Ohio Power (OHIPN) 10-Q27 Jul 232023 Q2 Quarterly reportFinancial data

Company Profile

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
Document and Entity Information - shares	Jun. 30, 2023	Jul. 27, 2023
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2023
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		515,176,044
Entity Central Index Key	0000004904
Amendment Flag	false
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q2
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				6 Months Ended
Consolidated Statements of Income - USD ($) $ in Millions		Jun. 30, 2023		Jun. 30, 2022		Jun. 30, 2023		Jun. 30, 2022
Revenues
Revenue from Contracts with Customers		$ 4,372.5		$ 4,639.7		$ 9,063.4		$ 9,232.3
TOTAL REVENUES		4,372.5		4,639.7		9,063.4		9,232.3
Expenses
Other Operation		631.2		619.8		1,311.2		1,282
Maintenance		340		326.5		657.3		611.5
Loss On Expected Sale Of KPCo		0		68.8		0		68.8
Gain on Sale of Mineral Rights		0		(116.3)		0		(116.3)
Depreciation and Amortization		741.6		802.6		1,517.1		1,595
Taxes Other Than Income Taxes		360.4		369.5		755.3		733.7
TOTAL EXPENSES		3,497.8		3,635.3		7,483.9		7,239.8
OPERATING INCOME (LOSS)		874.7		1,004.4		1,579.5		1,992.5
Other Income (Expense):
Other Income		14.4		(12.7)		29.1		(10.4)
Allowance for Equity Funds Used During Construction		41		28.6		72.3		59.6
Non-Service Cost Components of Net Periodic Benefit Cost		55.2		47.1		110.7		94.3
Interest Expense		(460)		(327.6)		(875.7)		(641)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		525.3		739.8		915.9		1,495
Income Tax Expense (Benefit)		28.6		54		39		106.8
Equity Earnings (Loss) of Unconsolidated Subsidiaries		19.4		(165)		39.6		(149.3)
Net Income (Loss)		516.1		520.8		916.5		1,238.9
Net Income (Loss) Attributable to Noncontrolling Interests		(5.1)		(3.7)		(1.7)		(0.3)
Earnings Attributable to Common Shareholders		$ 521.2		$ 524.5		$ 918.2		$ 1,239.2
Earnings Per Share
Weighted Average Number of Basic AEP Common Shares Outstanding		514,879,144		513,623,431		514,529,837		509,857,710
Total Basic Earnings Per Share Attributable to AEP Common Shareholders		$ 1.01		$ 1.02		$ 1.78		$ 2.43
Weighted Average Number of Diluted AEP Common Shares Outstanding		516,242,919		515,162,210		515,922,446		511,391,735
Total Diluted Earnings Per Share Attributable to AEP Common Shareholders		$ 1.01		$ 1.02		$ 1.78		$ 2.42
Common Stock, Dividends Per Share, Declared		$ 0.83		$ 0.78
Acquisition Of Nuclear Fuel Included In Current Liabilities						$ (36)		$ 0
Cash Flow Hedges, Tax		$ 9.3		$ 35.2		(31.2)		101.1
Amortization of Pension and OPEB Deferred Costs, Tax		(0.8)		(3.1)		(5.1)		(3.7)
Related Party
Revenues
Revenue from Contracts with Customers		0		0		0		0
Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers		2,629		2,595		5,445.3		5,241.8
Transmission and Distribution Utilities [Member]
Revenues
Revenue from Contracts with Customers		1,330.8		1,296.8		2,786.1		2,539
Generation and Marketing [Member]
Revenues
Revenue from Contracts with Customers		318.2		654.4		645.1		1,263.9
Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		94.5		93.5		186.9		187.6
TOTAL REVENUES		(128.8)	[1]	135.7	[2],[3]	(258.7)	[4],[5]	301.1	[6],[7]
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold		1,424.6		1,564.4		3,131		3,065.1
AEP Texas Inc. [Member]
Revenues
TOTAL REVENUES		461.2		478.8		890.7		895.5
Expenses
Other Operation		93.9		142		240.8		267.8
Maintenance		26.3		24.8		50.7		47.4
Depreciation and Amortization		114.9		116.2		225.9		225
Taxes Other Than Income Taxes		44.8		43		88.3		80.3
TOTAL EXPENSES		279.9		326		605.7		620.5
OPERATING INCOME (LOSS)		181.3		152.8		285		275
Other Income (Expense):
Interest Income		0.6		1.3		1		1.4
Allowance for Equity Funds Used During Construction		5.3		3.7		11.6		8
Non-Service Cost Components of Net Periodic Benefit Cost		4.8		4.1		9.6		8.3
Interest Expense		(56.3)		(52.3)		(113.2)		(97.8)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		135.7		109.6		194		194.9
Income Tax Expense (Benefit)		26.6		19.6		37.3		35.3
Net Income (Loss)		109.1		90		156.7		159.6
Earnings Per Share
Cash Flow Hedges, Tax		0.8		0		0.8		0.1
Amortization of Pension and OPEB Deferred Costs, Tax		0		0		(0.1)		0
AEP Texas Inc. [Member] \| Related Party
Revenues
Revenue from Contracts with Customers		1.3		0.8		2.5		1.7
AEP Texas Inc. [Member] \| Transmission and Distribution Utilities [Member]
Revenues
Revenue from Contracts with Customers		459.4		476.9		887.1		891.6
AEP Texas Inc. [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		0.5		1.1		1.1		2.2
TOTAL REVENUES		0	[8]	0	[9]	0	[10]	0	[11]
AEP Transmission Co [Member]
Revenues
Provision for Refund Affiliated		(8.3)		(46.8)		(13.1)		(56.4)
Provision for Refund-Nonaffiliated		(2.8)		(8.3)		(3.8)		(10.3)
TOTAL REVENUES		444.9		364.4		886.5		764.8
Expenses
Other Operation		26.4		29.6		55.4		55.1
Maintenance		4.3		3.8		9.2		7.1
Depreciation and Amortization		96.4		85.7		191.6		168.8
Taxes Other Than Income Taxes		68		68.7		142.8		134.3
TOTAL EXPENSES		195.1		187.8		399		365.3
OPERATING INCOME (LOSS)		249.8		176.6		487.5		399.5
Other Income (Expense):
Interest Income		2.6		0.2		4.1		0.3
Allowance for Equity Funds Used During Construction		23.1		15.3		39.5		30.9
Interest Expense		(50.7)		(39.3)		(95.9)		(77)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		224.8		152.8		435.2		353.7
Income Tax Expense (Benefit)		49.1		34.3		96.8		79.8
Net Income (Loss)		175.7		118.5		338.4		273.9
Earnings Per Share
Revenues from Related Parties, Net of Provisions for Refund		357.5		287.1		710.1		602.5
AEP Transmission Co [Member] \| Related Party
Revenues
Revenue from Contracts with Customers		365.8		333.9		723.2		658.9
AEP Transmission Co [Member] \| AEPTCo Parent [Member]
Revenues
Revenue from Contracts with Customers		0		0		0		0
TOTAL REVENUES		0		0		0		0
Other Income (Expense):
Net Income (Loss)	[12]	1.5		0.1		2.6		0.1
AEP Transmission Co [Member] \| AEPTCo Parent [Member] \| Related Party
Revenues
Revenue from Contracts with Customers		0		0		0		0
AEP Transmission Co [Member] \| State Transcos [Member]
Revenues
TOTAL REVENUES		444.9		364.4		886.5		764.8
Other Income (Expense):
Net Income (Loss)		174.2		118.4		335.8		273.8
AEP Transmission Co [Member] \| State Transcos [Member] \| Related Party
Revenues
Revenue from Contracts with Customers		357.5		287.1		710.1		602.5
AEP Transmission Co [Member] \| Transmission [Member]
Revenues
Revenue from Contracts with Customers		90.2		85.6		180.2		172.6
Earnings Per Share
Revenue from Contract with Customers, Net of Provisions for Refund, Including Assessed Tax		87.4		77.3		176.4		162.3
AEP Transmission Co [Member] \| Transmission [Member] \| State Transcos [Member]
Revenues
Revenue from Contracts with Customers		87.4		77.3		176.4		162.3
AEP Transmission Co [Member] \| Other Revenues [Member]
Revenues
TOTAL REVENUES		0	[8]	0	[9]	0	[10]	0	[11]
Appalachian Power Co [Member]
Revenues
TOTAL REVENUES		826.5		773.6		1,814.2		1,680.9
Expenses
Other Operation		189.9		147.1		381.7		332
Maintenance		75.1		71.2		148.2		145.3
Depreciation and Amortization		138.1		142.9		281.1		288.1
Taxes Other Than Income Taxes		41.2		39.3		83		79.5
TOTAL EXPENSES		722.2		646.2		1,511.6		1,361.1
OPERATING INCOME (LOSS)		104.3		127.4		302.6		319.8
Other Income (Expense):
Interest Income		0.8		0.3		1.4		0.4
Allowance for Equity Funds Used During Construction		2.7		2.6		5.1		4.6
Non-Service Cost Components of Net Periodic Benefit Cost		8.2		7.2		16.3		14.5
Interest Expense		(66.9)		(55.1)		(132.2)		(109.4)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		49.1		82.4		193.2		229.9
Income Tax Expense (Benefit)		6.2		(7.8)		37.8		19.5
Net Income (Loss)		42.9		90.2		155.4		210.4
Earnings Per Share
Cash Flow Hedges, Tax		0		0		(0.1)		(0.1)
Amortization of Pension and OPEB Deferred Costs, Tax		(0.2)		(0.3)		(0.4)		(0.6)
Appalachian Power Co [Member] \| Related Party
Revenues
Revenue from Contracts with Customers		61.1		63.1		130.7		120
Appalachian Power Co [Member] \| Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers		762.5		704.9		1,677		1,552
Appalachian Power Co [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		2.9		5.6		6.5		8.9
TOTAL REVENUES		0	[8]	0	[9]	0	[10]	0.1	[11]
Appalachian Power Co [Member] \| Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold		277.9		245.7		617.6		516.2
Indiana Michigan Power Co [Member]
Revenues
TOTAL REVENUES		599.2		631		1,262.2		1,256.2
Expenses
Purchased Electricity from AEP Affiliates		37.1		59.6		82.2		116.7
Other Operation		170.1		149.2		339.8		288.5
Maintenance		57.1		60.8		115.7		111.8
Depreciation and Amortization		111		133.7		236.2		268.6
Taxes Other Than Income Taxes		20.6		28.6		40.1		53.8
TOTAL EXPENSES		489.8		542.8		1,007.1		1,056
OPERATING INCOME (LOSS)		109.4		88.2		255.1		200.2
Other Income (Expense):
Other Income		3		2.4		3.6		5
Allowance for Equity Funds Used During Construction						2.8		5.4
Non-Service Cost Components of Net Periodic Benefit Cost		7.7		6.2		15.7		12.5
Interest Expense		(35.8)		(31)		(69)		(61.3)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		84.3		65.8		205.4		156.4
Income Tax Expense (Benefit)		9.5		(1.4)		27.8		(0.3)
Net Income (Loss)		74.8		67.2		177.6		156.7
Earnings Per Share
Acquisition Of Nuclear Fuel Included In Current Liabilities						(36)		0
