[13]	20,100,000	[11]		20,100,000	[11]		5,300,000	[12]
Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets
Risk Management Assets	[9],[10]	1,650,100,000	[11]		1,650,100,000	[11]		648,500,000	[12]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[13]	1,227,700,000	[11]		1,227,700,000	[11]		485,000,000	[12]
Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Risk Management Assets	[9],[10]	467,700,000	[11]		467,700,000	[11]		226,300,000	[12]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[13]	240,500,000	[11]		240,500,000	[11]		147,600,000	[12]
Energy Contracts [Member] \| Held For Sale
Fair Value Measurements 1 (Textuals)
Liabilities Held for Sale								100,000
Energy Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Risk Management Assets		292,700,000			292,700,000			164,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		230,600,000			230,600,000			135,200,000	[14]
Energy Contracts [Member] \| Level 3 [Member] \| Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15]	(4.31)			(4.31)			10.30
Energy Contracts [Member] \| Level 3 [Member] \| High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15]	172.05			172.05			76.70
Energy Contracts [Member] \| Level 3 [Member] \| Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15],[16]	49.58			49.58			37.11
Natural Gas Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Risk Management Assets		6,900,000			6,900,000			3,600,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0			0
Natural Gas Contracts [Member] \| Level 3 [Member] \| Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[17]	3.22			3.22			3.11
Natural Gas Contracts [Member] \| Level 3 [Member] \| High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[17]	7.37			7.37			4.02
Natural Gas Contracts [Member] \| Level 3 [Member] \| Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[16],[17]	5.92			5.92			3.47
FTRs [Member] \| Held For Sale
Fair Value Measurements 1 (Textuals)
Assets Held for Sale		14,400,000			14,400,000			6,000,000
Liabilities Held for Sale		100,000			100,000			500,000
FTRs [Member] \| Level 3 [Member]
Risk Management Assets
Risk Management Assets		213,400,000	[18]		213,400,000	[18]		77,500,000	[19]
Liabilities, Fair Value Disclosure
Risk Management Liabilities		10,800,000	[20]		10,800,000	[20]		13,000,000	[21]
FTRs [Member] \| Level 3 [Member] \| Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15]	(37.97)			(37.97)			(23.93)
FTRs [Member] \| Level 3 [Member] \| High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15]	27.55			27.55			26.38
FTRs [Member] \| Level 3 [Member] \| Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15],[16]	0.99			0.99			0.86
Commodity Hedges [Member] \| Other [Member]
Risk Management Assets
Risk Management Assets	[10]	(68,900,000)			(68,900,000)			(41,700,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10]	(68,900,000)			(68,900,000)			(41,700,000)
Commodity Hedges [Member]
Risk Management Assets
Risk Management Assets	[10]	588,500,000			588,500,000			220,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10]	15,700,000			15,700,000			12,900,000
Commodity Hedges [Member] \| Level 1 [Member]
Risk Management Assets
Risk Management Assets	[10]	0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10]	0			0			0
Commodity Hedges [Member] \| Level 2 [Member]
Risk Management Assets
Risk Management Assets	[10]	612,100,000			612,100,000			242,900,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10]	83,700,000			83,700,000			54,000,000
Commodity Hedges [Member] \| Level 3 [Member]
Risk Management Assets
Risk Management Assets	[10]	45,300,000			45,300,000			19,200,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10]	900,000			900,000			600,000
Interest Rate [Member] \| Other [Member]
Risk Management Assets
Risk Management Assets		(500,000)			(500,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities		(500,000)			(500,000)
Interest Rate [Member]
Risk Management Assets
Risk Management Assets		8,800,000			8,800,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0
Interest Rate [Member] \| Level 1 [Member]
Risk Management Assets
Risk Management Assets		0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0
Interest Rate [Member] \| Level 2 [Member]
Risk Management Assets
Risk Management Assets		9,300,000			9,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		500,000			500,000
Interest Rate [Member] \| Level 3 [Member]
Risk Management Assets
Risk Management Assets		0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0
Fair Value Hedges [Member] \| Other [Member]
Risk Management Assets
Risk Management Assets								0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0			0
Fair Value Hedges [Member]
Risk Management Assets
Risk Management Assets								1,200,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		135,400,000			135,400,000			38,100,000
Fair Value Hedges [Member] \| Level 1 [Member]
Risk Management Assets
Risk Management Assets								0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0			0
Fair Value Hedges [Member] \| Level 2 [Member]
Risk Management Assets
Risk Management Assets								1,200,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		135,400,000			135,400,000			38,100,000
Fair Value Hedges [Member] \| Level 3 [Member]
Risk Management Assets
Risk Management Assets								0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0			0
Other Investments \| Other [Member]
Risk Management Assets
Risk Management Assets	[22]							0
Other Investments
Risk Management Assets
Risk Management Assets	[22]							43,700,000
Other Investments \| Level 1 [Member]
Risk Management Assets
Risk Management Assets	[22]							28,800,000
Other Investments \| Level 2 [Member]
Risk Management Assets
Risk Management Assets	[22]							14,900,000
Other Investments \| Level 3 [Member]
Risk Management Assets
Risk Management Assets	[22]							0
AEP Texas Inc. [Member] \| Other [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		200,000			200,000			(600,000)
AEP Texas Inc. [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		47,700,000			47,700,000			30,400,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		48,000,000			48,000,000			30,400,000
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		5,693,900,000			5,693,900,000			5,180,800,000
AEP Texas Inc. [Member] \| Level 1 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		47,700,000			47,700,000			30,400,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		47,700,000			47,700,000			30,400,000
AEP Texas Inc. [Member] \| Level 2 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		100,000			100,000			600,000
AEP Texas Inc. [Member] \| Level 3 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		0			0			0
AEP Texas Inc. [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets
Risk Management Assets	[10]	200,000			200,000			(600,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10]	0			0
AEP Texas Inc. [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[10]	300,000			300,000			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10]	100,000			100,000
AEP Texas Inc. [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets
Risk Management Assets	[10]	0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10]	0			0
AEP Texas Inc. [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets
Risk Management Assets	[10]	100,000			100,000			600,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10]	100,000			100,000
AEP Texas Inc. [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Risk Management Assets	[10]	0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10]	0			0
AEP Transmission Co [Member]
Fair Value Measurements 1 (Textuals)
Assets Held for Sale		173,700,000			173,700,000			167,900,000
Liabilities Held for Sale		27,600,000			27,600,000			27,600,000
Total Long-term Debt Outstanding		4,886,600,000			4,886,600,000			4,343,900,000
Appalachian Power Co [Member] \| Other [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		(800,000)			(800,000)			(5,800,000)
Appalachian Power Co [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		7,400,000			7,400,000			17,600,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		114,200,000			114,200,000			59,600,000
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		79,600,000		36,600,000	41,700,000		19,300,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	20,100,000		4,000,000	3,000,000		38,800,000
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		0
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	0		0	0		0
Settlements		(34,600,000)		(10,500,000)	(44,700,000)		(58,200,000)
Transfers into Level 3	[4],[5]	0		0	0		0
Transfers out of Level 3	[5]	0		100,000	0		0
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	41,500,000		15,700,000	106,600,000		46,000,000
Assets and Liabilities Held for Sale related to KPCo		0			0
Ending Balance		106,600,000		45,900,000	106,600,000		45,900,000
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		5,509,800,000			5,509,800,000			4,938,900,000
Appalachian Power Co [Member] \| Quarter to Date
Changes in the Fair Value of Net Trading Derivatives and other investments
Assets and Liabilities Held for Sale related to KPCo		0			0
Appalachian Power Co [Member] \| Level 1 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		7,400,000			7,400,000			17,600,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		7,400,000			7,400,000			17,600,000
Appalachian Power Co [Member] \| Level 2 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		900,000			900,000			5,800,000
Appalachian Power Co [Member] \| Level 3 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		106,700,000			106,700,000			42,000,000
Risk Management Assets
Risk Management Assets								42,000,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities								300,000
Appalachian Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	(800,000)			(800,000)			(5,800,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[23]	(800,000)			(800,000)			(6,700,000)
Appalachian Power Co [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	106,800,000			106,800,000			42,000,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[23]	0			0			800,000
Appalachian Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[23]	0			0			0
Appalachian Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	900,000			900,000			5,800,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[23]	700,000			700,000			7,200,000
Appalachian Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	106,700,000			106,700,000			42,000,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[23]	100,000			100,000			300,000
Appalachian Power Co [Member] \| Energy Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Risk Management Assets								0
Liabilities, Fair Value Disclosure
Risk Management Liabilities								300,000
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
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
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
Appalachian Power Co [Member] \| FTRs [Member] \| Level 3 [Member]
Risk Management Assets
Risk Management Assets		106,700,000			106,700,000			42,000,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		100,000			100,000			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]	(2.01)			(2.01)			(0.30)
Appalachian Power Co [Member] \| FTRs [Member] \| Level 3 [Member] \| High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[15]	20.64			20.64			26.38
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]	3.75			3.75			2.63
Indiana Michigan Power Co [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		10,400,000			10,400,000			7,000,000
Total Assets		9,300,000			9,300,000			(1,100,000)
Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		3,130,500,000			3,130,500,000			3,867,000,000
Total Assets		3,142,100,000			3,142,100,000			3,870,300,000
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		9,800,000		7,300,000	(700,000)		2,100,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	2,100,000		100,000	3,700,000		400,000
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		0
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	0		0	0		0
Settlements		(4,800,000)		(3,800,000)	(3,000,000)		(2,500,000)
Transfers into Level 3	[4],[5]	0		0	0		0
Transfers out of Level 3	[5]	0		0	0		0
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	2,500,000		(300,000)	9,600,000		3,300,000
Assets and Liabilities Held for Sale related to KPCo		0			0
Ending Balance		9,600,000		3,300,000	9,600,000		3,300,000
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		3,206,700,000			3,206,700,000			3,195,000,000
Indiana Michigan Power Co [Member] \| Quarter to Date
Changes in the Fair Value of Net Trading Derivatives and other investments
Assets and Liabilities Held for Sale related to KPCo		0			0
Indiana Michigan Power Co [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,937,000,000			1,937,000,000			2,619,600,000
Total Assets		1,937,000,000			1,937,000,000			2,619,600,000
Indiana Michigan Power Co [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,183,100,000			1,183,100,000			1,240,400,000
Total Assets		1,185,500,000			1,185,500,000			1,244,200,000
Indiana Michigan Power Co [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
Total Assets		10,300,000			10,300,000			7,600,000
Risk Management Assets
Risk Management Assets								7,600,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities								8,300,000
Indiana Michigan Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	(1,100,000)			(1,100,000)			(8,100,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[23]	(1,200,000)			(1,200,000)			(10,000,000)
Indiana Michigan Power Co [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	11,600,000			11,600,000			3,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[23]	0			0			5,000,000
Indiana Michigan Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[23]	0			0			0
Indiana Michigan Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	2,400,000			2,400,000			3,800,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[23]	500,000			500,000			6,700,000
Indiana Michigan Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	10,300,000			10,300,000			7,600,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[23]	700,000			700,000			8,300,000
Indiana Michigan Power Co [Member] \| Energy Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Risk Management Assets								0
Liabilities, Fair Value Disclosure
Risk Management Liabilities								200,000
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
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
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
Indiana Michigan Power Co [Member] \| FTRs [Member] \| Level 3 [Member]
Risk Management Assets
Risk Management Assets		10,300,000			10,300,000			7,600,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		700,000			700,000			8,100,000
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]	0.21			0.21			(5.45)
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]	17.73			17.73			17.78
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]	1.61			1.61			(0.12)
Ohio Power Co [Member]
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		(48,400,000)		(105,400,000)	(92,500,000)		(110,300,000)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	300,000		100,000	4,600,000		400,000
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		0
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	0		0	0		0
Settlements		(1,100,000)		900,000	200,000		5,800,000
Transfers into Level 3	[4],[5]	0		0	0		0
Transfers out of Level 3	[5]	0		0	0		0
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	6,000,000		14,000,000	44,500,000		13,700,000
Assets and Liabilities Held for Sale related to KPCo		0			0
Ending Balance		(43,200,000)		(90,400,000)	(43,200,000)		(90,400,000)
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		2,969,900,000			2,969,900,000			2,968,500,000
Ohio Power Co [Member] \| Quarter to Date
Changes in the Fair Value of Net Trading Derivatives and other investments
Assets and Liabilities Held for Sale related to KPCo		0			0
Ohio Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	2,000,000			2,000,000			(500,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[23]	1,800,000			1,800,000			0
Ohio Power Co [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	2,100,000			2,100,000			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[23]	45,100,000			45,100,000			92,500,000