Cash Flow Hedges, Tax		0		0.1		(0.2)		0.2
Amortization of Pension and OPEB Deferred Costs, Tax		(0.1)		0		(0.6)		0
Indiana Michigan Power Co [Member] \| Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers		580.4		604.4		1,223.2		1,216.4
Indiana Michigan Power Co [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		2.4		2.8		5.5		5.6
TOTAL REVENUES		0	[8]	0	[9]	0	[10]	(0.1)	[11]
Indiana Michigan Power Co [Member] \| Other Revenues [Member] \| Related Party
Revenues
Revenue from Contracts with Customers				19		35		29
Indiana Michigan Power Co [Member] \| Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold		93.9		110.9		193.1		216.6
Ohio Power Co [Member]
Revenues
TOTAL REVENUES		879.1		822.9		1,913.7		1,652.9
Expenses
Purchased Electricity from AEP Affiliates		11.6		3.5		11.6		9.8
Other Operation		265.4		223.3		539.2		460.9
Maintenance		51.2		48.5		95.5		88.9
Depreciation and Amortization		68.2		71.3		143.4		146.2
Taxes Other Than Income Taxes		114.2		121		249.5		248
TOTAL EXPENSES		778.2		716.8		1,699.4		1,429.3
OPERATING INCOME (LOSS)		100.9		106.1		214.3		223.6
Other Income (Expense):
Other Income		0.2		0.6		0.3		0.8
Allowance for Equity Funds Used During Construction		2.9		3.4		5.7		6.4
Non-Service Cost Components of Net Periodic Benefit Cost		6.5		5.5		13		11
Interest Expense		(31.9)		(29.8)		(63)		(59)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		78.6		85.8		170.3		182.8
Income Tax Expense (Benefit)		10.9		11.8		24.6		25.6
Equity Earnings (Loss) of Unconsolidated Subsidiaries		0		0.8		0		0.8
Net Income (Loss)		67.7		74.8		145.7		158
Ohio Power Co [Member] \| Related Party
Revenues
Revenue from Contracts with Customers		8.2		3.9		15.8		7.6
Ohio Power Co [Member] \| Transmission and Distribution Utilities [Member]
Revenues
Revenue from Contracts with Customers		868.8		817.2		1,890.6		1,641.4
Ohio Power Co [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		2.1		1.8		7.3		3.9
TOTAL REVENUES		6	[8]	6.8	[9]	17.1	[10]	13.1	[11]
Ohio Power Co [Member] \| Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold		267.6		249.2		660.2		475.5
Public Service Co Of Oklahoma [Member]
Revenues
TOTAL REVENUES		474.7		442.9		891.7		830.5
Expenses
Other Operation		87.5		95.9		179.6		184.7
Maintenance		28.5		31.3		57.3		56.7
Depreciation and Amortization		64.9		60.5		126		113.2
Taxes Other Than Income Taxes		15		13.8		32.3		28
TOTAL EXPENSES		419		393.4		818.4		763.2
OPERATING INCOME (LOSS)		55.7		49.5		73.3		67.3
Other Income (Expense):
Interest Income		0.1		2.5		1.1		4.2
Allowance for Equity Funds Used During Construction		1.4		0.2		2.9		1.3
Non-Service Cost Components of Net Periodic Benefit Cost		3.5		3.2		7.1		6.3
Interest Expense		(26.8)		(21.3)		(52)		(40.2)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		33.9		34.1		32.4		38.9
Income Tax Expense (Benefit)		(17.1)		(8.9)		(16.3)		(9.9)
Net Income (Loss)		51		43		48.7		48.8
Earnings Per Share
Cash Flow Hedges, Tax		0		0		(0.4)		0
Public Service Co Of Oklahoma [Member] \| Related Party
Revenues
Revenue from Contracts with Customers		0.1		0.8		0.8		1.4
Public Service Co Of Oklahoma [Member] \| Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers		472.4		440		887.2		826.4
Public Service Co Of Oklahoma [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		2.2		2.1		3.7		2.7
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		223.1		191.9		423.2		380.6
Southwestern Electric Power Co [Member]
Revenues
TOTAL REVENUES		537.8		536.6		1,053.7		1,031.4
Expenses
Other Operation		85.2		103.1		184.4		194.6
Maintenance		45		44.8		82.7		74.9
Depreciation and Amortization		85.8		78.2		166.2		156
Taxes Other Than Income Taxes		32.1		30.9		68.2		60.7
TOTAL EXPENSES		438		437		900.7		864.4
OPERATING INCOME (LOSS)		99.8		99.6		153		167
Other Income (Expense):
Interest Income		5.3		7.6		10.7		11.2
Allowance for Equity Funds Used During Construction		2.5		0.8		3		2.4
Non-Service Cost Components of Net Periodic Benefit Cost		3.4		3.1		6.8		6.2
Interest Expense		(40.1)		(33.7)		(65.1)		(66.8)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		70.9		77.4		108.4		120
Income Tax Expense (Benefit)		(10)		(1)		(14)		(3.2)
Equity Earnings (Loss) of Unconsolidated Subsidiaries		0.4		0.4		0.7		0.7
Net Income (Loss)		81.3		78.8		123.1		123.9
Net Income (Loss) Attributable to Noncontrolling Interests		0.3		2.1		1.5		3.1
Earnings Attributable to Common Shareholders		81		76.7		121.6		120.8
Earnings Per Share
Cash Flow Hedges, Tax		0		0		0.1		0
Amortization of Pension and OPEB Deferred Costs, Tax		(0.1)		(0.1)		(0.2)		(0.2)
Southwestern Electric Power Co [Member] \| Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers		522.5		520.7		1,026.2		1,004.9
Southwestern Electric Power Co [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		0.8		0.4		1.3		1
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		189.9		180		399.2		378.2
Mineral Rights
Expenses
Gain on Sale of Mineral Rights						0		(116.3)
Reconciling Adjustments [Member]
Revenues
Revenue from Contracts with Customers		0		0		0		0
TOTAL REVENUES		(464.2)		(373.3)		(907.9)		(765.5)
Other Income (Expense):
Net Income (Loss)		0		0		0		0
Reconciling Adjustments [Member] \| Related Party
Revenues
Revenue from Contracts with Customers		(464.2)		(373.3)		(907.9)		(765.5)
Reconciling Adjustments [Member] \| Other Revenues [Member]
Revenues
TOTAL REVENUES		(2)	[1]	(2)	[2],[3]	(2.9)	[4],[5]	(4.9)	[6],[7]
Reconciling Adjustments [Member] \| AEP Transmission Co [Member]
Revenues
Revenue from Contracts with Customers		0		0		0		0
TOTAL REVENUES		0		0		0		0
Other Income (Expense):
Net Income (Loss)		0		0		0		0
Reconciling Adjustments [Member] \| AEP Transmission Co [Member] \| Related Party
Revenues
Revenue from Contracts with Customers		0		0		0		0
Competitive Contracted Renewable Portfolio
Expenses
Asset Impairments and Other Related Charges		$ 0		$ 0		$ 112		$ 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		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Net Income (Loss)	$ 516.1	$ 520.8	$ 916.5	$ 1,238.9
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	34.8	132.4	(117.6)	380.4
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(3.1)	(11.6)	(19.2)	(13.8)
Reclassifications of KPCo Pension and OPEB Regulatory Assets, Net of Tax	0	0	16.7	0
Other Comprehensive Income (Loss), Net of Tax, Total	31.7	120.8	(120.1)	366.6
TOTAL COMPREHENSIVE INCOME (LOSS)	547.8	641.6	796.4	1,605.5
Total Comprehensive Income (Loss) Attributable to Noncontrolling Interest	(5.1)	(3.7)	(1.7)	(0.3)
TOTAL COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	552.9	645.3	798.1	1,605.8
Cash Flow Hedges, Tax	9.3	35.2	(31.2)	101.1
Amortization of Pension and OPEB Deferred Costs, Tax	(0.8)	(3.1)	(5.1)	(3.7)
Reclassifications of KPCo Pension and OPEB Regulatory Assets, Tax	0	0	4.4	0
Appalachian Power Co [Member]
Net Income (Loss)	42.9	90.2	155.4	210.4
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	(0.2)	(0.2)	(0.4)	(0.4)
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(0.8)	(1)	(1.6)	(2.1)
Other Comprehensive Income (Loss), Net of Tax, Total	(1)	(1.2)	(2)	(2.5)
TOTAL COMPREHENSIVE INCOME (LOSS)	41.9	89	153.4	207.9
Cash Flow Hedges, Tax	0	0	(0.1)	(0.1)
Amortization of Pension and OPEB Deferred Costs, Tax	(0.2)	(0.3)	(0.4)	(0.6)
AEP Texas Inc. [Member]
Net Income (Loss)	109.1	90	156.7	159.6
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	3.2	0.2	3.2	0.5
Amortization of Pension and OPEB Deferred Costs, Net of Tax	0	0	(0.6)	0
Other Comprehensive Income (Loss), Net of Tax, Total	3.2	0.2	2.6	0.5
TOTAL COMPREHENSIVE INCOME (LOSS)	112.3	90.2	159.3	160.1
Cash Flow Hedges, Tax	0.8	0	0.8	0.1
Amortization of Pension and OPEB Deferred Costs, Tax	0	0	(0.1)	0
Indiana Michigan Power Co [Member]
Net Income (Loss)	74.8	67.2	177.6	156.7
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	0.1	0.4	(0.6)	0.8
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(0.3)	(0.1)	(2.2)	(0.2)
Other Comprehensive Income (Loss), Net of Tax, Total	(0.2)	0.3	(2.8)	0.6
TOTAL COMPREHENSIVE INCOME (LOSS)	74.6	67.5	174.8	157.3
Cash Flow Hedges, Tax	0	0.1	(0.2)	0.2
Amortization of Pension and OPEB Deferred Costs, Tax	(0.1)	0	(0.6)	0
Ohio Power Co [Member]
Net Income (Loss)	67.7	74.8	145.7	158
Public Service Co Of Oklahoma [Member]
Net Income (Loss)	51	43	48.7	48.8
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	0	0	(1.5)	0
TOTAL COMPREHENSIVE INCOME (LOSS)	51	43	47.2	48.8
Cash Flow Hedges, Tax	0	0	(0.4)	0
Southwestern Electric Power Co [Member]
Net Income (Loss)	81.3	78.8	123.1	123.9
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	(0.1)	(0.1)	0.3	0
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(0.3)	(0.4)	(0.6)	(0.8)
Other Comprehensive Income (Loss), Net of Tax, Total	(0.4)	(0.5)	(0.3)	(0.8)
TOTAL COMPREHENSIVE INCOME (LOSS)	80.9	78.3	122.8	123.1
Total Comprehensive Income (Loss) Attributable to Noncontrolling Interest	0.3	2.1	1.5	3.1
TOTAL COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	80.6	76.2	121.3	120
Cash Flow Hedges, Tax	0	0	0.1	0
Amortization of Pension and OPEB Deferred Costs, Tax	(0.1)	(0.1)	(0.2)	(0.2)
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
OTHER COMPREHENSIVE INCOME
Other Comprehensive Income (Loss), Net of Tax, Total	$ (3.1)	$ (11.6)	$ (2.5)	$ (13.8)

Condensed Consolidated Statemen

Condensed Consolidated Statements of Changes in Equity - USD ($)	Total	Vertically Integrated Utilities [Member]	Transmission and Distribution Utilities [Member]	Generation and Marketing Revenues [Member]	Other Revenues [Member]		Reconciling Adjustments [Member]	Reconciling Adjustments [Member] Other Revenues [Member]		Generation And Marketing [Member]	Generation And Marketing [Member] Generation and Marketing Revenues [Member]	Generation And Marketing [Member] Other Revenues [Member]		Other Segments [Member]	[2]	Other Segments [Member] Other Revenues [Member]		Transmission Operations [Member]	Transmission Operations [Member] Transmission [Member]	Transmission And Distribution Utilities [Member]	Transmission And Distribution Utilities [Member] Transmission and Distribution Utilities [Member]	Transmission And Distribution Utilities [Member] Other Revenues [Member]		Vertically Integrated Utilities [Member]	Vertically Integrated Utilities [Member] Vertically Integrated Utilities [Member]	Vertically Integrated Utilities [Member] Other Revenues [Member]		Appalachian Power Co [Member]	Appalachian Power Co [Member] Vertically Integrated Utilities [Member]	Appalachian Power Co [Member] Other Revenues [Member]		AEP Texas Inc. [Member]	AEP Texas Inc. [Member] Transmission and Distribution Utilities [Member]	AEP Texas Inc. [Member] Other Revenues [Member]		AEP Transmission Co [Member]	AEP Transmission Co [Member] Transmission [Member]	AEP Transmission Co [Member] Other Revenues [Member]		AEP Transmission Co [Member] Reconciling Adjustments [Member]	AEP Transmission Co [Member] State Transcos [Member]	AEP Transmission Co [Member] State Transcos [Member] Transmission [Member]	AEP Transmission Co [Member] AEPTCo Parent [Member]		Indiana Michigan Power Co [Member]	Indiana Michigan Power Co [Member] Related Party	Indiana Michigan Power Co [Member] Vertically Integrated Utilities [Member]	Indiana Michigan Power Co [Member] Other Revenues [Member]		Indiana Michigan Power Co [Member] Other Revenues [Member] Related Party	Ohio Power Co [Member]	Ohio Power Co [Member] Transmission and Distribution Utilities [Member]	Ohio Power Co [Member] Other Revenues [Member]		Public Service Co Of Oklahoma [Member]	Public Service Co Of Oklahoma [Member] Vertically Integrated Utilities [Member]	Public Service Co Of Oklahoma [Member] Other Revenues [Member]		Southwestern Electric Power Co [Member]	Southwestern Electric Power Co [Member] Related Party	Southwestern Electric Power Co [Member] Vertically Integrated Utilities [Member]	Southwestern Electric Power Co [Member] Other Revenues [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]
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																																																																524,400,000
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)	[1]
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
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Dividends Per Share, Declared	$ 0.78
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																																																																524,400,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Dividends Paid on Common Stock																												(37,500,000)								(90,000,000)									(50,000,000)						(30,000,000)				0				(12,500,000)
Net Income (Loss)	1,239,200,000																																																										120,800,000
Net Income (Loss) Attributable to Noncontrolling Interests	(300,000)																																																										3,100,000
Net Income (Loss)	1,238,900,000						$ 0			$ 181,900,000				$ (179,500,000)				$ 316,400,000		$ 317,600,000				$ 602,500,000				210,400,000				159,600,000				273,900,000				$ 0	$ 273,800,000		$ 100,000	[3]	156,700,000						158,000,000				48,800,000				123,900,000
Other Comprehensive Income (Loss)	366,600,000																											(2,500,000)				500,000													600,000														(800,000)
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				1,300,000				2,800,000									1,300,000						700,000				2,200,000				352,200,000
Ending Balance, Shares at Jun. 30, 2022																																																																524,900,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Revenue from Contracts with Customers	9,232,300,000	$ 5,241,800,000	$ 2,539,000,000	$ 1,263,900,000	$ 187,600,000		0				$ 1,263,900,000					$ 25,100,000	[2]		$ 162,500,000		$ 2,539,000,000				$ 5,241,800,000				$ 1,552,000,000	$ 8,900,000			$ 891,600,000	$ 2,200,000			$ 172,600,000			0		$ 162,300,000	0			$ 9,100,000	$ 1,216,400,000	$ 5,600,000		$ 25,100,000		$ 1,641,400,000	$ 3,900,000			$ 826,400,000	$ 2,700,000			$ 25,500,000	$ 1,004,900,000	$ 1,000,000
Revenues	9,232,300,000				301,100,000	[4],[5]	(765,500,000)	$ (4,900,000)	[4],[5]	1,278,900,000		$ 287,700,000	[4],[5]	44,400,000		5,100,000	[4],[5]	790,200,000		2,548,400,000		$ 13,100,000	[4],[5]	5,335,900,000		$ 100,000	[4],[5]	1,680,900,000		100,000	[6]	895,500,000		0	[6]	764,800,000		$ 0	[6]	0	764,800,000		0		1,256,200,000			(100,000)	[6]		1,652,900,000		13,100,000	[6]	830,500,000		0	[6]	1,031,400,000			0	[6]
Revenue from Contract with Customers, Net of Provisions for Refund, Including Assessed Tax																																					162,300,000
Revenues from Related Parties, Net of Provisions for Refund																																				602,500,000
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)	[1]
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													1,300,000	2,800,000	1,300,000	700,000		2,200,000
Dividends Paid on Common Stock																																				(50,000,000)																																														(50,000,000)
Net Income (Loss)	524,500,000																																																										76,700,000																			524,500,000								76,700,000
Net Income (Loss) Attributable to Noncontrolling Interests	(3,700,000)																																																										2,100,000																																		(3,700,000)	2,100,000
Net Income (Loss)	520,800,000						0			65,900,000				(155,900,000)				142,700,000		164,800,000				303,300,000				90,200,000				90,000,000				118,500,000				0	118,400,000		100,000	[3]	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																											2,200,000																2,800,000					2,200,000
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
Revenue from Contracts with Customers	$ 4,639,700,000	2,595,000,000	1,296,800,000	654,400,000	93,500,000		0				654,400,000					14,400,000	[2]		79,100,000		1,296,800,000				2,595,000,000				704,900,000	5,600,000			476,900,000	1,100,000			85,600,000			0		77,300,000	0			7,100,000	604,400,000	2,800,000		16,700,000		817,200,000	1,800,000			440,000,000	2,100,000			15,500,000	520,700,000	400,000
Revenues	4,639,700,000				135,700,000	[7],[8]	(373,300,000)	(2,000,000)	[7],[8]	659,600,000		128,500,000	[7],[8]	24,500,000		2,300,000	[7],[8]	378,800,000		1,301,600,000		6,800,000	[7],[8]	2,648,500,000		100,000	[7],[8]	773,600,000		0	[9]	478,800,000		0	[9]	364,400,000		0	[9]	0	364,400,000		0		631,000,000			0	[9]		822,900,000		6,800,000	[9]	442,900,000		0	[9]	536,600,000			0	[9]
Revenue from Contract with Customers, Net of Provisions for Refund, Including Assessed Tax																																					77,300,000
Revenues from Related Parties, Net of Provisions for Refund																																				287,100,000
Beginning Balance at Dec. 31, 2022																																				5,873,000,000																																					3,022,300,000									2,850,700,000
Beginning Balance at Dec. 31, 2022	$ 24,122,400,000																											4,975,400,000				3,904,300,000													3,008,300,000						3,088,100,000				$ 2,419,100,000				3,674,800,000					$ 3,413,100,000	260,400,000	56,600,000	321,200,000	157,200,000	100,000	8,051,000,000	1,828,700,000	1,558,200,000		988,800,000	837,800,000	1,042,600,000	1,442,200,000	12,345,600,000		2,891,100,000	2,354,700,000		1,963,200,000	1,929,100,000	1,218,000,000	2,236,000,000	83,700,000	(4,800,000)	(8,600,000)	(300,000)	1,300,000	(4,200,000)	229,000,000	700,000
Beginning Balance, Shares at Dec. 31, 2022	525,099,321																																																						10,482,000									525,100,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of Common Stock, Value	$ 41,100,000																																																															$ 5,100,000						36,000,000
Issuance of Common Stock, Shares																																																																800,000
Common Stock Dividends	(431,800,000)																																																																													(428,800,000)	[10]
Common Stock Dividends																																													(31,200,000)										$ (17,500,000)																												(31,200,000)		(17,500,000)
Common Stock Dividends																																																											(1,500,000)																																		(3,000,000)	(1,500,000)
Other Changes in Equity	(12,500,000)																																																																					(12,700,000)																							200,000
Capital Contribution from Member																																100,000,000				25,000,000															50,000,000								50,000,000													100,000,000	25,000,000		50,000,000		50,000,000
Dividends Paid on Common Stock																																				(55,000,000)																																														(55,000,000)
Net Income (Loss)																																																																														397,000,000								40,600,000
Net Income (Loss) Attributable to Noncontrolling Interests																																																																																													3,400,000	1,200,000
Net Income (Loss)	400,400,000																											112,500,000				47,600,000				162,700,000									102,800,000						78,000,000				(2,300,000)				41,800,000																					112,500,000	47,600,000	162,700,000	102,800,000	78,000,000	(2,300,000)