Ohio Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[23]	0			0			0
Ohio Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	100,000			100,000			500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[23]	100,000			100,000			0
Ohio Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[23]	43,200,000			43,200,000			92,500,000
Ohio Power Co [Member] \| Energy Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Risk Management Assets		0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		43,200,000			43,200,000			92,500,000
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]	1.65			1.65			14.26
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]	143.38			143.38			52.98
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]	47.12			47.12			30.68
Public Service Co Of Oklahoma [Member]
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		64,500,000		22,900,000	12,100,000		10,300,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	23,800,000		13,500,000	24,200,000		16,100,000
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		0
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	0		0	0		0
Settlements		(49,100,000)		(20,600,000)	(36,300,000)		(26,400,000)
Transfers into Level 3	[4],[5]	0		0	0		0
Transfers out of Level 3	[5]	0		0	0		0
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	5,200,000		2,700,000	44,400,000		18,500,000
Assets and Liabilities Held for Sale related to KPCo		0			0
Ending Balance		44,400,000		18,500,000	44,400,000		18,500,000
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		1,913,600,000			1,913,600,000			1,913,500,000
Public Service Co Of Oklahoma [Member] \| Quarter to Date
Changes in the Fair Value of Net Trading Derivatives and other investments
Assets and Liabilities Held for Sale related to KPCo		0			0
Public Service Co Of Oklahoma [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	(700,000)			(700,000)			(400,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[23]	(800,000)			(800,000)			(100,000)
Public Service Co Of Oklahoma [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	44,500,000			44,500,000			12,100,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[23]	0			0			3,700,000
Public Service Co Of Oklahoma [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[23]	0			0			0
Public Service Co Of Oklahoma [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	0			0			300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[23]	0			0			3,700,000
Public Service Co Of Oklahoma [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	45,200,000			45,200,000			12,200,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[23]	800,000			800,000			100,000
Public Service Co Of Oklahoma [Member] \| FTRs [Member] \| Level 3 [Member]
Risk Management Assets
Risk Management Assets		45,200,000			45,200,000			12,200,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		800,000			800,000			100,000
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]	(36.83)			(36.83)			(18.39)
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]	5.65			5.65			1.87
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]	(7.55)			(7.55)			(2.57)
Southwestern Electric Power Co [Member]
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		45,400,000		14,600,000	10,900,000		1,600,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	15,400,000		5,800,000	35,800,000		9,500,000
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		0
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	0		0	0		0
Settlements		(31,600,000)		(9,800,000)	(45,000,000)		(13,000,000)
Transfers into Level 3	[4],[5]	0		0	0		0
Transfers out of Level 3	[5]	0		0	0		0
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	7,000,000		9,000,000	34,500,000		21,500,000
Assets and Liabilities Held for Sale related to KPCo		0			0
Ending Balance		36,200,000		$ 19,600,000	36,200,000		$ 19,600,000
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		3,392,400,000			3,392,400,000			3,395,200,000
Southwestern Electric Power Co [Member] \| Quarter to Date
Changes in the Fair Value of Net Trading Derivatives and other investments
Assets and Liabilities Held for Sale related to KPCo		0			0
Southwestern Electric Power Co [Member] \| Level 3 [Member]
Risk Management Assets
Risk Management Assets		37,000,000			37,000,000			11,000,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		800,000			800,000			100,000
Southwestern Electric Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	(700,000)			(700,000)			(400,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[23]	(800,000)			(800,000)			(100,000)
Southwestern Electric Power Co [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	36,400,000			36,400,000			10,900,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[23]	0			0			2,100,000
Southwestern Electric Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[23]	0			0			0
Southwestern Electric Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	100,000			100,000			300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[23]	0			0			2,100,000
Southwestern Electric Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Risk Management Assets	[10],[23]	37,000,000			37,000,000			11,000,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[10],[23]	800,000			800,000			100,000
Southwestern Electric Power Co [Member] \| Natural Gas Contracts [Member] \| Level 3 [Member]
Risk Management Assets
Risk Management Assets		6,900,000			6,900,000			3,600,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0			0
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]	6.15			6.15			3.11
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]	7.37			7.37			4.02
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]	6.94			6.94			3.47
Southwestern Electric Power Co [Member] \| FTRs [Member] \| Level 3 [Member]
Risk Management Assets
Risk Management Assets		30,100,000			30,100,000			7,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		800,000			800,000			100,000
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]	(36.83)			(36.83)			(18.39)
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]	5.65			5.65			1.87
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]	(7.55)			(7.55)			(2.57)
Cash [Member] \| Other [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents	[24]	0			0			0
Cash [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents	[24]	55,100,000			55,100,000			48,000,000
Other Short-term Investments	[25]	55,100,000			55,100,000			48,000,000
Cash [Member] \| Level 1 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents	[24]	55,100,000			55,100,000			48,000,000
Cash [Member] \| Level 2 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents	[24]	0			0			0
Cash [Member] \| Level 3 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents	[24]	0			0			0
Other Cash Deposits [Member] \| Other [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		18,100,000			18,100,000			10,000,000
Other Cash Deposits [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		18,100,000			18,100,000			10,000,000
Other Cash Deposits [Member] \| Level 1 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0			0
Other Cash Deposits [Member] \| Level 2 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0			0
Other Cash Deposits [Member] \| Level 3 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0			0
Mutual Funds Fixed Income [Member] \| Other [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0			0
Mutual Funds Fixed Income [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[26]	145,400,000			145,400,000			154,800,000
Mutual Funds Fixed Income [Member] \| Level 1 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		145,400,000			145,400,000			154,800,000
Mutual Funds Fixed Income [Member] \| Level 2 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0			0
Mutual Funds Fixed Income [Member] \| Level 3 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0			0
Mutual Funds Equity [Member] \| Other [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[27]	0			0			0
Mutual Funds Equity [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[27]	38,700,000			38,700,000			55,600,000
Mutual Funds Equity [Member] \| Level 1 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[27]	38,700,000			38,700,000			55,600,000
Mutual Funds Equity [Member] \| Level 2 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[27]	0			0			0
Mutual Funds Equity [Member] \| Level 3 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[27]	0			0			0
Cash and Cash Equivalents [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[28]	10,400,000			10,400,000			7,000,000
Cash and Cash Equivalents [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[28]	20,800,000			20,800,000			84,700,000
Cash and Cash Equivalents [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[28]	10,400,000			10,400,000			77,700,000
Cash and Cash Equivalents [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[28]	0			0			0
Cash and Cash Equivalents [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[28]	0			0			0
Cash and Cash Equivalents [Member] \| Indiana Michigan Power Co [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[28]	10,400,000			10,400,000			7,000,000
Cash and Cash Equivalents [Member] \| Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[28]	20,800,000			20,800,000			84,700,000
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	[28]	10,400,000			10,400,000			77,700,000
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	[28]	0			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	[28]	0			0			0
US Government Agencies Debt Securities [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
US Government Agencies Debt Securities [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,115,200,000			1,115,200,000			1,156,400,000
US Government Agencies Debt Securities [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
US Government Agencies Debt Securities [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,115,200,000			1,115,200,000			1,156,400,000
US Government Agencies Debt Securities [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
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			0
US Government Agencies Debt Securities [Member] \| Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,115,200,000			1,115,200,000			1,156,400,000
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			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		1,115,200,000			1,115,200,000			1,156,400,000
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			0
Corporate Debt [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
Corporate Debt [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		60,900,000			60,900,000			76,700,000
Corporate Debt [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
Corporate Debt [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		60,900,000			60,900,000			76,700,000
Corporate Debt [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
Corporate Debt [Member] \| Indiana Michigan Power Co [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
Corporate Debt [Member] \| Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		60,900,000			60,900,000			76,700,000
Corporate Debt [Member] \| Indiana Michigan Power Co [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
Corporate Debt [Member] \| Indiana Michigan Power Co [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		60,900,000			60,900,000			76,700,000
Corporate Debt [Member] \| Indiana Michigan Power Co [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
State and Local Jurisdiction [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
State and Local Jurisdiction [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		7,000,000			7,000,000			7,300,000
State and Local Jurisdiction [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
State and Local Jurisdiction [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		7,000,000			7,000,000			7,300,000
State and Local Jurisdiction [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
State and Local Jurisdiction [Member] \| Indiana Michigan Power Co [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
State and Local Jurisdiction [Member] \| Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		7,000,000			7,000,000			7,300,000
State and Local Jurisdiction [Member] \| Indiana Michigan Power Co [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
State and Local Jurisdiction [Member] \| Indiana Michigan Power Co [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		7,000,000			7,000,000			7,300,000
State and Local Jurisdiction [Member] \| Indiana Michigan Power Co [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
Fixed Income Funds [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
Fixed Income Funds [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,183,100,000			1,183,100,000			1,240,400,000
Fixed Income Funds [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
Fixed Income Funds [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,183,100,000			1,183,100,000			1,240,400,000
Fixed Income Funds [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
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			0
Fixed Income Funds [Member] \| Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,183,100,000			1,183,100,000			1,240,400,000
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			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		1,183,100,000			1,183,100,000			1,240,400,000
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			0
Domestic [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[27]	0			0			0
Domestic [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[27]	1,926,600,000			1,926,600,000			2,541,900,000
Domestic [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[27]	1,926,600,000			1,926,600,000			2,541,900,000
Domestic [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[27]	0			0			0
Domestic [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[27]	0			0			0
Domestic [Member] \| Indiana Michigan Power Co [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[27]	0			0			0
Domestic [Member] \| Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[27]	1,926,600,000			1,926,600,000			2,541,900,000
Domestic [Member] \| Indiana Michigan Power Co [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[27]	1,926,600,000			1,926,600,000			2,541,900,000
Domestic [Member] \| Indiana Michigan Power Co [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[27]	0			0			0
Domestic [Member] \| Indiana Michigan Power Co [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[27]	$ 0			$ 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]The book value amounts exclude Long-term Debt of $1.2 billion and $1.1 billion as of September 30, 2022 and December 31, 2021, respectively, classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.[8]Amount represents Risk Management Assets classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.[9]Amount excludes Risk Management Assets of $14.4 million and $6 million as of September 30, 2022 and December 31, 2021, respectively, classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 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 September 30, 2022 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $2 million in 2022 and $9 million in periods 2023-2025; Level 2 matures $47 million in 2022, $363 million in periods 2023-2025, $10 million in periods 2026-2027 and $3 million in periods 2028-2033; Level 3 matures $87 million in 2022, $139 million in periods 2023-2025, $18 million in periods 2026-2027 and $(2) million in periods 2028-2033. Risk management commodity contracts are substantially comprised of power contracts.[12]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.[13]Amount excludes Risk Management Liabilities of $0 and $0.1 million as of September 30, 2022 and December 31, 2021, respectively, classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 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 6 for additional information . Amount excludes Risk Management Assets of $14.4 million classified as Assets Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 for additional information . 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 6 for additional information . 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 6 for additional information . 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 6 for additional information .

Income Taxes (Details)

Income Taxes (Details)	3 Months Ended		9 Months Ended
Income Taxes (Details)	Sep. 30, 2022	Sep. 30, 2021	Sep. 30, 2022	Sep. 30, 2021
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21%	21%	21%	21%
State Income Tax, net of Federal Benefit	(0.80%)	0.60%	0.70%	1.20%
Tax Reform Excess ADIT Reversal	(9.70%)	(8.50%)	(7.80%)	(8.90%)
Production and Investment Tax Credits	(12.00%)	(4.70%)	(8.70%)	(4.90%)
Flow Through	(0.30%)	0%	0%	0.20%
AFUDC Equity	(1.40%)	(1.20%)	(1.10%)	(1.10%)
Parent Company Loss Benefit		0%		0%
Discrete Tax Adjustments	(0.20%)	0.20%	(0.20%)	1.10%
Other	1%	0.70%	0.60%	0.10%
Effective Income Tax Rate	(2.40%)	8.10%	4.50%	8.70%
Corporate Alternative Minimum Tax
Effective Income Tax Rate Reconciliation, Percent [Abstract]
Effective Income Tax Rate			15%
AEP Texas Inc. [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21%	21%	21%	21%
State Income Tax, net of Federal Benefit	0.50%	0.30%	0.50%	0.30%
Tax Reform Excess ADIT Reversal	(2.00%)	(6.30%)	(2.00%)	(7.20%)
Production and Investment Tax Credits	(0.40%)	(0.30%)	(0.40%)	(0.30%)
Flow Through	0.20%	0.30%	0.20%	0.30%
AFUDC Equity	(1.20%)	(1.00%)	(1.20%)	(1.10%)
Parent Company Loss Benefit		(1.10%)		(0.70%)
Discrete Tax Adjustments	0%	0%	0%	0%
Other	0.20%	(0.10%)	0.10%	0%
Effective Income Tax Rate	18.30%	12.80%	18.20%	12.30%
AEP Transmission Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21%	21%	21%	21%
State Income Tax, net of Federal Benefit	2.60%	3%	2.70%	2.80%
Tax Reform Excess ADIT Reversal	0.30%	0.30%	0.30%	0.30%
Production and Investment Tax Credits	0%	0%	0%	0%
Flow Through	0.30%	0.30%	0.30%	0.30%
AFUDC Equity	(1.90%)	(2.20%)	(1.90%)	(1.90%)
Parent Company Loss Benefit		(2.30%)		(1.90%)
Discrete Tax Adjustments	0%	0%	0%	0%
Other	0.20%	0.10%	0.10%	0%
Effective Income Tax Rate	22.50%	20.20%	22.50%	20.60%
Appalachian Power Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21%	21%	21%	21%
State Income Tax, net of Federal Benefit	(6.20%)	(0.30%)	(0.80%)	1.50%
Tax Reform Excess ADIT Reversal	(8.60%)	(14.20%)	(10.30%)	(15.20%)
Production and Investment Tax Credits	0%	(0.20%)	0%	0%
Flow Through	(0.70%)	0.40%	0.20%	1.70%
AFUDC Equity	(0.40%)	(1.80%)	(0.80%)	(1.20%)
Parent Company Loss Benefit		(1.20%)		(1.30%)
Discrete Tax Adjustments	0%	0%	(1.80%)	0%
Other	0%	0.30%	0%	0.10%
Effective Income Tax Rate	5.10%	4%	7.50%	6.60%
Indiana Michigan Power Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21%	21%	21%	21%
State Income Tax, net of Federal Benefit	2.70%	1.90%	1.30%	1.60%
Tax Reform Excess ADIT Reversal	(13.30%)	(16.10%)	(15.70%)	(17.70%)
Production and Investment Tax Credits	0%	(2.00%)	(1.40%)	(2.20%)
Flow Through	(1.50%)	(2.80%)	(1.60%)	(3.00%)
AFUDC Equity	(0.60%)	(1.00%)	(0.80%)	(1.00%)
Parent Company Loss Benefit		(3.60%)		(2.80%)
Discrete Tax Adjustments	0%	0%	0%	0%
Other	(0.50%)	0.80%	0.20%	0.40%
Effective Income Tax Rate	7.80%	(1.80%)	3%	(3.70%)
Ohio Power Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21%	21%	21%	21%
State Income Tax, net of Federal Benefit	0.70%	1.20%	0.80%	0.80%
Tax Reform Excess ADIT Reversal	(6.20%)	(8.90%)	(7.30%)	(9.10%)
Production and Investment Tax Credits	0%	0%	0%	0%
Flow Through	0.40%	0.60%	0.50%	0.90%
AFUDC Equity	(0.80%)	(0.30%)	(0.70%)	(0.80%)
Parent Company Loss Benefit		0%		0%
Discrete Tax Adjustments	0%	0%	0%	(1.30%)
Other	0.20%	0%	0.10%	0.20%
Effective Income Tax Rate	15.30%	13.60%	14.40%	11.70%
Public Service Co Of Oklahoma [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21%	21%	21%	21%
State Income Tax, net of Federal Benefit	3%	5%	3.20%	4.80%
Tax Reform Excess ADIT Reversal	(21.90%)	(19.80%)	(20.80%)	(19.80%)
Production and Investment Tax Credits	(43.70%)	(8.90%)	(39.50%)	(8.10%)
Flow Through	0.40%	0.70%	0.30%	0.70%
AFUDC Equity	(0.40%)	(0.20%)	(0.40%)	(0.30%)
Parent Company Loss Benefit		0%		0%
Discrete Tax Adjustments	0%	0%	0%	(0.90%)
Other	0.20%	(0.10%)	0.20%	(0.20%)
Effective Income Tax Rate	(41.40%)	(2.30%)	(36.00%)	(2.80%)
Southwestern Electric Power Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21%	21%	21%	21%
State Income Tax, net of Federal Benefit	(5.30%)	(6.90%)	(1.50%)	(3.40%)
Tax Reform Excess ADIT Reversal	(4.60%)	(4.20%)	(4.80%)	(4.30%)
Production and Investment Tax Credits	(24.10%)	(5.40%)	(22.50%)	(4.60%)
Flow Through	(1.30%)	(0.20%)	(0.80%)	(0.20%)
AFUDC Equity	(0.20%)	(0.50%)	(0.40%)	(0.60%)
Parent Company Loss Benefit		0.70%		0%
Discrete Tax Adjustments	0%	1.20%	0.30%	0.60%
Other	(0.20%)	(0.20%)	0%	(0.10%)
Effective Income Tax Rate	(14.70%)	5.50%	(8.70%)	8.40%

Financing Activities (Details)

Financing Activities (Details) - USD ($)		1 Months Ended	3 Months Ended								9 Months Ended
Financing Activities (Details) - USD ($)		Oct. 27, 2022	Sep. 30, 2022		Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2021		Jun. 30, 2021	Mar. 31, 2021	Sep. 30, 2022		Sep. 30, 2021		Dec. 31, 2021
Long-term Debt
Senior Unsecured Notes			$ 28,892,700,000								$ 28,892,700,000				$ 27,497,300,000
Pollution Control Bonds			1,804,900,000								1,804,900,000				1,804,500,000
Notes Payable			218,000,000								218,000,000				211,300,000
Securitization Bonds			524,800,000								524,800,000				603,500,000
Spent Nuclear Fuel Obligation	[1]		283,200,000								283,200,000				281,300,000
Junior Subordinated Notes	[2]		2,377,300,000								2,377,300,000				2,373,000,000
Other Long-term Debt			949,200,000								949,200,000				683,600,000
Total Long-term Debt Outstanding	[3]		35,050,100,000								35,050,100,000				33,454,500,000
Long-term Debt Due Within One Year	[4]		1,403,500,000								1,403,500,000				2,153,800,000
Long-term Debt	[5]		33,646,600,000								33,646,600,000				31,300,700,000
Liabilities Held for Sale			1,992,000,000								1,992,000,000				1,880,900,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[6]										3,457,200,000
Repayments of Long-term Debt											1,679,100,000		$ 1,549,800,000
Short-term Debt:
Securitized Debt for Receivables	[7]		750,000,000								750,000,000				750,000,000
Commercial Paper			1,952,300,000								1,952,300,000				1,364,000,000
Total Short-term Debt			$ 2,702,300,000								$ 2,702,300,000				$ 2,614,000,000
Securitized Debt for Receivables	[7],[8]		1.16%								1.16%				0.19%
Comparative Accounts Receivable Information
Effective Interest Rates on Securitization of Accounts Receivable			2.25%				0.18%				1.16%		0.19%
Net Uncollectible Accounts Receivable Written Off			$ 9,500,000				$ 7,500,000				$ 23,100,000		$ 22,600,000
Customer Accounts Receivable Managed Portfolio
Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts			1,172,500,000								1,172,500,000				$ 995,200,000
Total Principal Outstanding			750,000,000								750,000,000				750,000,000
Delinquent Securitized Accounts Receivable			57,400,000								57,400,000				57,900,000
Bad Debt Reserves Related to Securitization, Sale of Accounts Receivable			39,400,000								39,400,000				42,800,000
Unbilled Receivables Related to Securitization, Sale of Accounts Receivable			252,300,000								252,300,000				307,100,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			5,526,100,000				4,623,000,000				14,758,400,000		12,730,600,000
Financing Activities (Textuals)
Maximum Value of Shares to be Issued Under ATM Program											$ 1,000,000,000
Maximum Percentage Paid to Selling Agents											2%
Issuance of Common Stock											$ 827,200,000		548,000,000
Trust Fund Assets One Time Fee Obligation for Nuclear Fuel Disposition															329,000,000
Maximum Percentage Debt to Capitalization											67.50%
Total Commitment from Bank Conduits to Finance Receivables			750,000,000								$ 750,000,000
Forward Equity Purchase Contract Included in Current and Noncurrent Liabilities as of September 30,			(3,000,000)		$ (18,800,000)	$ 16,700,000	(7,800,000)		$ (10,500,000)	$ 19,100,000
Commitment from Bank Conduits to Finance Receivables			125,000,000								125,000,000
Commitment from Bank Conduits to Finance Receivables Two			625,000,000								625,000,000
Assets Held for Sale			2,830,600,000								2,830,600,000				$ 2,919,700,000
Issuance of Long-term Debt											3,428,400,000		5,062,300,000
Revenue from Related Parties			0				0				0		0
Wholesale Transmission [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			314,800,000	[9]			308,800,000	[10]			991,000,000	[11]	878,600,000	[12]
Wholesale Transmission [Member] \| AEP Transmission Holdco [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			424,900,000	[9]			375,800,000	[10]			1,261,000,000	[11]	1,092,100,000	[12]
Financing Activities (Textuals)
Revenue from Related Parties			342,000,000				286,000,000				$ 1,000,000,000		835,000,000
2020 Equity Units [Member]
Financing Activities (Textuals)
Equity Units Issued											17,000,000
Per Unit Conversion for Equity Units			$ 50								$ 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%								6.125%
Forward Equity Contract Payment Rate			4.825%								4.825%
Maximum Shares Issued Under Equity Units Conversion											10,205,100
Corporate unit ownership share of an equity unit			5%								5%
2019 Equity Units [Member]
Financing Activities (Textuals)
Stock Issued During Period, Shares, New Issues											8,970,920
Issuance of Common Stock											$ 805,000,000
Equity Units Issued											16,100,000
Per Unit Conversion for Equity Units			$ 50								$ 50
Net Equity Units Issuance Proceeds											785,000,000
Principal Amounts of Junior Subordinated Debt											$ 1,000
Forward Equity Purchase Contract Date											2022
Corporate unit ownership share of an equity unit			5%								5%
Kentucky Transmission Company
Financing Activities (Textuals)
Assets Held for Sale			$ 5,000,000								$ 5,000,000
Junior Subordinated Debt [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Interest Rate (Percentage)			2.031%								2.031%
Junior Subordinated Debt [Member] \| 2020 Equity Units [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt											$ 850,000,000
Interest Rate (Percentage)			1.30%								1.30%
Junior Subordinated Debt [Member] \| 2019 Equity Units [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt											$ 805,000,000
Interest Rate (Percentage)			3.40%								3.40%
Commercial Paper [Member]
Short-term Debt:
Weighted Average Interest Rate	[8]		3.38%								3.38%				0.34%
Term Loan [Member]
Short-term Debt:
Weighted Average Interest Rate	[8]		0%								0%				0.81%
Term Loan			$ 0								$ 0				$ 500,000,000
AEP Texas Inc. [Member]
Long-term Debt
Total Long-term Debt Outstanding			5,693,900,000								5,693,900,000				5,180,800,000
Long-term Debt Due Within One Year			277,500,000								277,500,000				716,000,000
Long-term Debt			5,416,400,000								5,416,400,000				4,464,800,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 678,600,000		52,200,000
Financing Activities (Textuals)
Maximum Percentage Debt to Capitalization											67.50%
Issuance of Long-term Debt											$ 1,188,700,000		444,200,000
Revenue from Related Parties			900,000				900,000				2,600,000		2,900,000
AEP Texas Inc. [Member] \| Wholesale Transmission [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			140,800,000	[13]			131,500,000	[14]			$ 417,700,000	[15]	$ 364,500,000	[16]
AEP Texas Inc. [Member] \| Utility [Member]
Maximum Interest Rate											3.39%		0.40%
Minimum Interest Rate											0.10%		0.02%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool											$ 348,800,000
Maximum Loans to Money Pool											652,300,000
Average Borrowings from Money Pool											208,100,000
Average Loans to Money Pool											319,800,000
Net Loans (Borrowings) to/from Money Pool			129,500,000								129,500,000
Authorized Short Term Borrowing Limit											$ 500,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed											0.90%		0.33%
Average Interest Rate For Funds Loaned											1.82%		0.27%
AEP Texas Inc. [Member] \| Nonutility [Member]
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Loans to Money Pool											$ 6,900,000
Average Loans to Money Pool											6,800,000
Net Loans (Borrowings) to/from Money Pool			$ 6,800,000								$ 6,800,000
Maximum and Minimum Interest Rates
Maximum Interest Rate For Funds Loaned											3.39%		0.41%
Minimum Interest Rate for Funds Loaned											0.46%		0.21%
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Loaned											1.51%		0.34%