Other Comprehensive Income (Loss)	(151,800,000)																											(1,000,000)				(600,000)													(2,600,000)										(1,500,000)				100,000																												(151,800,000)	(1,000,000)	(600,000)	(2,600,000)	(1,500,000)	100,000
Ending Balance at Mar. 31, 2023																																				6,005,700,000																																					3,047,300,000									2,958,400,000
Ending Balance at Mar. 31, 2023	$ 23,967,800,000																											5,086,900,000				4,051,300,000													3,077,300,000						3,216,100,000				2,397,800,000				3,765,200,000					$ 3,418,200,000	260,400,000	56,600,000	321,200,000	157,200,000	100,000	8,074,300,000	1,828,700,000	1,658,200,000		988,800,000	887,800,000	1,042,600,000	1,492,200,000	12,313,800,000		3,003,600,000	2,402,300,000		2,034,800,000	2,007,100,000	1,198,200,000	2,276,600,000	(68,100,000)	(5,800,000)	(9,200,000)	(2,900,000)	(200,000)	(4,100,000)	229,600,000	400,000
Ending Balance, Shares at Mar. 31, 2023																																																																525,900,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Dividends Per Share, Declared	$ 0.83
Beginning Balance at Dec. 31, 2022																																				5,873,000,000																																					3,022,300,000									2,850,700,000
Beginning Balance at Dec. 31, 2022	$ 24,122,400,000																											4,975,400,000				3,904,300,000													3,008,300,000						3,088,100,000				$ 2,419,100,000				3,674,800,000					$ 3,413,100,000	260,400,000	56,600,000	321,200,000	157,200,000	100,000	8,051,000,000	1,828,700,000	1,558,200,000		988,800,000	837,800,000	1,042,600,000	1,442,200,000	12,345,600,000		2,891,100,000	2,354,700,000		1,963,200,000	1,929,100,000	1,218,000,000	2,236,000,000	83,700,000	(4,800,000)	(8,600,000)	(300,000)	1,300,000	(4,200,000)	229,000,000	700,000
Beginning Balance, Shares at Dec. 31, 2022	525,099,321																																																						10,482,000									525,100,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Dividends Paid on Common Stock																												0								(85,000,000)									(62,500,000)						0				$ (17,500,000)				(50,000,000)
Net Income (Loss)	$ 918,200,000																																																										121,600,000
Net Income (Loss) Attributable to Noncontrolling Interests	(1,700,000)																																																										1,500,000
Net Income (Loss)	916,500,000						0			(195,000,000)				(111,200,000)				379,700,000		302,400,000				540,600,000				155,400,000				156,700,000				338,400,000				0	335,800,000		2,600,000	[3]	177,600,000						145,700,000				48,700,000				123,100,000
Other Comprehensive Income (Loss)	(120,100,000)																											(2,000,000)				2,600,000													(2,800,000)														(300,000)
Ending Balance at Jun. 30, 2023																																				6,142,800,000																																					3,038,700,000									3,104,100,000
Ending Balance at Jun. 30, 2023	$ 24,123,600,000																											5,133,100,000				4,334,600,000													3,120,700,000						3,408,800,000				2,446,300,000				3,795,500,000					$ 3,421,500,000	260,400,000	56,600,000	321,200,000	157,200,000	100,000	8,110,800,000	1,833,000,000	1,829,200,000		988,900,000	1,012,800,000	1,040,100,000	1,492,200,000	12,405,500,000		3,046,500,000	2,511,400,000		2,078,300,000	2,074,800,000	1,249,200,000	2,307,600,000	(36,400,000)	(6,800,000)	(6,000,000)	(3,100,000)	(200,000)	(4,500,000)	222,200,000	100,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contributions from Parent																												4,300,000				275,300,000				25,000,000									100,000						175,000,000				$ 0				50,000,000
Ending Balance, Shares at Jun. 30, 2023	526,387,081																																																						10,482,000									526,400,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Revenue from Contracts with Customers	$ 9,063,400,000	5,445,300,000	2,786,100,000	645,100,000	186,900,000		0				645,100,000					8,500,000	[2]		178,400,000		2,786,100,000				5,445,300,000				1,677,000,000	6,500,000			887,100,000	1,100,000			180,200,000			0		176,400,000	0			3,100,000	1,223,200,000	5,500,000		30,400,000		1,890,600,000	7,300,000			887,200,000	3,700,000			26,200,000	1,026,200,000	1,300,000
Revenues	9,063,400,000				(258,700,000)	[11],[12]	(907,900,000)	(2,900,000)	[11],[12]	658,400,000		(276,200,000)	[11],[12]	62,100,000		3,200,000	[11],[12]	914,100,000		2,804,400,000		17,200,000	[11],[12]	5,532,300,000		0	[11],[12]	1,814,200,000		0	[13]	890,700,000		0	[13]	886,500,000		0	[13]	0	886,500,000		0		1,262,200,000			0	[13]		1,913,700,000		17,100,000	[13]	$ 891,700,000		0	[13]	1,053,700,000			0	[13]
Revenue from Contract with Customers, Net of Provisions for Refund, Including Assessed Tax																																					176,400,000
Revenues from Related Parties, Net of Provisions for Refund																																				710,100,000
Beginning Balance at Mar. 31, 2023																																				6,005,700,000																																					3,047,300,000									2,958,400,000
Beginning Balance at Mar. 31, 2023	23,967,800,000																											5,086,900,000				4,051,300,000													3,077,300,000						3,216,100,000				2,397,800,000				3,765,200,000					$ 3,418,200,000	260,400,000	56,600,000	321,200,000	157,200,000	100,000	8,074,300,000	1,828,700,000	1,658,200,000		988,800,000	887,800,000	1,042,600,000	1,492,200,000	12,313,800,000		3,003,600,000	2,402,300,000		2,034,800,000	2,007,100,000	1,198,200,000	2,276,600,000	(68,100,000)	(5,800,000)	(9,200,000)	(2,900,000)	(200,000)	(4,100,000)	229,600,000	400,000
Beginning Balance, Shares at Mar. 31, 2023																																																																525,900,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of Common Stock, Value	36,500,000																																																															$ 3,300,000						33,200,000
Issuance of Common Stock, Shares																																																																500,000
Common Stock Dividends	(431,800,000)																																																																													(429,500,000)	[10]
Common Stock Dividends																																													(31,300,000)														(50,000,000)																								(31,300,000)			(50,000,000)
Common Stock Dividends																																																											(600,000)																																		(2,300,000)	(600,000)
Other Changes in Equity	3,300,000																																																																					3,300,000
Capital Contribution from Member																																175,300,000													100,000						125,000,000																					175,300,000		100,000	125,000,000
Dividends Paid on Common Stock																																				(30,000,000)																																														(30,000,000)
Net Income (Loss)	521,200,000																																																										81,000,000																			521,200,000								81,000,000
Net Income (Loss) Attributable to Noncontrolling Interests	(5,100,000)																																																										300,000																																		(5,100,000)	300,000
Net Income (Loss)	516,100,000						0			(38,600,000)				(97,700,000)				197,300,000		176,700,000				278,400,000				42,900,000				109,100,000				175,700,000				0	174,200,000		1,500,000	[3]	74,800,000						67,700,000				51,000,000				81,300,000																					42,900,000	109,100,000	175,700,000	74,800,000	67,700,000	51,000,000
Other Comprehensive Income (Loss)	31,700,000																											(1,000,000)				3,200,000													(200,000)														(400,000)																												31,700,000	(1,000,000)	3,200,000	(200,000)		(400,000)
Ending Balance at Jun. 30, 2023																																				6,142,800,000																																					3,038,700,000									$ 3,104,100,000
Ending Balance at Jun. 30, 2023	$ 24,123,600,000																											5,133,100,000				4,334,600,000													3,120,700,000						3,408,800,000				2,446,300,000				3,795,500,000					$ 3,421,500,000	$ 260,400,000	$ 56,600,000	$ 321,200,000	$ 157,200,000	$ 100,000	$ 8,110,800,000	1,833,000,000	1,829,200,000		$ 988,900,000	$ 1,012,800,000	1,040,100,000	$ 1,492,200,000	$ 12,405,500,000		$ 3,046,500,000	$ 2,511,400,000		$ 2,078,300,000	$ 2,074,800,000	$ 1,249,200,000	$ 2,307,600,000	$ (36,400,000)	$ (6,800,000)	$ (6,000,000)	$ (3,100,000)	$ (200,000)	$ (4,500,000)	$ 222,200,000	$ 100,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contributions from Parent																												4,300,000																																											$ 4,300,000
Return of Capital to Parent Equity Statement																																(4,300,000)				(8,600,000)																			$ (2,500,000)																	$ (4,300,000)	$ (8,600,000)			$ (2,500,000)
Ending Balance, Shares at Jun. 30, 2023	526,387,081																																																						10,482,000									526,400,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Dividends Per Share, Declared	$ 0.83
Revenue from Contracts with Customers	$ 4,372,500,000	$ 2,629,000,000	$ 1,330,800,000	$ 318,200,000	94,500,000		0				$ 318,200,000					6,200,000	[2]		$ 88,300,000		$ 1,330,800,000				$ 2,629,000,000				$ 762,500,000	2,900,000			$ 459,400,000	500,000			90,200,000			0		$ 87,400,000	0			$ 1,900,000	$ 580,400,000	2,400,000		$ 14,500,000		$ 868,800,000	2,100,000			$ 472,400,000	2,200,000			$ 14,500,000	$ 522,500,000	800,000
Revenues	$ 4,372,500,000				$ (128,800,000)	[14]	$ (464,200,000)	$ (2,000,000)	[14]	$ 331,400,000		$ (135,200,000)	[14],[15]	$ 32,000,000		$ 2,200,000	[14]	$ 458,600,000		$ 1,340,200,000		$ 6,100,000	[14]	$ 2,674,500,000		$ 100,000	[14]	$ 826,500,000		$ 0	[16]	$ 461,200,000		$ 0	[16]	444,900,000		$ 0	[16]	$ 0	$ 444,900,000		$ 0		$ 599,200,000			$ 0	[16]		$ 879,100,000		$ 6,000,000	[16]	$ 474,700,000		$ 0	[16]	$ 537,800,000			$ 0	[16]
Revenue from Contract with Customers, Net of Provisions for Refund, Including Assessed Tax																																					$ 87,400,000
Revenues from Related Parties, Net of Provisions for Refund																																				$ 357,500,000