AEP Texas Inc. [Member] \| Securitization Bonds [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 30,600,000
Due Date											2024
Interest Rate (Percentage)			2.85%								2.85%
AEP Texas Inc. [Member] \| Securitization Bonds Two [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 23,000,000
Due Date											2025
Interest Rate (Percentage)			2.06%								2.06%
AEP Texas Inc. [Member] \| Senior Unsecured Notes [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[6]										$ 500,000,000
Due Date											2052
Interest Rate (Percentage)			5.25%								5.25%
AEP Texas Inc. [Member] \| Senior Unsecured Notes Two [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[6]										$ 500,000,000
Due Date											2032
Interest Rate (Percentage)			4.70%								4.70%
AEP Texas Inc. [Member] \| OtherLongTermDebtThree
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[6]										$ 200,000,000
Due Date											2025
Interest Rate (Variable)											Variable
AEP Texas Inc. [Member] \| Other Long Term Debt Six
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 200,000,000
Due Date											2022
Interest Rate (Variable)											Variable
AEP Texas Inc. [Member] \| Senior Unsecured Notes Five
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 400,000,000
Due Date											2022
Interest Rate (Percentage)			2.40%								2.40%
AEP Texas Inc. [Member] \| Senior Unsecured Notes Six
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 25,000,000
Due Date											2022
Interest Rate (Percentage)			3.27%								3.27%
AEP Transmission Co [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 4,886,600,000								$ 4,886,600,000				4,343,900,000
Long-term Debt Due Within One Year			104,000,000								104,000,000				104,000,000
Long-term Debt			4,782,600,000								4,782,600,000				4,239,900,000
Liabilities Held for Sale			27,600,000								27,600,000				27,600,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold													$ 300,000
Financing Activities (Textuals)
Sub-Limit of Secured Debt			$ 50,000,000								$ 50,000,000
Maximum Percentage of Consolidated Tangible Net Assets			10%								10%
Tangible Capital to Tangible Assets			0.50%								0.50%
Maximum Percentage Debt to Capitalization											67.50%
Assets Held for Sale			$ 173,700,000								$ 173,700,000				167,900,000
Issuance of Long-term Debt											540,900,000		443,700,000
Revenue from Related Parties			340,600,000				297,700,000				999,500,000		882,300,000
AEP Transmission Co [Member] \| Wholesale Transmission [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			411,700,000	[13]			360,100,000	[14]			1,218,100,000	[15]	1,045,200,000	[16]
Financing Activities (Textuals)
Revenue from Related Parties			339,000,000				281,000,000				$ 992,000,000		$ 823,000,000
AEP Transmission Co [Member] \| Utility [Member]
Maximum Interest Rate											3.39%		0.40%
Minimum Interest Rate											0.10%		0.02%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool											$ 480,200,000
Maximum Loans to Money Pool											137,000,000
Average Borrowings from Money Pool											197,400,000
Average Loans to Money Pool											31,300,000
Net Loans (Borrowings) to/from Money Pool	[17]		78,700,000								78,700,000
Authorized Short Term Borrowing Limit	[18]										$ 820,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed											1.03%		0.32%
Average Interest Rate For Funds Loaned											2.14%		0.07%
AEP Transmission Co [Member] \| Direct Borrowing [Member]
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool											$ 52,400,000
Maximum Loans to Money Pool											141,800,000
Average Borrowings from Money Pool											7,100,000
Average Loans to Money Pool											59,600,000
Borrowings from Parent			33,000,000								33,000,000
Loans to Parent			$ 0								0
Authorized Short Term Borrowing Limit	[19]										$ 50,000,000
Maximum and Minimum Interest Rates
Maximum Interest Rate for Funds Borrowed											3.39%		0.86%
Minimum Interest Rate For Funds Borrowed											0.46%		0.25%
Maximum Interest Rate For Funds Loaned											3.37%		0.86%
Minimum Interest Rate for Funds Loaned											0.46%		0.25%
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed											1.56%		0.35%
Average Interest Rate For Funds Loaned											1.38%		0.34%
AEP Transmission Co [Member] \| Senior Unsecured Notes Three
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[6]										$ 550,000,000
Due Date											2052
Interest Rate (Percentage)			4.50%								4.50%
AEP Transmission Co [Member] \| Senior Unsecured Notes Nine \| Subsequent Event [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt		$ 104,000,000
Appalachian Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 5,509,800,000								$ 5,509,800,000				4,938,900,000
Long-term Debt Due Within One Year			351,800,000								351,800,000				480,700,000
Long-term Debt			5,158,000,000								5,158,000,000				4,458,200,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											130,400,000		$ 393,000,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues			127,500,000								127,500,000				153,100,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit			360,400,000				342,200,000				$ 1,114,900,000		980,600,000
Financing Activities (Textuals)
Maximum Percentage Debt to Capitalization											67.50%
Issuance of Long-term Debt											$ 698,200,000		494,000,000
Revenue from Related Parties			67,600,000				52,400,000				187,600,000		140,600,000
Appalachian Power Co [Member] \| Wholesale Transmission [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			41,500,000	[13]			35,200,000	[14]			123,400,000	[15]	94,100,000	[16]
Appalachian Power Co [Member] \| Servicing Contracts [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			2,800,000				1,300,000	[20]			$ 5,600,000		$ 3,700,000	[20]
Appalachian Power Co [Member] \| Utility [Member]
Maximum Interest Rate											3.39%		0.40%
Minimum Interest Rate											0.10%		0.02%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool											$ 438,400,000
Maximum Loans to Money Pool											214,200,000
Average Borrowings from Money Pool											180,900,000
Average Loans to Money Pool											52,800,000
Net Loans (Borrowings) to/from Money Pool			$ 182,100,000								182,100,000
Authorized Short Term Borrowing Limit											$ 500,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed											1.39%		0.28%
Average Interest Rate For Funds Loaned											2.13%		0.28%
Appalachian Power Co [Member] \| Pollution Control Bond [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[6]										$ 104,400,000
Due Date											2025
Interest Rate (Percentage)			3.75%								3.75%
Appalachian Power Co [Member] \| Securitization Bonds Three
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 25,900,000
Due Date											2023
Interest Rate (Percentage)			2.01%								2.01%
Appalachian Power Co [Member] \| Other Long Term Debt Seven
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 100,000
Due Date											2026
Interest Rate (Percentage)			13.72%								13.72%
Appalachian Power Co [Member] \| Other Long Term Debt Ten
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[6]										$ 100,000,000
Due Date											2023
Interest Rate (Variable)											Variable
Appalachian Power Co [Member] \| Pollution Control Bond Five
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 104,400,000
Due Date											2022
Interest Rate (Percentage)			2.63%								2.63%
Appalachian Power Co [Member] \| Senior Unsecured Notes Four
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[6]										$ 500,000,000
Due Date											2032
Interest Rate (Percentage)			4.50%								4.50%
Appalachian Power Co [Member] \| Pollution Control Bond Seven \| Subsequent Event [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt		100,000,000
Indiana Michigan Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 3,206,700,000								$ 3,206,700,000				3,195,000,000
Long-term Debt Due Within One Year			320,900,000								320,900,000				67,000,000
Long-term Debt			2,885,800,000								2,885,800,000				3,128,000,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											64,500,000		$ 307,200,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues			187,800,000								187,800,000				156,900,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit			558,500,000				536,800,000				1,574,300,000		1,478,900,000
Financing Activities (Textuals)
Trust Fund Assets One Time Fee Obligation for Nuclear Fuel Disposition			326,000,000								$ 326,000,000				329,000,000
Maximum Percentage Debt to Capitalization											67.50%
Issuance of Long-term Debt											$ 72,800,000		507,000,000
Revenue from Related Parties			2,000,000				1,100,000				11,100,000		2,600,000
Indiana Michigan Power Co [Member] \| Wholesale Transmission [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			8,800,000	[13]			8,700,000	[14]			26,300,000	[15]	25,300,000	[16]
Indiana Michigan Power Co [Member] \| Servicing Contracts [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			2,800,000				2,100,000	[20]			$ 6,500,000		$ 5,300,000	[20]
Indiana Michigan Power Co [Member] \| Utility [Member]
Maximum Interest Rate											3.39%		0.40%
Minimum Interest Rate											0.10%		0.02%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool											$ 159,100,000
Maximum Loans to Money Pool											22,600,000
Average Borrowings from Money Pool											86,000,000
Average Loans to Money Pool											22,100,000
Net Loans (Borrowings) to/from Money Pool			$ (82,300,000)								(82,300,000)
Authorized Short Term Borrowing Limit											$ 500,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed											1.38%		0.32%
Average Interest Rate For Funds Loaned											1.46%		0.25%
Indiana Michigan Power Co [Member] \| Notes Payable, Other Payable Four [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 1,300,000
Due Date											2022
Interest Rate (Variable)											Variable
Indiana Michigan Power Co [Member] \| Notes Payable, Other Payable Five [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 3,400,000
Due Date											2022
Interest Rate (Variable)											Variable
Indiana Michigan Power Co [Member] \| Notes Payable, Other Payable Six [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 6,700,000
Due Date											2023
Interest Rate (Variable)											Variable
Indiana Michigan Power Co [Member] \| Notes Payable, Other Payable Seven [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 13,700,000
Due Date											2025
Interest Rate (Variable)											Variable
Indiana Michigan Power Co [Member] \| Notes Payable, Other Payable Eight [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 18,900,000
Due Date											2025
Interest Rate (Percentage)			0.93%								0.93%
Indiana Michigan Power Co [Member] \| Notes Payable, Other Payable Nine
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 8,000,000
Due Date											2026
Interest Rate (Percentage)			3.44%								3.44%
Indiana Michigan Power Co [Member] \| Notes Payable, Other Payable
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[6]										$ 72,800,000
Due Date											2026
Interest Rate (Percentage)			3.44%								3.44%
Indiana Michigan Power Co [Member] \| Notes Payable, Other Payable Ten \| Subsequent Event [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt		7,000,000
Indiana Michigan Power Co [Member] \| Notes Payable, Other Payable Two [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 10,800,000
Due Date											2024
Interest Rate (Variable)											Variable
Indiana Michigan Power Co [Member] \| Other Long Term Debt Eight
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 1,700,000
Due Date											2025
Interest Rate (Percentage)			6%								6%
Ohio Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 2,969,900,000								$ 2,969,900,000				2,968,500,000
Long-term Debt Due Within One Year			100,000								100,000				100,000
Long-term Debt			2,969,800,000								2,969,800,000				2,968,400,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											100,000		$ 100,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues			476,700,000								476,700,000				392,700,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit			874,100,000				668,400,000				2,284,000,000		1,867,500,000