[1]Cash dividends declared per AEP common share were $0.78.[2]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.[3]Includes the elimination of AEPTCo Parent’s equity earnings in the State Transcos.[4]Amounts include affiliated and nonaffiliated revenues.[5]Generation & Marketing includes economic hedge activity.[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]Cash dividends declared per AEP common share were $0.83.[11]Amounts include affiliated and nonaffiliated revenues.[12]Generation & Marketing includes economic hedge activity.[13]Amounts include affiliated and nonaffiliated revenues.[14]Amounts include affiliated and nonaffiliated revenues.[15]Generation & Marketing includes economic hedge activity.[16]Amounts include affiliated and nonaffiliated revenues.

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Millions		Jun. 30, 2023		Dec. 31, 2022
Current Assets
Cash and Cash Equivalents		$ 304.9		$ 509.4
Restricted Cash		45.8		47.1
Other Temporary Investments		202.5		187.6
Accounts Receivable:
Accounts Receivable and Accrued Unbilled Revenues		990.8		1,145.1
Accrued Unbilled Revenues		179.2		322.9
Pledged Accounts Receivable - AEP Credit		1,226.6		1,207.4
Miscellaneous		47.9		49.7
Allowance for Uncollectible Accounts		(58.6)		(57.1)
Total Accounts Receivable		2,385.9		2,668
Fuel		705.9		435.1
Materials and Supplies		975.9		915.1
Risk Management Assets		279.5		348.8
Accrued Tax Benefits		191.8		99.4
Assets Held for Sale		1,382.8		0
Regulatory Asset for Under-Recovered Fuel Costs		1,256.4		1,310
Prepayments and Other Current Assets		309.9		255
TOTAL CURRENT ASSETS		8,041.3		6,775.5
Property, Plant and Equipment
Generation		24,113.5		25,834.2
Transmission		34,145.5		33,266.9
Distribution		28,033.8		27,138.8
Other Property, Plant and Equipment		6,187.6		5,971.8
Construction Work in Progress		5,935.4		4,809.7
Total Property, Plant and Equipment		98,415.8		97,021.4
Accumulated Depreciation and Amortization		23,734.4		23,682.3
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		74,681.4		73,339.1
Other Noncurrent Assets
Regulatory Assets		4,672.8		4,762
Securitized Assets		394.3		446
Spent Nuclear Fuel and Decommissioning Trusts		3,648.8		3,341.2
Goodwill		52.5		52.5
Long-term Risk Management Assets		266.8		284.1
Operating Lease Assets		634.1		645.5
Deferred Charges and Other Noncurrent Assets		3,610.1		3,757.4
TOTAL OTHER NONCURRENT ASSETS		13,279.4		13,288.7
TOTAL ASSETS		96,002.1	[1]	93,403.3
Current Liabilities
Accounts Payable		2,433.9		2,670.8
Short-term Debt:
Securitized Debt for Receivables - AEP Credit	[2]	750		750
Other Short-term Debt		3,117.6		3,362.2
Total Short-term Debt		3,867.6		4,112.2
Long-term Debt Due Within One Year		3,380.3		2,486.4
Risk Management Liabilities		176.2		145.2
Customer Deposits		382.2		408.8
Accrued Taxes		1,366.5		1,714.6
Accrued Interest		402.9		336.5
Obligations Under Operating Leases		116.6		113.6
Liabilities Held for Sale		64.8		0
Other Liabilities, Current		1,076.1		1,278.2
TOTAL CURRENT LIABILITIES		13,267.1		13,266.3
Noncurrent Liabilities
Long-term Debt		36,762		34,314.6
Deferred Income Tax Liabilities, Net		9,157.7		8,896.9
Long-term Risk Management Liabilities		275.3		345.2
Regulatory Liabilities and Deferred Investment Tax Credits		8,121.1		8,115.6
Asset Retirement Obligations		2,879.9		2,879.3
Employee Benefits and Pension Obligations		248.9		257.3
Obligations Under Operating Leases		533.6		552.5
Deferred Credits and Other Noncurrent Liabilities		568.2		607.3
TOTAL NONCURRENT LIABILITIES		58,546.7		55,968.7
TOTAL LIABILITIES		71,813.8		69,235
Rate Matters
Commitments and Contingencies
Contingently Reedemable Performance Share Awards		64.7		45.9
Total Mezzanine Equity		64.7		45.9
Equity
Common Stock		3,421.5		3,413.1
Paid-in Capital		8,110.8		8,051
Retained Earnings		12,405.5		12,345.6
Accumulated Other Comprehensive Income (Loss)		(36.4)		83.7
TOTAL COMMON SHAREHOLDER'S EQUITY		23,901.4		23,893.4
Noncontrolling Interests		222.2		229
TOTAL EQUITY		24,123.6		24,122.4
TOTAL LIABILITIES AND EQUITY		$ 96,002.1		$ 93,403.3
Common Stock, No Par Value		$ 6.50		$ 6.50
Common Stock, Shares Authorized		600,000,000		600,000,000
Common Stock, Shares, Issued		526,387,081		525,099,321
Treasury Stock, Shares		11,233,240		11,233,240
Commodity [Member]
Equity
Cross Default Provisions Maximum Third Party Obligation Amount		$ 50
Subsidiaries [Member]
Current Assets
Restricted Cash		45.8		$ 47.1
Other Temporary Investments		190.9		182.9
Short-term Debt:
Long-term Debt Due Within One Year		196.2		218.2
Noncurrent Liabilities
Long-term Debt		591.3		755.3
AEP Texas Inc. [Member]
Current Assets
Cash and Cash Equivalents		0.1		0.1
Restricted Cash		30.7		32.7
Accounts Receivable:
Accounts Receivable and Accrued Unbilled Revenues		173.2		150.9
Accrued Unbilled Revenues		91.6		91.4
Miscellaneous		0.5		0.2
Allowance for Uncollectible Accounts		(4.9)		(4.2)
Total Accounts Receivable		283.3		250.2
Materials and Supplies		157.3		138.8
Prepayments and Other Current Assets		8.9		18.2
TOTAL CURRENT ASSETS		487.2		446.9
Property, Plant and Equipment
Transmission		6,487.9		6,301.5
Distribution		5,572.7		5,312.8
Other Property, Plant and Equipment		1,098.3		1,022.8
Construction Work in Progress		984.9		805.2
Total Property, Plant and Equipment		14,143.8		13,442.3
Accumulated Depreciation and Amortization		1,829.1		1,760.7
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		12,314.7		11,681.6
Other Noncurrent Assets
Regulatory Assets		326.5		298.3
Securitized Assets		247.8		286.4
Deferred Charges and Other Noncurrent Assets		238.2		179
TOTAL OTHER NONCURRENT ASSETS		812.5		763.7
TOTAL ASSETS		13,614.4		12,892.2
Current Liabilities
Accounts Payable		247.2		331
Short-term Debt:
Long-term Debt Due Within One Year		154.7		278.5
Accrued Taxes		138.7		95.5
Accrued Interest		50.5		48.3
Obligations Under Operating Leases		29.8		28.6
Other Liabilities, Current		132.6		130.7
TOTAL CURRENT LIABILITIES		923.7		1,043.8
Noncurrent Liabilities
Long-term Debt		5,782.8		5,379.3
Deferred Income Tax Liabilities, Net		1,180.3		1,144.2
Regulatory Liabilities and Deferred Investment Tax Credits		1,250.6		1,259.6
Obligations Under Operating Leases		59.2		67.8
Deferred Credits and Other Noncurrent Liabilities		83.2		93.2
TOTAL NONCURRENT LIABILITIES		8,356.1		7,944.1
TOTAL LIABILITIES		9,279.8		8,987.9
Rate Matters
Commitments and Contingencies
Equity
Paid-in Capital		1,829.2		1,558.2
Retained Earnings		2,511.4		2,354.7
Accumulated Other Comprehensive Income (Loss)		(6)		(8.6)
TOTAL EQUITY		4,334.6		3,904.3
TOTAL LIABILITIES AND EQUITY		13,614.4		12,892.2
AEP Texas Inc. [Member] \| Related Party
Current Assets
Advances to Affiliates		6.9		6.9
Accounts Receivable:
Affiliated Companies - Contracts with Customers		22.9		11.9
Current Liabilities
Advances From Affiliates		135.9		96.5
Accounts Payable		34.3		34.7
AEP Texas Inc. [Member] \| AEP Texas Transition Funding and Restoration Funding [Member]
Current Assets
Restricted Cash		30.7		32.7
Other Noncurrent Assets
Securitized Assets		247.8		286.4
Short-term Debt:
Long-term Debt Due Within One Year		94.7		93.5
Accrued Interest		2.1		2.2
Noncurrent Liabilities
Long-term Debt		177		221
AEP Transmission Co [Member]
Current Assets
Cash and Cash Equivalents		0		0
Accounts Receivable:
Accounts Receivable and Accrued Unbilled Revenues		91.1		46.9
Total Accounts Receivable		270.5		166.4
Materials and Supplies		15.5		10.7
Prepayments and Other Current Assets		1.8		7.2
TOTAL CURRENT ASSETS		367.2		188.7
Property, Plant and Equipment
Transmission		12,780		12,335.4
Other Property, Plant and Equipment		489.6		476.8
Construction Work in Progress		1,918.9		1,554.7
Total Property, Plant and Equipment		15,188.5		14,366.9
Accumulated Depreciation and Amortization		1,150.8		1,027
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		14,037.7		13,339.9
Other Noncurrent Assets
Regulatory Assets		5.8		7.2
Deferred Property Taxes		155.9		266.6
Deferred Charges and Other Noncurrent Assets		9.9		11.8
TOTAL OTHER NONCURRENT ASSETS		171.6		285.6
TOTAL ASSETS		14,576.5		13,814.2
Current Liabilities
Accounts Payable		387.4		427.8
Short-term Debt:
Long-term Debt Due Within One Year		60		60
Accrued Taxes		392.4		529.8
Accrued Interest		40.1		28.8
Obligations Under Operating Leases		1.4		1.3
Other Liabilities, Current		12.3		8.3
TOTAL CURRENT LIABILITIES		1,072.9		1,368
Noncurrent Liabilities
Long-term Debt		5,413		4,722.8
Deferred Income Tax Liabilities, Net		1,107.3		1,056.5
Regulatory Liabilities and Deferred Investment Tax Credits		768.9		723.3
Obligations Under Operating Leases		1.8		1.5
Deferred Credits and Other Noncurrent Liabilities		69.8		69.1
TOTAL NONCURRENT LIABILITIES		7,360.8		6,573.2
TOTAL LIABILITIES		8,433.7		7,941.2
Rate Matters
Commitments and Contingencies
Equity
Paid-in Captial		3,038.7		3,022.3
Retained Earnings		3,104.1		2,850.7
TOTAL MEMBER'S EQUITY		6,142.8		5,873
TOTAL LIABILITIES AND EQUITY		14,576.5		13,814.2
AEP Transmission Co [Member] \| Related Party
Current Assets
Advances to Affiliates		79.4		4.4
Accounts Receivable:
Affiliated Companies - Contracts with Customers		179.4		119.5
Current Liabilities
Advances From Affiliates		74.4		229.3
Accounts Payable		104.9		82.7
Appalachian Power Co [Member]
Current Assets
Cash and Cash Equivalents		6.8		7.5
Restricted Cash		15.1		14.4
Accounts Receivable:
Accounts Receivable and Accrued Unbilled Revenues		138.1		168.9
Accrued Unbilled Revenues		35.6		91.3
Miscellaneous		0.5		0.3
Allowance for Uncollectible Accounts		(1.6)		(1.7)
Total Accounts Receivable		294.1		352.8
Fuel		267.1		158.9
Materials and Supplies		136.5		130.6
Risk Management Assets		39.2		69.1
Regulatory Asset for Under-Recovered Fuel Costs		586		473.1
Prepayments and Other Current Assets		28.9		33.4
TOTAL CURRENT ASSETS		1,392.6		1,259.6
Property, Plant and Equipment
Generation		6,903		6,776.8
Transmission		4,536.9		4,482.8
Distribution		5,067.5		4,933
Other Property, Plant and Equipment		922.7		883.3
Construction Work in Progress		790.9		705.3
Total Property, Plant and Equipment		18,221		17,781.2
Accumulated Depreciation and Amortization		5,547		5,402
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		12,674		12,379.2
Other Noncurrent Assets
Regulatory Assets		891.7		1,058.6
Securitized Assets		146.5		159.6
Employee Benefits and Pension Assets		161.9		152.9
Operating Lease Assets		67.9		73.6
Deferred Charges and Other Noncurrent Assets		123.4		138.7
TOTAL OTHER NONCURRENT ASSETS		1,391.4		1,583.4
TOTAL ASSETS		15,458		15,222.2
Current Liabilities
Accounts Payable		324.3		451.2
Short-term Debt:
Long-term Debt Due Within One Year		538.3		251.8
Risk Management Liabilities		1.1		3.6
Customer Deposits		75.3		75.1
Accrued Taxes		101.8		101
Accrued Interest		60		57.9
Obligations Under Operating Leases		14.3		15
Other Liabilities, Current		108.6		109.7
TOTAL CURRENT LIABILITIES		1,604		1,390.2
Noncurrent Liabilities
Long-term Debt		5,061.4		5,158.7
Deferred Income Tax Liabilities, Net		2,007.9		1,992.2
Regulatory Liabilities and Deferred Investment Tax Credits		1,094.5		1,143.6
Asset Retirement Obligations		419.7		419.2
Employee Benefits and Pension Obligations		33.7		34.2
Obligations Under Operating Leases		54		59.1
Deferred Credits and Other Noncurrent Liabilities		49.7		49.6