Financing Activities (Textuals)
Issuance of Long-term Debt											0		1,037,500,000
Revenue from Related Parties			4,000,000				4,300,000				11,600,000		21,900,000
Ohio Power Co [Member] \| Wholesale Transmission [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			21,500,000	[13]			19,100,000	[14]			64,400,000	[15]	56,200,000	[16]
Ohio Power Co [Member] \| Servicing Contracts [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			7,300,000				4,600,000	[20]			$ 22,200,000		$ 3,500,000	[20]
Ohio Power Co [Member] \| Utility [Member]
Maximum Interest Rate											3.39%		0.40%
Minimum Interest Rate											0.10%		0.02%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool											$ 147,200,000
Maximum Loans to Money Pool											246,100,000
Average Borrowings from Money Pool											59,900,000
Average Loans to Money Pool											86,900,000
Net Loans (Borrowings) to/from Money Pool			$ (68,800,000)								(68,800,000)
Authorized Short Term Borrowing Limit											$ 500,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed											1.81%		0.27%
Average Interest Rate For Funds Loaned											1.22%		0.15%
Ohio Power Co [Member] \| Other Long Term Debt Nine
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 100,000
Due Date											2028
Interest Rate (Percentage)			1.15%								1.15%
Public Service Co Of Oklahoma [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 1,913,600,000								$ 1,913,600,000				1,913,500,000
Long-term Debt Due Within One Year			500,000								500,000				125,500,000
Long-term Debt			1,913,100,000								1,913,100,000				1,788,000,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											500,400,000		$ 750,400,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues			188,400,000								188,400,000				114,500,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit			588,500,000				460,100,000				$ 1,380,400,000		1,068,800,000
Financing Activities (Textuals)
Maximum Percentage Debt to Capitalization											67.50%
Issuance of Long-term Debt											$ 499,700,000		1,290,000,000
Revenue from Related Parties			700,000				1,000,000				2,100,000		3,100,000
Public Service Co Of Oklahoma [Member] \| Wholesale Transmission [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			10,200,000	[13]			10,600,000	[14]			28,900,000	[15]	28,800,000	[16]
Public Service Co Of Oklahoma [Member] \| Servicing Contracts [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			2,400,000				1,100,000	[20]			$ 4,600,000		$ 2,400,000	[20]
Public Service Co Of Oklahoma [Member] \| Utility [Member]
Maximum Interest Rate											3.39%		0.40%
Minimum Interest Rate											0.10%		0.02%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool											$ 338,300,000
Maximum Loans to Money Pool											432,500,000
Average Borrowings from Money Pool											200,900,000
Average Loans to Money Pool											402,800,000
Net Loans (Borrowings) to/from Money Pool			$ (223,500,000)								(223,500,000)
Authorized Short Term Borrowing Limit											$ 400,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed											1.70%		0.34%
Average Interest Rate For Funds Loaned											0.75%		0.06%
Public Service Co Of Oklahoma [Member] \| Other Long Term Debt [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[6]										$ 500,000,000
Due Date											2022
Interest Rate (Variable)											Variable
Public Service Co Of Oklahoma [Member] \| Other Long Term Debt Eleven
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 500,000,000
Due Date											2022
Interest Rate (Variable)											Variable
Public Service Co Of Oklahoma [Member] \| Other Long Term Debt Twelve
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 400,000
Due Date											2027
Interest Rate (Percentage)			3%								3%
Southwestern Electric Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 3,392,400,000								$ 3,392,400,000				3,395,200,000
Long-term Debt Due Within One Year			6,200,000								6,200,000				6,200,000
Long-term Debt			3,386,200,000								3,386,200,000				3,389,000,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											4,700,000		$ 4,700,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues			217,000,000								217,000,000				153,000,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit			593,600,000				488,500,000				$ 1,425,300,000		1,265,500,000
Financing Activities (Textuals)
Maximum Percentage Debt to Capitalization											67.50%
Issuance of Long-term Debt											$ 0		496,400,000
Revenue from Related Parties			18,200,000				13,500,000				43,700,000		32,200,000
Southwestern Electric Power Co [Member] \| Wholesale Transmission [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			42,300,000	[13]			37,100,000	[14]			116,800,000	[15]	94,500,000	[16]
Southwestern Electric Power Co [Member] \| Servicing Contracts [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			3,200,000				1,300,000	[20]			$ 6,000,000		$ 4,100,000	[20]
Southwestern Electric Power Co [Member] \| Utility [Member]
Maximum Interest Rate											3.39%		0.40%
Minimum Interest Rate											0.10%		0.02%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool											$ 261,600,000
Maximum Loans to Money Pool											156,600,000
Average Borrowings from Money Pool											191,000,000
Average Loans to Money Pool											109,700,000
Net Loans (Borrowings) to/from Money Pool			(156,300,000)								(156,300,000)
Authorized Short Term Borrowing Limit											$ 400,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed											1.67%		0.28%
Average Interest Rate For Funds Loaned											0.55%		0.38%
Southwestern Electric Power Co [Member] \| Nonutility [Member]
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Loans to Money Pool											$ 2,100,000
Average Loans to Money Pool											2,100,000
Net Loans (Borrowings) to/from Money Pool			$ 2,100,000								$ 2,100,000
Maximum and Minimum Interest Rates
Maximum Interest Rate For Funds Loaned											3.39%		0.41%
Minimum Interest Rate for Funds Loaned											0.46%		0.21%
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Loaned											1.52%		0.34%
Southwestern Electric Power Co [Member] \| Other Long Term Debt Thirteen
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 1,500,000
Due Date											2028
Interest Rate (Percentage)			4.68%								4.68%
Southwestern Electric Power Co [Member] \| Notes Payable, Other Payable Three [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 3,200,000
Due Date											2032
Interest Rate (Percentage)			4.58%								4.58%
Transource Energy [Member] \| Other Long Term Debt Five
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[6]										$ 5,000,000
Due Date											2023
Interest Rate (Variable)											Variable
Transource Energy [Member] \| Senior Unsecured Notes Seven
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 2,400,000
Due Date											2050
Interest Rate (Percentage)			2.75%								2.75%
Transource Energy [Member] \| Other Long Term Debt Fifteen \| Subsequent Event [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt		64,000,000
Transource Energy [Member] \| Other Long Term Debt Sixteen \| Subsequent Event [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt		64,000,000
Kentucky Power Co [Member] \| Total Long-Term Debt Due Within One Year
Long-term Debt
Liabilities Held for Sale			$ 215,000,000								$ 215,000,000				200,000,000
Kentucky Power Co [Member] \| Total Long-Term Debt
Long-term Debt
Liabilities Held for Sale			$ 963,000,000								963,000,000				$ 903,000,000
Kentucky Power Co [Member] \| OtherLongTermDebtFour
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[6]										$ 150,000,000
Due Date											2023
Interest Rate (Variable)											Variable
Kentucky Power Co [Member] \| Other Long Term Debt Fourteen
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 75,000,000
Due Date											2022
Interest Rate (Variable)											Variable
Wheeling Power Company \| Other Long Term Debt Two [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[6]										$ 165,000,000
Due Date											2024
Interest Rate (Variable)											Variable
Wheeling Power Company \| Pollution Control Bond Three
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[6]										$ 65,000,000
Due Date											2027
Interest Rate (Percentage)			3%								3%
Wheeling Power Company \| Pollution Control Bond Six
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 65,000,000
Due Date											2022
Interest Rate (Percentage)			3%								3%
Wheeling Power Company \| Senior Unsecured Notes Eight
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 113,000,000
Due Date											2022
Interest Rate (Percentage)			3.36%								3.36%
AEP Generating Company \| Pollution Control Bond Two [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[6]										$ 45,000,000
Due Date											2025
Interest Rate (Percentage)			3.13%								3.13%
AEP Generating Company \| Pollution Control Bond Four
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 45,000,000
Due Date											2022
Interest Rate (Percentage)			1.35%								1.35%
AEP Generating Company \| Other Long Term Debt Seventeen \| Subsequent Event [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt		120,000,000
AEP Generating Company \| Other Long Term Debt Eighteen \| Subsequent Event [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt		$ 80,000,000
Maximum [Member] \| 2020 Equity Units [Member]
Financing Activities (Textuals)
AEP Share Price for Equity Unit Conversion			$ 99.95								$ 99.95
Shares Per Equity Unit			0.5003								0.5003
Minimum [Member] \| 2020 Equity Units [Member]
Financing Activities (Textuals)
AEP Share Price for Equity Unit Conversion			$ 83.29								$ 83.29
Shares Per Equity Unit			0.6003								0.6003
Additional Paid-in Capital [Member]
Financing Activities (Textuals)
Forward Equity Purchase Contract Included in Current and Noncurrent Liabilities as of September 30,			$ (3,000,000)		$ (17,200,000)	$ 15,200,000	$ (6,300,000)		$ 200,000	$ 21,900,000
Additional Paid-in Capital [Member] \| 2020 Equity Units [Member]
Financing Activities (Textuals)
Forward Equity Purchase Contract Included in Current and Noncurrent Liabilities as of September 30,											$ 121,000,000

[1]Pursuant to the Nuclear Waste Policy Act of 1982, I&M, a nuclear licensee, has an obligation to the United States Department of Energy for SNF disposal. The obligation includes a one-time fee for nuclear fuel consumed prior to April 7, 1983. Trust fund assets related to this obligation were $326 million and $329 million as of September 30, 2022 and December 31, 2021, respectively, and are included in Spent Nuclear Fuel and Decommissioning Trusts on the balance sheets.[2]See “Equity Units” section below for additional information.[3]The book value amounts exclude Long-term Debt of $1.2 billion and $1.1 billion as of September 30, 2022 and December 31, 2021, respectively, classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.[4]Amount excludes $215 million and $200 million as of September 30, 2022 and December 31, 2021, respectively, of Long-term Debt Due Within One Year classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.[5]Amount excludes $963 million and $903 million as of September 30, 2022 and December 31, 2021, respectively, of Long-term Debt classified as Liabilities Held for Sale on the balance sheet. See “Disposition of KPCo and KTCo” section of Note 6 for additional information.[6]Amounts indicated on the statements of cash flows are net of issuance costs and premium or discount and will not tie to the issuance amounts.[7]Amount of securitized debt for receivables as accounted for under the “Transfers and Servicing” accounting guidance.[8]Weighted-average rate.[9]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $342 million. The remaining affiliated amounts were immaterial.[10]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $286 million. The remaining affiliated amounts were immaterial.[11]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $1 billion. The affiliated revenue for Vertically Integrated Utilities was $120 million. The remaining affiliated amounts were immaterial.[12] (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $835 million. The remaining affiliated amounts were immaterial.

Property, Plant and Equipment_3

Property, Plant and Equipment (Details) - USD ($) $ in Millions		9 Months Ended
		Sep. 30, 2022	Dec. 31, 2021
Asset Retirement Obligations (ARO)
Beginning Balance	[1],[2],[3],[4],[5]	$ 2,741.7
Accretion Expense	[1],[2],[3],[4],[5]	82.1
Liabilities Incurred	[1],[2],[3],[4],[5]	37.4
Liabilities Settled	[1],[2],[3],[4],[5]	(29.4)
Asset Retirement Obligation, Revision of Estimate	[1],[2],[3],[4],[5]	90.9
Ending Balance	[1],[2],[3],[4],[5]	2,922.7
Indiana Michigan Power Co [Member]
Property, Plant and Equipment (Textuals)
Asset Retirement Obligations (ARO) Liability for Nuclear Decommissioning of the Cook Plant		1,980	$ 1,930
Public Service Co Of Oklahoma [Member]
Asset Retirement Obligations (ARO)
Beginning Balance	[3],[4]	57.6
Accretion Expense	[3],[4]	3
Liabilities Incurred	[3],[4]	12.8
Liabilities Settled	[3],[4]	(0.6)
Asset Retirement Obligation, Revision of Estimate	[3],[4]	1.9
Ending Balance	[3],[4]	74.7
Public Service Co Of Oklahoma [Member] \| ARO Additional Liability Incurred [Member]
Asset Retirement Obligations (ARO)
Liabilities Incurred		13
Southwestern Electric Power Co [Member]
Asset Retirement Obligations (ARO)
Beginning Balance	[2],[3],[4]	222.7
Accretion Expense	[2],[3],[4]	8.3
Liabilities Incurred	[2],[3],[4]	15.4
Liabilities Settled	[2],[3],[4]	(16.9)
Asset Retirement Obligation, Revision of Estimate	[2],[3],[4]	48
Ending Balance	[2],[3],[4]	277.5
Southwestern Electric Power Co [Member] \| Ash Pond Closure Revision [Member]
Asset Retirement Obligations (ARO)
Asset Retirement Obligation, Revision of Estimate		13
Southwestern Electric Power Co [Member] \| ARO Additional Liability Incurred [Member]
Asset Retirement Obligations (ARO)
Liabilities Incurred		15
Southwestern Electric Power Co [Member] \| Reclamation Cost Revision [Member]
Asset Retirement Obligations (ARO)
Asset Retirement Obligation, Revision of Estimate		16
Southwestern Electric Power Co [Member] \| Landfille Closure Revision [Member]
Asset Retirement Obligations (ARO)
Asset Retirement Obligation, Revision of Estimate		14
Kentucky Power Co [Member]
Asset Retirement Obligations (ARO)
Liabilities Held for Sale		$ 18	$ 18

[1]Includes $18 million and $18 million as of September 30, 2022 and December 31, 2021, respectively, of ARO classified as Liabilities Held for Sale on the balance sheets. See “Disposition of KPCo and KTCo” section of Note 6 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 $1.98 billion and $1.93 billion as of September 30, 2022 and December 31, 2021, respectively.

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Details) - USD ($)		3 Months Ended				9 Months Ended
Revenue from Contracts with Customers (Details) - USD ($)		Sep. 30, 2022		Sep. 30, 2021		Sep. 30, 2022		Sep. 30, 2021		Dec. 31, 2021
Disaggregation of Revenue
Revenue from Contracts with Customers		$ 5,526,100,000		$ 4,623,000,000		$ 14,758,400,000		$ 12,730,600,000
Revenues		5,526,100,000		4,623,000,000		14,758,400,000		12,730,600,000
Revenue, Performance Obligation
Fixed Performance Obligations		745,500,000				745,500,000
Revenue Textuals
Revenue from Related Parties		0		0		0		0
Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		4,037,000,000		3,360,800,000		10,773,300,000		9,147,600,000
Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,019,900,000		1,742,300,000		5,312,200,000		4,657,400,000
Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,098,100,000		898,800,000		2,917,200,000		2,446,100,000
Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		849,700,000		661,100,000		2,349,900,000		1,885,800,000
Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		69,300,000		58,600,000		194,000,000		158,300,000
Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,224,700,000		1,008,000,000		3,247,000,000		3,097,800,000
Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		382,800,000		281,600,000		881,700,000	[1]	876,500,000
Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		314,800,000	[2]	308,800,000	[3]	991,000,000	[4]	878,600,000	[5]
Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		41,800,000	[6]	23,500,000	[7]	98,700,000	[1]	65,000,000	[8]
Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		485,300,000		394,100,000	[9]	1,275,600,000	[10]	1,277,700,000	[11]
Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		138,000,000	[12]	93,500,000	[7]	373,800,000	[13]	261,000,000	[8]
Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		5,399,700,000		4,462,300,000		14,394,100,000		12,506,400,000
Alternative and Other [Member]
Disaggregation of Revenue
Revenues		126,400,000		160,700,000		364,300,000		224,200,000
Alternative [Member]
Disaggregation of Revenue
Revenues		(1,900,000)	[6]	5,900,000	[7]	(65,100,000)	[1]	35,500,000	[8]
Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		92,900,000		93,800,000		280,500,000		276,200,000
Revenues		128,300,000	[6]	154,800,000	[7],[14]	429,400,000	[1],[15]	188,700,000	[8],[16]
2022 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		318,700,000				318,700,000
2023-2024 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		172,100,000				172,100,000
2025-2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		157,800,000				157,800,000
After 2026
Revenue, Performance Obligation
Fixed Performance Obligations		96,900,000				96,900,000
AEP Texas Inc. [Member]
Disaggregation of Revenue
Revenues		508,900,000		432,600,000		1,404,400,000		1,195,300,000
Revenue, Performance Obligation
Fixed Performance Obligations		145,800,000				145,800,000
Affiliated Companies - Contracts with Customers		5,900,000				5,900,000				$ 7,900,000
Revenue Textuals
Revenue from Related Parties		900,000		900,000		2,600,000		2,900,000
AEP Texas Inc. [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		358,000,000		295,200,000		965,200,000		793,600,000
AEP Texas Inc. [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		204,000,000		172,500,000		520,800,000		423,700,000
AEP Texas Inc. [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		107,100,000		89,100,000		312,600,000		265,200,000
AEP Texas Inc. [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		35,400,000		25,400,000		102,600,000	[17]	81,600,000
AEP Texas Inc. [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		11,500,000		8,200,000		29,200,000		23,100,000
AEP Texas Inc. [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		140,800,000		131,500,000		417,700,000		364,500,000
AEP Texas Inc. [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[18]	0	[19]	0	[20]	0	[21]
AEP Texas Inc. [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		140,800,000	[22]	131,500,000	[23]	417,700,000	[24]	364,500,000	[25]
AEP Texas Inc. [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		9,500,000	[26]	6,800,000	[27]	24,400,000	[28]	35,400,000	[29]
AEP Texas Inc. [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		508,300,000		433,500,000		1,407,300,000		1,193,500,000
AEP Texas Inc. [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		600,000		(900,000)		(2,900,000)		1,800,000
AEP Texas Inc. [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		600,000	[30]	(900,000)	[31]	(2,900,000)	[17]	1,800,000	[32]
AEP Texas Inc. [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		300,000		900,000		2,500,000		3,300,000
Revenues		0	[30]	0	[31]	0	[17]	0	[32]
AEP Texas Inc. [Member] \| Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		0				0				400,000
AEP Texas Inc. [Member] \| 2022 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		145,800,000				145,800,000
AEP Texas Inc. [Member] \| 2023-2024 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
AEP Texas Inc. [Member] \| 2025-2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
AEP Texas Inc. [Member] \| After 2026
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
AEP Transmission Co [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers								300,000
Revenues		418,500,000		377,000,000		1,183,300,000		1,104,200,000
Revenue, Performance Obligation
Fixed Performance Obligations		369,400,000				369,400,000
Affiliated Companies - Contracts with Customers		111,000,000				111,000,000				96,100,000
Revenue Textuals
Revenue from Related Parties		340,600,000		297,700,000		999,500,000		882,300,000
AEP Transmission Co [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
AEP Transmission Co [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
AEP Transmission Co [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
AEP Transmission Co [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0	[17]	0
AEP Transmission Co [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
AEP Transmission Co [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		411,700,000		360,100,000		1,218,100,000		1,045,200,000
AEP Transmission Co [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[18]	0	[19]	0	[20]	0	[21]
AEP Transmission Co [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		411,700,000	[22]	360,100,000	[23]	1,218,100,000	[24]	1,045,200,000	[25]
Revenue Textuals
Revenue from Related Parties		339,000,000		281,000,000		992,000,000		823,000,000
AEP Transmission Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(300,000)	[26]	5,000,000	[27]	(400,000)	[28]	12,500,000	[29]
AEP Transmission Co [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		411,400,000		365,100,000		1,217,700,000		1,057,700,000
AEP Transmission Co [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		7,100,000		11,900,000		(34,400,000)		46,500,000
AEP Transmission Co [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		7,100,000	[30]	11,900,000	[31]	(34,400,000)	[17]	46,500,000	[32]
AEP Transmission Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		200,000		0		300,000
Revenues		0	[30]	0	[31]	0	[17]	0	[32]
AEP Transmission Co [Member] \| Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		110,600,000				110,600,000				95,500,000
AEP Transmission Co [Member] \| 2022 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		369,400,000				369,400,000
AEP Transmission Co [Member] \| 2023-2024 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
AEP Transmission Co [Member] \| 2025-2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
AEP Transmission Co [Member] \| After 2026
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
Appalachian Power Co [Member]
Disaggregation of Revenue
Revenues		888,900,000		804,000,000		2,569,800,000		2,298,000,000
Revenue, Performance Obligation
Fixed Performance Obligations		121,900,000				121,900,000
Affiliated Companies - Contracts with Customers		92,600,000				92,600,000				129,900,000
Revenue Textuals
Revenue from Related Parties		67,600,000		52,400,000		187,600,000		140,600,000
Appalachian Power Co [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		705,500,000		660,400,000		2,139,700,000		1,919,600,000
Appalachian Power Co [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		360,500,000		340,100,000		1,131,700,000		1,025,000,000
Appalachian Power Co [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		161,100,000		146,900,000		467,600,000		409,500,000
Appalachian Power Co [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		163,300,000		154,800,000		479,000,000	[17]	433,400,000
Appalachian Power Co [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		20,600,000		18,600,000		61,400,000		51,700,000
Appalachian Power Co [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		149,400,000		118,900,000		351,000,000		325,300,000
Appalachian Power Co [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		107,900,000	[18]	83,700,000	[19]	227,600,000	[20]	231,200,000	[21]
Revenue Textuals
Revenue from Related Parties		44,000,000		30,000,000		122,000,000		90,000,000
Appalachian Power Co [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		41,500,000	[22]	35,200,000	[23]	123,400,000	[24]	94,100,000	[25]
Appalachian Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		33,700,000	[26]	22,500,000	[27]	78,600,000	[28]	43,600,000	[29]
Appalachian Power Co [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		888,600,000		801,800,000		2,569,300,000		2,288,500,000
Appalachian Power Co [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		300,000		2,200,000		500,000		9,500,000
Appalachian Power Co [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		0	[30]	2,200,000	[31]	100,000	[17]	9,500,000	[32]
Appalachian Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,900,000		3,100,000		11,800,000		8,200,000
Revenues		300,000	[30]	0	[31]	400,000	[17]	0	[32]
Appalachian Power Co [Member] \| Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		65,800,000				65,800,000				117,800,000