TOTAL NONCURRENT LIABILITIES		8,720.9		8,856.6
TOTAL LIABILITIES		10,324.9		10,246.8
Rate Matters
Commitments and Contingencies
Equity
Common Stock		260.4		260.4
Paid-in Capital		1,833		1,828.7
Retained Earnings		3,046.5		2,891.1
Accumulated Other Comprehensive Income (Loss)		(6.8)		(4.8)
TOTAL EQUITY		5,133.1		4,975.4
TOTAL LIABILITIES AND EQUITY		$ 15,458		$ 15,222.2
Common Stock, No Par Value		$ 0		$ 0
Common Stock, Shares Authorized		30,000,000		30,000,000
Common Stock, Shares, Outstanding		13,499,500		13,499,500
Appalachian Power Co [Member] \| Related Party
Current Assets
Advances to Affiliates		$ 18.9		$ 19.8
Accounts Receivable:
Affiliated Companies - Contracts with Customers		121.5		94
Current Liabilities
Advances From Affiliates		266.1		182.2
Accounts Payable		114.2		142.7
Indiana Michigan Power Co [Member]
Current Assets
Cash and Cash Equivalents		3.8		4.2
Accounts Receivable:
Accounts Receivable and Accrued Unbilled Revenues		48.9		96.6
Accrued Unbilled Revenues		0.8		0.6
Miscellaneous		6.6		4.7
Allowance for Uncollectible Accounts		(0.1)		(0.1)
Total Accounts Receivable		169.5		205.8
Fuel		85.6		46.5
Materials and Supplies		201.7		188.1
Risk Management Assets		21.4		15.2
Regulatory Asset for Under-Recovered Fuel Costs		17.5		47.1
Prepayments and Other Current Assets		44.1		41.9
TOTAL CURRENT ASSETS		584.1		571.8
Property, Plant and Equipment
Generation		5,598.9		5,585.1
Transmission		1,871.5		1,842.2
Distribution		3,131.7		3,024.7
Other Property, Plant and Equipment		831.6		839.3
Construction Work in Progress		292		253
Total Property, Plant and Equipment		11,725.7		11,544.3
Accumulated Depreciation and Amortization		4,243		4,132.8
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		7,482.7		7,411.5
Other Noncurrent Assets
Regulatory Assets		392.1		459.6
Spent Nuclear Fuel and Decommissioning Trusts		3,648.8		3,341.2
Operating Lease Assets		59.3		64.3
Deferred Charges and Other Noncurrent Assets		273.2		270.5
TOTAL OTHER NONCURRENT ASSETS		4,373.4		4,135.6
TOTAL ASSETS		12,440.2		12,118.9
Current Liabilities
Accounts Payable		220.8		173.4
Short-term Debt:
Long-term Debt Due Within One Year		74.3		341.8
Customer Deposits		50.4		48.6
Accrued Taxes		100.2		103.2
Accrued Interest		42.1		36.9
Obligations Under Operating Leases		16.5		16
Other Liabilities, Current		84.6		105.8
TOTAL CURRENT LIABILITIES		678.2		1,197.1
Noncurrent Liabilities
Long-term Debt		3,389.8		2,919
Deferred Income Tax Liabilities, Net		1,182.6		1,157
Regulatory Liabilities and Deferred Investment Tax Credits		1,909.5		1,702.2
Asset Retirement Obligations		2,064.9		2,027.6
Obligations Under Operating Leases		43.5		48.9
Deferred Credits and Other Noncurrent Liabilities		51		58.8
TOTAL NONCURRENT LIABILITIES		8,641.3		7,913.5
TOTAL LIABILITIES		9,319.5		9,110.6
Rate Matters
Commitments and Contingencies
Equity
Common Stock		56.6		56.6
Paid-in Capital		988.9		988.8
Retained Earnings		2,078.3		1,963.2
Accumulated Other Comprehensive Income (Loss)		(3.1)		(0.3)
TOTAL EQUITY		3,120.7		3,008.3
TOTAL LIABILITIES AND EQUITY		$ 12,440.2		$ 12,118.9
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] \| Related Party
Current Assets
Advances to Affiliates		$ 40.5		$ 23
Accounts Receivable:
Affiliated Companies - Contracts with Customers		113.3		104
Current Liabilities
Advances From Affiliates		0		249.9
Accounts Payable		89.3		121.5
Indiana Michigan Power Co [Member] \| DCC Fuel [Member]
Short-term Debt:
Long-term Debt Due Within One Year		72.1		89.6
Ohio Power Co [Member]
Current Assets
Cash and Cash Equivalents		9.7		9.6
Accounts Receivable:
Accounts Receivable and Accrued Unbilled Revenues		106		119.9
Accrued Unbilled Revenues		0		17.8
Miscellaneous		0.4		0.1
Allowance for Uncollectible Accounts		0		(0.1)
Total Accounts Receivable		232.9		238.6
Materials and Supplies		139.3		109.5
Renewable Energy Credits		28.9		35
Prepayments and Other Current Assets		15.8		21.7
TOTAL CURRENT ASSETS		426.6		414.4
Property, Plant and Equipment
Transmission		3,274		3,198.6
Distribution		6,633.3		6,450.3
Other Property, Plant and Equipment		1,071.3		1,051.4
Construction Work in Progress		651.3		474.3
Total Property, Plant and Equipment		11,629.9		11,174.6
Accumulated Depreciation and Amortization		2,627		2,565.3
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		9,002.9		8,609.3
Other Noncurrent Assets
Regulatory Assets		406.9		327.3
Operating Lease Assets		71		73.8
Deferred Charges and Other Noncurrent Assets		363.3		578.3
TOTAL OTHER NONCURRENT ASSETS		841.2		979.4
TOTAL ASSETS		10,270.7		10,003.1
Current Liabilities
Accounts Payable		322.6		337.3
Short-term Debt:
Long-term Debt Due Within One Year		0		0.1
Risk Management Liabilities		6.3		1.8
Customer Deposits		59.5		96.5
Accrued Taxes		441.8		733.1
Obligations Under Operating Leases		13.5		13.5
Other Liabilities, Current		158.5		154.2
TOTAL CURRENT LIABILITIES		1,228		1,635.5
Noncurrent Liabilities
Long-term Debt		3,365.6		2,970.2
Deferred Income Tax Liabilities, Net		1,123.4		1,101.1
Long-term Risk Management Liabilities		47.7		37.9
Regulatory Liabilities and Deferred Investment Tax Credits		992.6		1,044
Obligations Under Operating Leases		57.8		60.3
Deferred Credits and Other Noncurrent Liabilities		46.8		66
TOTAL NONCURRENT LIABILITIES		5,633.9		5,279.5
TOTAL LIABILITIES		6,861.9		6,915
Rate Matters
Commitments and Contingencies
Equity
Common Stock		321.2		321.2
Paid-in Capital		1,012.8		837.8
Retained Earnings		2,074.8		1,929.1
TOTAL EQUITY		3,408.8		3,088.1
TOTAL LIABILITIES AND EQUITY		$ 10,270.7		$ 10,003.1
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
Ohio Power Co [Member] \| Related Party
Accounts Receivable:
Affiliated Companies - Contracts with Customers		$ 126.5		$ 100.9
Current Liabilities
Advances From Affiliates		72.3		172.9
Accounts Payable		153.5		126.1
Public Service Co Of Oklahoma [Member]
Current Assets
Cash and Cash Equivalents		4.6		4
Accounts Receivable:
Accounts Receivable and Accrued Unbilled Revenues		80.5		70.1
Miscellaneous		0.5		0.8
Total Accounts Receivable		148.1		123.1
Fuel		20.6		11.6
Materials and Supplies		105.8		111.1
Risk Management Assets		44.8		25.3
Accrued Tax Benefits		39		16.1
Regulatory Asset for Under-Recovered Fuel Costs		178.7		178.7
Prepayments and Other Current Assets		22.8		21.6
TOTAL CURRENT ASSETS		564.4		491.5
Property, Plant and Equipment
Generation		2,675.7		2,394.8
Transmission		1,182.7		1,164.4
Distribution		3,309		3,216.4
Other Property, Plant and Equipment		492.7		469.3
Construction Work in Progress		295.2		219.3
Total Property, Plant and Equipment		7,955.3		7,464.2
Accumulated Depreciation and Amortization		2,011		1,837.7
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		5,944.3		5,626.5
Other Noncurrent Assets
Regulatory Assets		570		653.7
Employee Benefits and Pension Assets		70		67.3
Operating Lease Assets		114.9		106.1
Deferred Charges and Other Noncurrent Assets		50.4		20.8
TOTAL OTHER NONCURRENT ASSETS		805.3		847.9
TOTAL ASSETS		7,314		6,965.9
Current Liabilities
Accounts Payable		284.2		202.9
Short-term Debt:
Long-term Debt Due Within One Year		0.6		0.5
Customer Deposits		60		59
Accrued Taxes		60.5		28.7
Obligations Under Operating Leases		9.5		8.9
Other Liabilities, Current		95.5		101.8
TOTAL CURRENT LIABILITIES		663.8		842.7
Noncurrent Liabilities
Long-term Debt		2,383.3		1,912.3
Deferred Income Tax Liabilities, Net		815.7		788.6
Regulatory Liabilities and Deferred Investment Tax Credits		797.1		809.1
Asset Retirement Obligations		81.4		73.5
Obligations Under Operating Leases		108.4		99.3
Deferred Credits and Other Noncurrent Liabilities		18		21.3
TOTAL NONCURRENT LIABILITIES		4,203.9		3,704.1
TOTAL LIABILITIES		4,867.7		4,546.8
Rate Matters
Commitments and Contingencies
Equity
Common Stock		157.2		157.2
Paid-in Capital		1,040.1		1,042.6
Retained Earnings		1,249.2		1,218
Accumulated Other Comprehensive Income (Loss)		(0.2)		1.3
TOTAL EQUITY		2,446.3		2,419.1
TOTAL LIABILITIES AND EQUITY		$ 7,314		$ 6,965.9
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
Public Service Co Of Oklahoma [Member] \| Related Party
Accounts Receivable:
Affiliated Companies - Contracts with Customers		$ 67.1		$ 52.2
Current Liabilities
Advances From Affiliates		68.1		364.2
Accounts Payable		85.4		76.7
Southwestern Electric Power Co [Member]
Current Assets
Cash and Cash Equivalents		4.6		88.4
Accounts Receivable:
Accounts Receivable and Accrued Unbilled Revenues		38.6		38.8
Miscellaneous		16.7		10.4
Total Accounts Receivable		118.9		114.6
Fuel		96.7		81.3
Materials and Supplies		86.3		92.1
Risk Management Assets		28		16.4
Accrued Tax Benefits		43.8		16.5
Regulatory Asset for Under-Recovered Fuel Costs		213.6		353
Prepayments and Other Current Assets		18		47.8
TOTAL CURRENT ASSETS		612.1		812.2
Property, Plant and Equipment
Generation		4,887.9		5,476.2
Transmission		2,536.4		2,479.8
Distribution		2,739.4		2,659.6
Other Property, Plant and Equipment		800		804.4
Construction Work in Progress		516.9		369.5
Total Property, Plant and Equipment		11,480.6		11,789.5
Accumulated Depreciation and Amortization		3,007.7		3,527.3
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		8,472.9		8,262.2
Other Noncurrent Assets
Regulatory Assets		1,147.2		1,042.4
Deferred Charges and Other Noncurrent Assets		313.9		262
TOTAL OTHER NONCURRENT ASSETS		1,461.1		1,304.4
TOTAL ASSETS		10,546.1		10,378.8
Current Liabilities
Accounts Payable		260.2		213.1
Short-term Debt:
Other Short-term Debt		3.9		0
Long-term Debt Due Within One Year		0		6.2
Customer Deposits		71		65.4
Accrued Taxes		118.4		52.8
Accrued Interest		38.9		36
Obligations Under Operating Leases		9.2		8.4
Asset Retirement Obligations		43.7		43.7
Other Liabilities, Current		110.1		129.7
TOTAL CURRENT LIABILITIES		784.7		947.7
Noncurrent Liabilities
Long-term Debt		3,645.6		3,385.4
Deferred Income Tax Liabilities, Net		1,131.9		1,089.7
Regulatory Liabilities and Deferred Investment Tax Credits		766.8		825.7
Asset Retirement Obligations		225.5		237.2
Employee Benefits and Pension Obligations		29.8		29.7
Obligations Under Operating Leases		125		120.2
Deferred Credits and Other Noncurrent Liabilities		41.3		68.4
TOTAL NONCURRENT LIABILITIES		5,965.9		5,756.3
TOTAL LIABILITIES		6,750.6		6,704
Rate Matters
Commitments and Contingencies
Equity
Common Stock		0.1		0.1
Paid-in Capital		1,492.2		1,442.2
Retained Earnings		2,307.6		2,236
Accumulated Other Comprehensive Income (Loss)		(4.5)		(4.2)
TOTAL COMMON SHAREHOLDER'S EQUITY		3,795.4		3,674.1
Noncontrolling Interests		0.1		0.7
TOTAL EQUITY		3,795.5		3,674.8
TOTAL LIABILITIES AND EQUITY		$ 10,546.1		$ 10,378.8
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] \| Related Party
Current Assets
Advances to Affiliates		$ 2.2		$ 2.1
Accounts Receivable:
Affiliated Companies - Contracts with Customers		63.6		65.4
Current Liabilities
Advances From Affiliates		32.6		310.7
Accounts Payable		96.7		81.7
Southwestern Electric Power Co [Member] \| Sabine Mining Co [Member]
Current Assets
Cash and Cash Equivalents		0.2		84.2
Accounts Receivable:
Fuel		0		14.2
Materials and Supplies		4.2		4.2
Property, Plant and Equipment
Other Property, Plant and Equipment		187.8		219.8
Accumulated Depreciation and Amortization		$ 187.8		$ 212.5