Appalachian Power Co [Member] \| 2022 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		50,100,000				50,100,000
Appalachian Power Co [Member] \| 2023-2024 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		33,700,000				33,700,000
Appalachian Power Co [Member] \| 2025-2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		26,600,000				26,600,000
Appalachian Power Co [Member] \| After 2026
Revenue, Performance Obligation
Fixed Performance Obligations		11,500,000				11,500,000
Indiana Michigan Power Co [Member]
Disaggregation of Revenue
Revenues		715,400,000		635,700,000		1,971,600,000		1,784,000,000
Revenue, Performance Obligation
Fixed Performance Obligations		37,000,000				37,000,000
Affiliated Companies - Contracts with Customers		72,700,000				72,700,000				78,200,000
Revenue Textuals
Revenue from Related Parties		2,000,000		1,100,000		11,100,000		2,600,000
Indiana Michigan Power Co [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		549,700,000		523,700,000		1,540,900,000		1,431,700,000
Indiana Michigan Power Co [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		238,600,000		231,700,000		665,600,000		624,400,000
Indiana Michigan Power Co [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		154,300,000		143,900,000		419,500,000		384,500,000
Indiana Michigan Power Co [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		155,600,000		146,800,000		452,100,000	[17]	418,900,000
Indiana Michigan Power Co [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,200,000		1,300,000		3,700,000		3,900,000
Indiana Michigan Power Co [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		135,100,000		88,900,000		337,200,000		273,400,000
Indiana Michigan Power Co [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		126,300,000	[18]	80,200,000	[19]	310,900,000	[20]	248,100,000	[21]
Indiana Michigan Power Co [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		8,800,000	[22]	8,700,000	[23]	26,300,000	[24]	25,300,000	[25]
Indiana Michigan Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		30,600,000	[26]	24,200,000	[27]	86,300,000	[28]	81,900,000	[29]
Indiana Michigan Power Co [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		715,400,000		636,800,000		1,964,400,000		1,787,000,000
Indiana Michigan Power Co [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		0		(1,100,000)		7,200,000		(3,000,000)
Indiana Michigan Power Co [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		0	[30]	(1,100,000)	[31]	7,300,000	[17]	(3,000,000)	[32]
Indiana Michigan Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		4,400,000		1,700,000		10,000,000		5,100,000
Revenues		0	[30]	0	[31]	(100,000)	[17]	0	[32]
Revenue Textuals
Revenue from Related Parties		15,000,000		17,000,000		44,000,000		46,000,000
Indiana Michigan Power Co [Member] \| Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		51,100,000				51,100,000				61,200,000
Indiana Michigan Power Co [Member] \| 2022 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		9,700,000				9,700,000
Indiana Michigan Power Co [Member] \| 2023-2024 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		13,600,000				13,600,000
Indiana Michigan Power Co [Member] \| 2025-2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		9,200,000				9,200,000
Indiana Michigan Power Co [Member] \| After 2026
Revenue, Performance Obligation
Fixed Performance Obligations		4,500,000				4,500,000
Ohio Power Co [Member]
Disaggregation of Revenue
Revenues		1,021,300,000		767,700,000		2,674,200,000		2,196,500,000
Revenue, Performance Obligation
Fixed Performance Obligations		22,600,000				22,600,000
Affiliated Companies - Contracts with Customers		105,900,000				105,900,000				71,800,000
Revenue Textuals
Revenue from Related Parties		4,000,000		4,300,000		11,600,000		21,900,000
Ohio Power Co [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		943,600,000		689,100,000		2,440,200,000		1,968,000,000
Ohio Power Co [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		517,900,000		425,400,000		1,363,300,000		1,217,500,000
Ohio Power Co [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		266,100,000		190,800,000		681,900,000		538,900,000
Ohio Power Co [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		156,100,000		69,800,000		384,800,000	[17]	202,200,000
Ohio Power Co [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		3,500,000		3,100,000		10,200,000		9,400,000
Ohio Power Co [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		21,500,000		19,100,000		64,400,000		56,200,000
Ohio Power Co [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[18]	0	[19]	0	[20]	0	[21]
Ohio Power Co [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		21,500,000	[22]	19,100,000	[23]	64,400,000	[24]	56,200,000	[25]
Ohio Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		64,800,000	[26]	47,300,000	[27]	169,600,000	[28]	113,800,000	[29]
Ohio Power Co [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,029,900,000		755,500,000		2,674,200,000		2,138,000,000
Ohio Power Co [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(8,600,000)		12,200,000		0		58,500,000
Ohio Power Co [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		(14,100,000)	[30]	7,300,000	[31]	(18,600,000)	[17]	44,300,000	[32]
Ohio Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,100,000		2,400,000		6,000,000		6,800,000
Revenues		5,500,000	[30]	4,900,000	[31]	18,600,000	[17]	14,200,000	[32]
Ohio Power Co [Member] \| Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		61,500,000				61,500,000				51,700,000
Ohio Power Co [Member] \| 2022 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		19,200,000				19,200,000
Ohio Power Co [Member] \| 2023-2024 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		3,400,000				3,400,000
Ohio Power Co [Member] \| 2025-2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
Ohio Power Co [Member] \| After 2026
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
Public Service Co Of Oklahoma [Member]
Disaggregation of Revenue
Revenues		608,200,000		483,800,000		1,438,700,000		1,124,400,000
Revenue, Performance Obligation
Fixed Performance Obligations		3,400,000				3,400,000
Affiliated Companies - Contracts with Customers		93,500,000				93,500,000				35,000,000
Revenue Textuals
Revenue from Related Parties		700,000		1,000,000		2,100,000		3,100,000
Public Service Co Of Oklahoma [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		582,000,000		458,200,000		1,369,900,000		1,063,500,000
Public Service Co Of Oklahoma [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		299,600,000		236,800,000		650,700,000		516,400,000
Public Service Co Of Oklahoma [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		153,400,000		120,900,000		372,100,000		286,800,000
Public Service Co Of Oklahoma [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		98,900,000		77,100,000		270,000,000	[17]	202,100,000
Public Service Co Of Oklahoma [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		30,100,000		23,400,000		77,100,000		58,200,000
Public Service Co Of Oklahoma [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		19,600,000		17,800,000		48,100,000		35,600,000
Public Service Co Of Oklahoma [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		9,400,000	[18]	7,200,000	[19]	19,200,000	[20]	6,800,000	[21]
Public Service Co Of Oklahoma [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		10,200,000	[22]	10,600,000	[23]	28,900,000	[24]	28,800,000	[25]
Public Service Co Of Oklahoma [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		6,400,000	[26]	8,300,000	[27]	21,400,000	[28]	24,800,000	[29]
Public Service Co Of Oklahoma [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		608,000,000		484,300,000		1,439,400,000		1,123,900,000
Public Service Co Of Oklahoma [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		200,000		(500,000)		(700,000)		500,000
Public Service Co Of Oklahoma [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		200,000	[30]	(500,000)	[31]	(700,000)	[17]	500,000	[32]
Public Service Co Of Oklahoma [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,000,000		1,500,000		3,700,000		3,900,000
Revenues		0	[30]	0	[31]	0	[17]	0	[32]
Public Service Co Of Oklahoma [Member] \| Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		36,800,000				36,800,000				18,800,000
Public Service Co Of Oklahoma [Member] \| 2022 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		3,400,000				3,400,000
Public Service Co Of Oklahoma [Member] \| 2023-2024 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
Public Service Co Of Oklahoma [Member] \| 2025-2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
Public Service Co Of Oklahoma [Member] \| After 2026
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
Southwestern Electric Power Co [Member]
Disaggregation of Revenue
Revenues		717,500,000		584,100,000		1,748,900,000		1,630,300,000
Revenue, Performance Obligation
Fixed Performance Obligations		10,900,000				10,900,000
Affiliated Companies - Contracts with Customers		53,800,000				53,800,000				38,300,000
Revenue Textuals
Revenue from Related Parties		18,200,000		13,500,000		43,700,000		32,200,000
Southwestern Electric Power Co [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		576,700,000		464,000,000		1,406,300,000		1,186,800,000
Southwestern Electric Power Co [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		285,500,000		230,900,000		650,000,000		547,100,000
Southwestern Electric Power Co [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		182,300,000		145,400,000		458,800,000		385,400,000
Southwestern Electric Power Co [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		108,300,000		85,400,000		290,100,000	[17]	247,100,000
Southwestern Electric Power Co [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		600,000		2,300,000		7,400,000		7,200,000
Southwestern Electric Power Co [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		129,900,000		114,200,000		323,000,000		420,700,000
Southwestern Electric Power Co [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		87,600,000	[18]	77,100,000	[19]	206,200,000	[20]	326,200,000	[21]
Southwestern Electric Power Co [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		42,300,000	[22]	37,100,000	[23]	116,800,000	[24]	94,500,000	[25]
Southwestern Electric Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		7,600,000	[26]	6,100,000	[27]	18,900,000	[28]	17,700,000	[29]
Southwestern Electric Power Co [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		714,200,000		584,300,000		1,748,200,000		1,625,200,000
Southwestern Electric Power Co [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		3,300,000		(200,000)		700,000		5,100,000
Southwestern Electric Power Co [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		3,300,000	[30]	(200,000)	[31]	700,000	[17]	5,100,000	[32]
Southwestern Electric Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		500,000		500,000		1,500,000		1,500,000
Revenues		0	[30]	0	[31]	0	[17]	0	[32]
Southwestern Electric Power Co [Member] \| Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		20,200,000				20,200,000				$ 24,700,000
Southwestern Electric Power Co [Member] \| 2022 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		10,900,000				10,900,000
Southwestern Electric Power Co [Member] \| 2023-2024 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
Southwestern Electric Power Co [Member] \| 2025-2026 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
Southwestern Electric Power Co [Member] \| After 2026
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
Consolidation Eliminations [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Revenues		(425,000,000)		(376,000,000)		(1,190,500,000)		(1,112,200,000)
Revenue Textuals
Revenue from Related Parties		(425,000,000)		(376,000,000)		(1,190,500,000)		(1,112,200,000)
Consolidation Eliminations [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(300,000)		(100,000)		(700,000)		(500,000)
Consolidation Eliminations [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Consolidation Eliminations [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Consolidation Eliminations [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(300,000)		(100,000)		(700,000)		(500,000)
Consolidation Eliminations [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Consolidation Eliminations [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(395,200,000)		(321,100,000)		(1,103,900,000)		(951,700,000)
Consolidation Eliminations [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(200,000)		0		(100,000)	[1]	0
Consolidation Eliminations [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(392,700,000)	[2]	(317,400,000)	[3]	(1,086,500,000)	[4]	(901,500,000)	[5]