[1]Amount includes Assets Held for Sale on the balance sheet. See “Planned Disposition of the Competitive Contracted Renewables Portfolio” section of Note 6 for additional information.[2]Amount of securitized debt for receivables as accounted for under the “Transfers and Servicing” accounting guidance.

Condensed Consolidated Statem_2

Condensed Consolidated Statements of Cash Flows $ in Millions	6 Months Ended
	Jun. 30, 2023 USD ($) $ / shares	Jun. 30, 2022 USD ($)
Operating Activities
Net Income (Loss)	$ 916.5	$ 1,238.9
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	1,517.1	1,595
Deferred Income Taxes	135.8	21.4
Allowance for Equity Funds Used During Construction	(72.3)	(59.6)
Mark-to-Market of Risk Management Contracts	(124.7)	431.4
Property Taxes	202.7	191.6
Deferred Fuel Over/Under-Recovery, Net	342.5	(599.5)
Change in Other Noncurrent Assets	(375.5)	(49.3)
Change in Other Noncurrent Liabilities	(55.4)	144.5
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	277.8	(445.8)
Fuel, Materials and Supplies	(315.1)	(110.5)
Accounts Payable	62.6	484.8
Accrued Taxes, Net	(433.7)	(218.2)
Other Current Assets	(76.6)	69.9
Other Current Liabilities	(232.1)	158.1
Net Cash Flows from (Used for) Operating Activities	1,881.6	2,990.7
Investing Activities
Construction Expenditures	(4,049.7)	(3,138.1)
Purchases of Investment Securities	(1,235.6)	(1,254.8)
Sales of Investment Securities	1,206.3	1,244.9
Acquisitions of Nuclear Fuel	(73.9)	(67.7)
Proceeds from Sale of Property, Plant, and Equipment	1	208.5
Other Investing Activities	32.1	15.5
Net Cash Flows from (Used for) Investing Activities	(4,265.5)	(4,199)
Financing Activities
Issuance of Common Stock	77.6	812.7
Issuance of Long-term Debt	3,958.8	2,639.1
Issuance of Short-term Debt with Original Maturities greater than 90 Days	597.4	271
Change in Short-term Debt with Original Maturities less than 90 Days, Net	(688.2)	(268.9)
Retirement of Long-term Debt	(641.7)	(582.4)
Redemption of Short-term Debt with Original Maturities Greater than 90 Days	(153.8)	(486.1)
Principal Payments for Finance Leases Obligations	(40.6)	(106.2)
Dividends Paid on Common Stock	(863.6)	(803.5)
Other Financing Activities	(67.8)	(97.6)
Net Cash Flows from (Used for) Financing Activities	2,178.1	1,378.1
Net Increase (Decrease) in Cash and Cash Equivalents	(205.8)	169.8
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	556.5	451.4
Cash and Cash Equivalents at Beginning of Period	509.4
Cash, Cash Equivalents and Restricted Cash at End of Period	350.7	621.2
Cash and Cash Equivalents at End of Period	304.9
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	773.5	591.2
Net Cash Paid (Received) for Income Taxes	9.9	95.5
Noncash Acquisitions Under Finance Leases	25.6	13.7
Construction Expenditures Included in Current Liabilities as of March 31,	966.6	849.1
Acquisition of Nuclear Fuel Included in Current Liabilities as of March 31,	(36)	0
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
Kentucky Power Co [Member]
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Loss on the Expected Sale	$ 0	68.8
Flat Ridge II
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Impairment of Equity Method Investment	0	185.5
Competitive Contracted Renewable Portfolio
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Loss on the Expected Sale	112	0
Renewable Energy Facilities
Investing Activities
Acquisitions of Assets	(145.7)	(1,207.3)
AEP Texas Inc. [Member]
Operating Activities
Net Income (Loss)	156.7	159.6
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	225.9	225
Deferred Income Taxes	28.5	24.6
Allowance for Equity Funds Used During Construction	(11.6)	(8)
Mark-to-Market of Risk Management Contracts	0.4	(0.2)
Property Taxes	(60)	(54.8)
Change in Other Noncurrent Assets	(89.7)	(25.9)
Change in Other Noncurrent Liabilities	7.8	32.1
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(33.1)	(70.3)
Fuel, Materials and Supplies	(18.5)	(24.1)
Accounts Payable	1.9	17.9
Accrued Taxes, Net	50.2	34
Other Current Assets	2.9	(0.8)
Other Current Liabilities	(34.4)	31.9
Net Cash Flows from (Used for) Operating Activities	227	341
Investing Activities
Construction Expenditures	(834.2)	(647.6)
Change in Advances to Affiliates, Net	0	(634)
Other Investing Activities	20.2	22.3
Net Cash Flows from (Used for) Investing Activities	(814)	(1,259.3)
Financing Activities
Capital Contributions from Parent	275.3	1.3
Return of Capital to Parent Cash Flows	(4.3)	0
Issuance of Long-term Debt	445.9	1,188.6
Change in Advances from Affiliates, Net	39.4	(26.9)
Retirement of Long-term Debt	(168.2)	(242)
Principal Payments for Finance Leases Obligations	(3.7)	(3.4)
Other Financing Activities	0.6	0
Net Cash Flows from (Used for) Financing Activities	585	917.6
Net Increase (Decrease) in Cash and Cash Equivalents	(2)	(0.7)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	32.8	30.5
Cash and Cash Equivalents at Beginning of Period	0.1
Cash, Cash Equivalents and Restricted Cash at End of Period	30.8	29.8
Cash and Cash Equivalents at End of Period	0.1
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	108.3	88.8
Net Cash Paid (Received) for Income Taxes	0.7	5.9
Noncash Acquisitions Under Finance Leases	2.6	3
Construction Expenditures Included in Current Liabilities as of March 31,	147.2	135.9
AEP Transmission Co [Member]
Operating Activities
Net Income (Loss)	338.4	273.9
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	191.6	168.8
Deferred Income Taxes	42.7	37.3
Allowance for Equity Funds Used During Construction	(39.5)	(30.9)
Property Taxes	110.7	101.4
Provision for Refund Affiliated	13.1	56.4
Change in Other Noncurrent Assets	3.4	1.8
Change in Other Noncurrent Liabilities	1.7	44.3
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(104.1)	(36.7)
Fuel, Materials and Supplies	(4.8)	(2.2)
Accounts Payable	64.6	13.1
Accrued Taxes, Net	(133.3)	(107.6)
Other Current Assets	1.3	0.9
Other Current Liabilities	10.2	(0.9)
Net Cash Flows from (Used for) Operating Activities	482.9	463.2
Investing Activities
Construction Expenditures	(876.1)	(730.9)
Change in Advances to Affiliates, Net	(75)	(109.8)
Other Investing Activities	2.6	(8)
Net Cash Flows from (Used for) Investing Activities	(948.5)	(848.7)
Financing Activities
Capital Contributions from Parent	25	2.8
Return of Capital to Parent Cash Flows	(8.6)	0
Issuance of Long-term Debt	689.1	540.9
Change in Advances from Affiliates, Net	(154.9)	(68.2)
Dividends Paid on Common Stock	(85)	(90)
Net Cash Flows from (Used for) Financing Activities	465.6	385.5
Net Increase (Decrease) in Cash and Cash Equivalents	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	82.8	74
Net Cash Paid (Received) for Income Taxes	32	39.7
Construction Expenditures Included in Current Liabilities as of March 31,	238.4	228.7
Appalachian Power Co [Member]
Operating Activities
Net Income (Loss)	155.4	210.4
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	281.1	288.1
Deferred Income Taxes	(2.8)	17.1
Allowance for Equity Funds Used During Construction	(5.1)	(4.6)
Mark-to-Market of Risk Management Contracts	27.4	(38.5)
Deferred Fuel Over/Under-Recovery, Net	54.2	(312.1)
Change in Other Noncurrent Assets	7.7	(42.3)
Change in Other Noncurrent Liabilities	(39.3)	(0.2)
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	60.4	65.4
Fuel, Materials and Supplies	(113.4)	(75.4)
Increase (Decrease) in Margin Deposits Outstanding	(11.7)	64.5
Accounts Payable	(128.7)	162.8
Accrued Taxes, Net	13.4	(5.7)
Other Current Assets	5.1	0.7
Other Current Liabilities	(20.8)	(0.7)
Net Cash Flows from (Used for) Operating Activities	282.9	329.5
Investing Activities
Construction Expenditures	(558.2)	(450.8)
Change in Advances to Affiliates, Net	0.9	1.4
Other Investing Activities	2.7	23.3
Net Cash Flows from (Used for) Investing Activities	(554.6)	(426.1)
Financing Activities
Capital Contributions from Parent	4.3	2.8
Issuance of Long-term Debt	200	103.3
Change in Advances from Affiliates, Net	83.9	149.9
Retirement of Long-term Debt	(13)	(117.1)
Principal Payments for Finance Leases Obligations	(4.1)	(4)
Dividends Paid on Common Stock	0	(37.5)
Other Financing Activities	0.6	0.2
Net Cash Flows from (Used for) Financing Activities	271.7	97.6
Net Increase (Decrease) in Cash and Cash Equivalents	0	1
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	21.9	20.1
Cash and Cash Equivalents at Beginning of Period	7.5
Cash, Cash Equivalents and Restricted Cash at End of Period	21.9	21.1
Cash and Cash Equivalents at End of Period	6.8
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	125.9	104.9
Net Cash Paid (Received) for Income Taxes	23.4	1
Noncash Acquisitions Under Finance Leases	1.7	0.5
Construction Expenditures Included in Current Liabilities as of March 31,	139.6	121.2
Indiana Michigan Power Co [Member]
Operating Activities
Net Income (Loss)	177.6	156.7
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	236.2	268.6
Deferred Income Taxes	(1.9)	0.3
Amortization (Deferral) of Incremental Nuclear Refueling Outage Expenses, Net	36.7	(38.3)
Allowance for Equity Funds Used During Construction	(2.8)	(5.4)
Mark-to-Market of Risk Management Contracts	(13.7)	(11.6)
Amortization of Nuclear Fuel	50.2	39
Deferred Fuel Over/Under-Recovery, Net	29.6	(17.5)
Change in Other Noncurrent Assets	(7)	3.3
Change in Other Noncurrent Liabilities	(4.6)	22.2
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	37.3	24
Fuel, Materials and Supplies	(52.7)	4.5
Accounts Payable	46.8	13.6
Accrued Taxes, Net	(3)	(2.4)
Other Current Assets	(3.6)	15.2
Other Current Liabilities	(23.4)	(20.1)
Net Cash Flows from (Used for) Operating Activities	501.7	452.1
Investing Activities
Construction Expenditures	(267.1)	(262.5)
Change in Advances to Affiliates, Net	(17.5)	(1)
Purchases of Investment Securities	(1,233.3)	(1,253.2)
Sales of Investment Securities	1,206.3	1,229.9
Acquisitions of Nuclear Fuel	(73.9)	(67.7)
Other Investing Activities	3.3	3
Net Cash Flows from (Used for) Investing Activities	(382.2)	(351.5)
Financing Activities
Capital Contributions from Parent	0.1	1.3
Issuance of Long-term Debt	494.9	72.8
Change in Advances from Affiliates, Net	(249.9)	(42.8)
Retirement of Long-term Debt	(299.2)	(40.7)
Principal Payments for Finance Leases Obligations	(3.8)	(40.1)
Dividends Paid on Common Stock	(62.5)	(50)
Other Financing Activities	0.5	0.4
Net Cash Flows from (Used for) Financing Activities	(119.9)	(99.1)
Net Increase (Decrease) in Cash and Cash Equivalents	(0.4)	1.5
Cash and Cash Equivalents at Beginning of Period	4.2	1.3
Cash and Cash Equivalents at End of Period	3.8	2.8
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	62.1	59.2
Net Cash Paid (Received) for Income Taxes	13.8	(4.9)
Noncash Acquisitions Under Finance Leases	3.2	0.4
Construction Expenditures Included in Current Liabilities as of March 31,	78.1	68.2
Acquisition of Nuclear Fuel Included in Current Liabilities as of March 31,	(36)	0
Ohio Power Co [Member]
Operating Activities
Net Income (Loss)	145.7	158
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	143.4	146.2
Deferred Income Taxes	7.1	13.8
Allowance for Equity Funds Used During Construction	(5.7)	(6.4)
Mark-to-Market of Risk Management Contracts	14.3	(44.3)
Property Taxes	193.9	178.6
Change in Other Noncurrent Assets	(88)	(53.1)
Change in Other Noncurrent Liabilities	(37.7)	44.3
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	8.2	(35.8)
Fuel, Materials and Supplies	(2.5)	(10.1)
Accounts Payable	30.8	78.2
Increase (Decrease) in Contract with Customer, Liability	(37)	142.5
Accrued Taxes, Net	(289.9)	(246.8)
Other Current Assets	2.3	12.2
Other Current Liabilities	(15.3)	35.6
Net Cash Flows from (Used for) Operating Activities	69.6	412.9
Investing Activities
Construction Expenditures	(547.7)	(376.4)
Change in Advances to Affiliates, Net	0	(14)
Other Investing Activities	11.1	12.6
Net Cash Flows from (Used for) Investing Activities	(536.6)	(377.8)
Financing Activities
Capital Contributions from Parent	175	0.7
Issuance of Long-term Debt	395.1	0
Change in Advances from Affiliates, Net	(100.6)	0
Retirement of Long-term Debt	(0.6)	(0.1)
Principal Payments for Finance Leases Obligations	(2.4)	(2.4)
Dividends Paid on Common Stock	0	(30)
Other Financing Activities	0.6	0.6
Net Cash Flows from (Used for) Financing Activities	467.1	(31.2)
Net Increase (Decrease) in Cash and Cash Equivalents	0.1	3.9
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	9.6	3
Cash and Cash Equivalents at Beginning of Period	9.6
Cash, Cash Equivalents and Restricted Cash at End of Period	9.7	6.9
Cash and Cash Equivalents at End of Period	9.7
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	57.6	56.8
Net Cash Paid (Received) for Income Taxes	9.2	21.4
Noncash Acquisitions Under Finance Leases	2.1	1.2
Construction Expenditures Included in Current Liabilities as of March 31,	87.4	92.9
Public Service Co Of Oklahoma [Member]
Operating Activities
Net Income (Loss)	48.7	48.8
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	126	113.2
Deferred Income Taxes	13.1	(20.4)
Allowance for Equity Funds Used During Construction	(2.9)	(1.3)
Mark-to-Market of Risk Management Contracts	(19.3)	(56.2)
Property Taxes	(27.9)	(24.4)
Deferred Fuel Over/Under-Recovery, Net	146.3	(124.2)
Change in Other Regulatory Assets	(57.3)	(4.8)
Change in Other Noncurrent Assets	(22.7)	(12.2)
Change in Other Noncurrent Liabilities	(0.6)	10.4
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(25)	(30.6)
Fuel, Materials and Supplies	(2.6)	(10.8)
Accounts Payable	75.2	123.7
Accrued Taxes, Net	8.9	23.9
Other Current Assets	5.3	(16.8)
Other Current Liabilities	(8.4)	9.9
Net Cash Flows from (Used for) Operating Activities	256.8	37.8
Investing Activities
Construction Expenditures	(263.6)	(200.2)
Acquisitions of Assets	(146)
Other Investing Activities	1.1	2.3
Net Cash Flows from (Used for) Investing Activities	(408.2)	(747.2)
Financing Activities
Capital Contributions from Parent	0	2.2
Return of Capital to Parent Cash Flows	(2.5)	0
Issuance of Long-term Debt	469.8	500
Change in Advances from Affiliates, Net	(296.1)	211.1
Retirement of Long-term Debt	(0.3)	(0.3)
Principal Payments for Finance Leases Obligations	(1.7)	(1.6)
Dividends Paid on Common Stock	(17.5)	0
Other Financing Activities	0.3	0.3
Net Cash Flows from (Used for) Financing Activities	152	711.7
Net Increase (Decrease) in Cash and Cash Equivalents	0.6	2.3
Cash and Cash Equivalents at Beginning of Period	4	1.3
Cash and Cash Equivalents at End of Period	4.6	3.6
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	37.6	38.1
Net Cash Paid (Received) for Income Taxes	(6.1)	12.2
Noncash Acquisitions Under Finance Leases	1.2	1.1
Construction Expenditures Included in Current Liabilities as of March 31,	83.6	41.6
Public Service Co Of Oklahoma [Member] \| Renewable Energy Facilities
Investing Activities
Acquisitions of Assets	(145.7)	(549.3)
Southwestern Electric Power Co [Member]
Operating Activities
Net Income (Loss)	123.1	123.9
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	166.2	156
Deferred Income Taxes	28	(1.4)
Allowance for Equity Funds Used During Construction	(3)	(2.4)
Mark-to-Market of Risk Management Contracts	(11.1)	(36.6)
Property Taxes	(49.3)	(44)
Deferred Fuel Over/Under-Recovery, Net	103.6	(53.6)
Change in Regulatory Assets	(43.8)	0.3
Change in Other Noncurrent Assets	5	45.1
Change in Other Noncurrent Liabilities	(22.4)	10.4
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(4.3)	(34.7)
Fuel, Materials and Supplies	(12.2)	8.7
Accounts Payable	81.2	46.2
Accrued Taxes, Net	39.7	41.3
Other Current Assets	20.5	(7.7)
Other Current Liabilities	(36.5)	(34)
Net Cash Flows from (Used for) Operating Activities	384.7	217.5
Investing Activities
Construction Expenditures	(429.6)	(247)
Change in Advances to Affiliates, Net	(0.1)	153.8
Acquisitions of Assets	0	658
Other Investing Activities	0.8	3.2
Net Cash Flows from (Used for) Investing Activities	(428.9)	(748)
Financing Activities
Capital Contributions from Parent	50	352.2
Issuance of Long-term Debt	346.8	0
Change in Short-term Debt with Original Maturities less than 90 Days, Net	3.9	0
Change in Advances from Affiliates, Net	(278.1)	213.2
Retirement of Long-term Debt	(94.1)	(3.1)
Principal Payments for Finance Leases Obligations	(16.2)	(5.4)
Dividends Paid on Common Stock	(50)	(12.5)
Dividends Paid on Common Stock	(2.1)	(1.5)
Other Financing Activities	0.2	0.1
Net Cash Flows from (Used for) Financing Activities	(39.6)	543
Net Increase (Decrease) in Cash and Cash Equivalents	(83.8)	12.5
Cash and Cash Equivalents at Beginning of Period	88.4	51.2
Cash and Cash Equivalents at End of Period	4.6	63.7
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	48.7	63.6
Net Cash Paid (Received) for Income Taxes	(17.1)	20.1
Noncash Acquisitions Under Finance Leases	2.6	2.8
Construction Expenditures Included in Current Liabilities as of March 31,	$ 85.7	$ 63.3