Consolidation Eliminations [Member] \| Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(2,500,000)	[6]	(600,000)	[7]	(6,200,000)	[1]	(1,700,000)	[8]
Consolidation Eliminations [Member] \| Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		200,000		(3,100,000)	[9]	(11,100,000)	[10]	(48,500,000)	[11]
Consolidation Eliminations [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(31,900,000)	[12]	(40,100,000)	[7]	(71,600,000)	[13]	(87,900,000)	[8]
Consolidation Eliminations [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(427,400,000)		(361,300,000)		(1,176,200,000)		(1,040,100,000)
Consolidation Eliminations [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		2,400,000		(14,700,000)		(14,300,000)		(72,100,000)
Consolidation Eliminations [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		4,400,000	[6]	(11,700,000)	[7]	(7,400,000)	[1]	(63,500,000)	[8]
Consolidation Eliminations [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenues		(2,000,000)	[6]	(3,000,000)	[7],[14]	(6,900,000)	[1],[15]	(8,600,000)	[8],[16]
Consolidation Eliminations [Member] \| AEP Transmission Co [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Revenues		0		0		0		0
Revenue Textuals
Revenue from Related Parties		0		0		0		0
Vertically Integrated Utilities [Member]
Disaggregation of Revenue
Revenues		3,226,300,000		2,759,300,000		8,562,200,000		7,557,200,000
Revenue Textuals
Revenue from Related Parties		51,700,000		42,500,000		145,800,000		111,300,000
Vertically Integrated Utilities [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,735,900,000		2,376,700,000		7,368,800,000		6,386,600,000
Vertically Integrated Utilities [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,298,000,000		1,144,300,000		3,428,100,000		3,016,200,000
Vertically Integrated Utilities [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		725,100,000		618,900,000		1,922,800,000		1,642,000,000
Vertically Integrated Utilities [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		658,500,000		566,000,000		1,863,300,000		1,602,500,000
Vertically Integrated Utilities [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		54,300,000		47,500,000		154,600,000		125,900,000
Vertically Integrated Utilities [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		419,600,000		333,600,000		1,009,200,000		1,024,400,000
Vertically Integrated Utilities [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		299,300,000		233,800,000		674,800,000	[1]	757,100,000
Vertically Integrated Utilities [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		120,300,000	[2]	99,800,000	[3]	334,400,000	[4]	267,300,000	[5]
Revenue Textuals
Revenue from Related Parties						120,000,000
Vertically Integrated Utilities [Member] \| Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[6]	0	[7]	0	[1]	0	[8]
Vertically Integrated Utilities [Member] \| Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0	[9]	0	[10]	0	[11]
Vertically Integrated Utilities [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		69,700,000	[12]	49,400,000	[7]	180,500,000	[13]	136,100,000	[8]
Vertically Integrated Utilities [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		3,225,200,000		2,759,700,000		8,558,500,000		7,547,100,000
Vertically Integrated Utilities [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		1,100,000		(400,000)		3,700,000		10,100,000
Vertically Integrated Utilities [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		900,000	[6]	500,000	[7]	3,400,000	[1]	10,700,000	[8]
Vertically Integrated Utilities [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenues		200,000	[6]	(900,000)	[7],[14]	300,000	[1],[15]	(600,000)	[8],[16]
Transmission And Distribution Utilities [Member]
Disaggregation of Revenue
Revenues		1,530,200,000		1,200,300,000		4,078,600,000		3,391,800,000
Revenue Textuals
Revenue from Related Parties		4,700,000		5,300,000		14,100,000		24,900,000
Transmission And Distribution Utilities [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,301,400,000		984,200,000		3,405,200,000		2,761,500,000
Transmission And Distribution Utilities [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		721,900,000		598,000,000		1,884,100,000		1,641,200,000
Transmission And Distribution Utilities [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		373,000,000		279,900,000		994,400,000		804,100,000
Transmission And Distribution Utilities [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		191,500,000		95,200,000		487,300,000		283,800,000
Transmission And Distribution Utilities [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		15,000,000		11,100,000		39,400,000		32,400,000
Transmission And Distribution Utilities [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		162,300,000		150,600,000		482,100,000		420,700,000
Transmission And Distribution Utilities [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0	[1]	0
Transmission And Distribution Utilities [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		162,300,000	[2]	150,600,000	[3]	482,100,000	[4]	420,700,000	[5]
Transmission And Distribution Utilities [Member] \| Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[6]	0	[7]	0	[1]	0	[8]
Transmission And Distribution Utilities [Member] \| Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0	[9]	0	[10]	0	[11]
Transmission And Distribution Utilities [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		74,500,000	[12]	54,200,000	[7]	194,200,000	[13]	149,300,000	[8]
Transmission And Distribution Utilities [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,538,200,000		1,189,000,000		4,081,500,000		3,331,500,000
Transmission And Distribution Utilities [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(8,000,000)		11,300,000		(2,900,000)		60,300,000
Transmission And Distribution Utilities [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		(13,500,000)	[6]	6,400,000	[7]	(21,500,000)	[1]	46,100,000	[8]
Transmission And Distribution Utilities [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenues		5,500,000	[6]	4,900,000	[7],[14]	18,600,000	[1],[15]	14,200,000	[8],[16]
AEP Transmission Holdco [Member]
Disaggregation of Revenue
Revenues		430,900,000		391,600,000		1,221,100,000		1,146,800,000
AEP Transmission Holdco [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
AEP Transmission Holdco [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
AEP Transmission Holdco [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
AEP Transmission Holdco [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
AEP Transmission Holdco [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
AEP Transmission Holdco [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		424,900,000		375,800,000		1,261,000,000		1,092,100,000
AEP Transmission Holdco [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0	[1]	0
AEP Transmission Holdco [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		424,900,000	[2]	375,800,000	[3]	1,261,000,000	[4]	1,092,100,000	[5]
Revenue Textuals
Revenue from Related Parties		342,000,000		286,000,000		1,000,000,000		835,000,000
AEP Transmission Holdco [Member] \| Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[6]	0	[7]	0	[1]	0	[8]
AEP Transmission Holdco [Member] \| Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0	[9]	0	[10]	0	[11]
AEP Transmission Holdco [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(300,000)	[12]	5,100,000	[7]	(300,000)	[13]	12,500,000	[8]
AEP Transmission Holdco [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		424,600,000		380,900,000		1,260,700,000		1,104,600,000
AEP Transmission Holdco [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		6,300,000		10,700,000		(39,600,000)		42,200,000
AEP Transmission Holdco [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		6,300,000	[6]	10,700,000	[7]	(39,600,000)	[1]	42,200,000	[8]
AEP Transmission Holdco [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenues		0	[6]	0	[7],[14]	0	[1],[15]	0	[8],[16]
Generation And Marketing [Member]
Disaggregation of Revenue
Revenues		735,400,000		621,100,000		2,014,300,000		1,691,900,000
Revenue Textuals
Revenue from Related Parties		2,300,000		3,700,000		17,300,000		50,300,000
Generation And Marketing [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Generation And Marketing [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Generation And Marketing [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Generation And Marketing [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Generation And Marketing [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Generation And Marketing [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		610,900,000		469,000,000		1,591,900,000		1,511,700,000
Revenue Textuals
Revenue from Related Parties						11,000,000		49,000,000
Generation And Marketing [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		83,700,000		47,800,000		207,000,000	[1]	119,400,000
Revenue Textuals
Revenue from Related Parties				4,000,000
Generation And Marketing [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[2]	0	[3]	0	[4]	0	[5]
Generation And Marketing [Member] \| Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		44,300,000	[6]	24,100,000	[7]	104,900,000	[1]	66,700,000	[8]
Generation And Marketing [Member] \| Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		482,900,000		397,100,000	[9]	1,280,000,000	[10]	1,325,600,000	[11]
Generation And Marketing [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,700,000	[12]	1,400,000	[7]	11,900,000	[13]	4,900,000	[8]
Generation And Marketing [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		612,600,000		470,400,000		1,603,800,000		1,516,600,000
Generation And Marketing [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		122,800,000		150,700,000		410,500,000		175,300,000
Generation And Marketing [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		0	[6]	0	[7]	0	[1]	0	[8]
Generation And Marketing [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenues		122,800,000	[6],[33]	150,700,000	[7],[14]	410,500,000	[1],[15]	175,300,000	[8],[16]
Other Segments [Member]
Disaggregation of Revenue
Revenues	[34]	28,300,000		26,700,000		72,700,000		55,100,000
Revenue Textuals
Revenue from Related Parties	[34]	17,300,000		23,200,000		36,600,000		43,500,000
Other Segments [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Other Segments [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Other Segments [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Other Segments [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Other Segments [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Other Segments [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,200,000		100,000		6,700,000		600,000
Other Segments [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0	[1]	0
Other Segments [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[2]	0	[3]	0	[4]	0	[5]
Other Segments [Member] \| Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[6]	0	[7]	0	[1]	0	[8]
Other Segments [Member] \| Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,200,000		100,000	[9]	6,700,000	[10]	600,000	[11]
Other Segments [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		24,300,000	[12]	23,500,000	[7]	59,100,000	[13]	46,100,000	[8]
Other Segments [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		26,500,000		23,600,000		65,800,000		46,700,000
Other Segments [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		1,800,000		3,100,000		6,900,000		8,400,000
Other Segments [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		0	[6]	0	[7]	0	[1]	0	[8]
Other Segments [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers	[34]	11,000,000		3,500,000		36,100,000		11,600,000
Revenues		1,800,000	[6]	$ 3,100,000	[7],[14]	6,900,000	[1],[15]	$ 8,400,000	[8],[16]
Corporate and Other \| Other Revenues [Member]
Revenue Textuals
Revenue from Related Parties		$ 18,000,000
Corporate and Other \| Other Revenues [Member]
Revenue Textuals
Revenue from Related Parties						$ 36,000,000

[1]Amounts include affiliated and nonaffiliated revenues.[2]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $342 million. The remaining affiliated amounts were immaterial.[3]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $286 million. The remaining affiliated amounts were immaterial.[4]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $1 billion. The affiliated revenue for Vertically Integrated Utilities was $120 million. The remaining affiliated amounts were immaterial.[5] (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $835 million. The remaining affiliated amounts were immaterial.