Significant Accounting Matters

Significant Accounting Matters	6 Months Ended
Significant Accounting Matters	Jun. 30, 2023
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 six months ended June 30, 2023 is not necessarily indicative of results that may be expected for the year ending December 31, 2023. The condensed financial statements are unaudited and should be read in conjunction with the audited 2022 financial statements and notes thereto, which are included in the Registrants’ Annual Reports on Form 10-K as filed with the SEC on February 23, 2023. 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 June 30, 2023 2022 (in millions, except per share data) $/share $/share Earnings Attributable to AEP Common Shareholders $ 521.2 $ 524.5 Weighted-Average Number of Basic AEP Common Shares Outstanding 514.9 $ 1.01 513.6 $ 1.02 Weighted-Average Dilutive Effect of Stock-Based Awards 1.3 — 1.6 — Weighted-Average Number of Diluted AEP Common Shares Outstanding 516.2 $ 1.01 515.2 $ 1.02 Six Months Ended June 30, 2023 2022 (in millions, except per share data) $/share $/share Earnings Attributable to AEP Common Shareholders $ 918.2 $ 1,239.2 Weighted-Average Number of Basic AEP Common Shares Outstanding 514.5 $ 1.78 509.9 $ 2.43 Weighted-Average Dilutive Effect of Stock-Based Awards 1.4 — 1.5 (0.01) Weighted-Average Number of Diluted AEP Common Shares Outstanding 515.9 $ 1.78 511.4 $ 2.42 Equity Units are potentially dilutive securities and were excluded from the calculation of diluted EPS for the three and six months ended June 30, 2023 and 2022, as the dilutive stock price threshold was not met. See Note 12 - Financing Activities for more information related to Equity Units. There were no antidilutive shares outstanding as of June 30, 2023 and 2022, 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: June 30, 2023 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 304.9 $ 0.1 $ 6.8 Restricted Cash 45.8 30.7 15.1 Total Cash, Cash Equivalents and Restricted Cash $ 350.7 $ 30.8 $ 21.9 December 31, 2022 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 509.4 $ 0.1 $ 7.5 Restricted Cash 47.1 32.7 14.4 Total Cash, Cash Equivalents and Restricted Cash $ 556.5 $ 32.8 $ 21.9

New Accounting Standards

New Accounting Standards	6 Months Ended
New Accounting Standards	Jun. 30, 2023
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	6 Months Ended
Comprehensive Income	Jun. 30, 2023
Comprehensive Income	COMPREHENSIVE INCOME The disclosures in this note apply to AEP only. The impact of AOCI is not material to the financial statements of the Registrant Subsidiaries. Presentation of Comprehensive Income The following tables provide AEP’s 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. Cash Flow Hedges Pension Three Months Ended June 30, 2023 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of March 31, 2023 $ 65.3 $ 6.1 $ (139.5) $ (68.1) Change in Fair Value Recognized in AOCI, Net of Tax 5.9 7.0 — 12.9 Amount of (Gain) Loss Reclassified from AOCI Purchased Electricity, Fuel and Other Consumables Used for Electric Generation (a) 28.3 — — 28.3 Interest Expense (a) — (0.5) — (0.5) Amortization of Prior Service Cost (Credit) — — (5.3) (5.3) Amortization of Actuarial (Gains) Losses — — 1.4 1.4 Reclassifications from AOCI, before Income Tax (Expense) Benefit 28.3 (0.5) (3.9) 23.9 Income Tax (Expense) Benefit 6.0 (0.1) (0.8) 5.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 22.3 (0.4) (3.1) 18.8 Net Current Period Other Comprehensive Income (Loss) 28.2 6.6 (3.1) 31.7 Balance in AOCI as of June 30, 2023 $ 93.5 $ 12.7 $ (142.6) $ (36.4) Cash Flow Hedges Pension Three Months Ended June 30, 2022 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of March 31, 2022 $ 404.0 $ (13.6) $ 40.2 $ 430.6 Change in Fair Value Recognized in AOCI, Net of Tax 257.3 2.0 — 259.3 Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (a) 0.1 — — 0.1 Purchased Electricity, Fuel and Other Consumables Used for Electric Generation (a) (161.8) — — (161.8) Interest Expense (a) — 1.1 — 1.1 Amortization of Prior Service Cost (Credit) — — (5.4) (5.4) Amortization of Actuarial (Gains) Losses — — 2.1 2.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit (161.7) 1.1 (3.3) (163.9) Income Tax (Expense) Benefit (34.0) 0.3 (0.7) (34.4) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (127.7) 0.8 (2.6) (129.5) 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) 129.6 2.8 (11.6) 120.8 Balance in AOCI as of June 30, 2022 $ 533.6 $ (10.8) $ 28.6 $ 551.4 Cash Flow Hedges Pension Six Months Ended June 30, 2023 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2022 $ 223.5 $ 0.3 $ (140.1) $ 83.7 Change in Fair Value Recognized in AOCI, Net of Tax (189.4) 12.2 (12.9) (190.1) Amount of (Gain) Loss Reclassified from AOCI Purchased Electricity, Fuel and Other Consumables Used for Electric Generation (a) 75.3 — — 75.3 Interest Expense (a) — 0.2 — 0.2 Amortization of Prior Service Cost (Credit) — — (10.6) (10.6) Amortization of Actuarial (Gains) Losses — — 2.6 2.6 Reclassifications from AOCI, before Income Tax (Expense) Benefit 75.3 0.2 (8.0) 67.5 Income Tax (Expense) Benefit 15.9 — (1.7) 14.2 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 59.4 0.2 (6.3) 53.3 Reclassifications of KPCo Pension and OPEB Regulatory Assets from AOCI — — 21.1 21.1 Income Tax (Expense) Benefit — — 4.4 4.4 Reclassifications of KPCo Pension and OPEB Regulatory Assets from AOCI, Net of Income Tax (Expense) Benefit — — 16.7 16.7 Net Current Period Other Comprehensive Income (Loss) (130.0) 12.4 (2.5) (120.1) Balance in AOCI as of June 30, 2023 $ 93.5 $ 12.7 $ (142.6) $ (36.4) Cash Flow Hedges Pension Six Months Ended June 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, Net of Tax 535.5 8.8 — 544.3 Amount of (Gain) Loss Reclassified from AOCI Purchased Electricity, Fuel and Other Consumables Used for Electric Generation (a) (209.7) — — (209.7) Interest Expense (a) — 2.2 — 2.2 Amortization of Prior Service Cost (Credit) — — (10.3) (10.3) Amortization of Actuarial (Gains) Losses — — 4.2 4.2 Reclassifications from AOCI, before Income Tax (Expense) Benefit (209.7) 2.2 (6.1) (213.6) Income Tax (Expense) Benefit (44.1) 0.5 (1.3) (44.9) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (165.6) 1.7 (4.8) (168.7) 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) 369.9 10.5 (13.8) 366.6 Balance in AOCI as of June 30, 2022 $ 533.6 $ (10.8) $ 28.6 $ 551.4 (a) Amounts reclassified to the referenced line item on the statements of income.

Rate Matters

Rate Matters	6 Months Ended
Rate Matters	Jun. 30, 2023
Rate Matters	RATE MATTERS The disclosures in this note apply to all Registrants unless indicated otherwise. As discussed in the 2022 Annual Report, the Registrants are involved in rate and regulatory proceedings at the FERC and their state commissions. The Rate Matters note within the 2022 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 2023 and updates the 2022 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 is not deemed recoverable, it could reduce future net income and cash flows and impact financial condition. Regulated Generating Units that have been Retired SWEPCo 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 through 2046, 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 through 2027, 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. As part of the 2020 Louisiana Base Rate Case, the LPSC authorized the recovery of SWEPCo’s Louisiana share of the Dolet Hills Power Station, through a separate rider, through 2032, but did not rule on the prudency of the early retirement of the plant, which is being addressed in a separate proceeding. See “2020 Texas Base Rate Case” and “2020 Louisiana Base Rate Case” sections below for additional information. In March 2023, the Pirkey Plant was retired. As part of the 2020 Louisiana Base Rate Case, the LPSC authorized the recovery of SWEPCo’s Louisiana jurisdictional share of the Pirkey Plant, through a separate rider, through 2032. As part of the 2021 Arkansas Base Rate Case, the APSC granted SWEPCo regulatory asset treatment. SWEPCo will request recovery including a weighted average cost of capital carrying charge through a future proceeding. The Texas jurisdictional share of the Pirkey Plant will be addressed in SWEPCo’s next base rate case. 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 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 June 30, 2023, 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 $ 120.5 $ 154.9 $ 20.4 (b) 2026 (c) $ 14.9 Welsh Plant, Units 1 and 3 384.3 105.4 58.2 (d) 2028 (e) (f) 38.6 (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 the removal of Northeastern Plant, Unit 3, after retirement. (c) Northeastern Plant, Unit 3 is currently being recovered through 2040. (d) Includes Welsh Plant, Unit 2, which was retired in 2016. Removal of Welsh Plant, Unit 2, will be performed with the removal of Welsh Plant, Units 1 and 3, after retirement. (e) Represents projected retirement date of coal assets, units are being evaluated for conversion to natural gas after 2028. (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 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 rate riders. As of June 30, 2023, SWEPCo’s share of the net investment in the Dolet Hills Power Station was $108 million, including materials and supplies, net of cost of removal collected in rates. Fuel costs incurred by the Dolet Hills Power Station are recoverable by SWEPCo through active fuel clauses 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 June 30, 2023, SWEPCo had a net under-recovered fuel balance of $120 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 $34 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 $34 million deferral, with refunds to customers over five years. In September 2022, SWEPCo filed rebuttal testimony addressing the LPSC staff recommendations and a hearing was held in May 2023. 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 June 2023, an unopposed settlement agreement was filed with the PUCT that would provide recovery of $48 million of Oxbow mine related costs through 2035. A decision from the PUCT on the unopposed settlement agreement is expected in the fourth quarter of 2023. 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 March 2023, the Pirkey Plant was retired. SWEPCo is recovering, or will seek recovery of, the remaining net book value of Pirkey Plant non-fuel costs. As of June 30, 2023, SWEPCo’s share of the net investment in the Pirkey Plant was $177 million, including materials and supplies, net of cost of removal. See the “Regulated Generating Units that have been Retired” section above for additional information. Fuel costs are recovered through active fuel clauses and are subject to prudency determinations by the various commissions. As of March 31, 2023, SWEPCo fuel deliveries, including billings of all fixed costs, from Sabine ceased. Additionally, as of June 30, 2023, SWEPCo had a net under-recovered fuel balance of $120 million, inclusive of costs related to the Pirkey Plant billed by Sabine, but excluding impacts of the February 2021 severe winter weather event. Remaining operational, reclamation and other land-related costs incurred by Sabine will be billed to SWEPCo and included in existing fuel clauses. In June 2023, an unopposed settlement agreement was filed with the PUCT that would provide recovery of $33 million of Sabine related fuel costs through 2035. In July 2023, Texas ALJs issued a proposal for decision that concluded the decision to retire the Pirkey Plant was prudent. A decision from the PUCT on the unopposed settlement agreement and the Texas ALJ proposal for decision is expected in the second half of 2023. Additionally in July 2023, the LPSC ordered that a separate proceeding be established to review the prudence of the decision to retire the Pirkey Plant, including the costs included in fuel for years starting in 2019 and after. 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 June 30, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Pirkey Plant Accelerated Depreciation $ 111.8 $ 116.5 Unrecovered Winter Storm Fuel Costs (a) 109.5 121.7 Welsh Plant, Units 1 and 3 Accelerated Depreciation 105.4 85.6 Dolet Hills Power Station Fuel Costs - Louisiana 33.9 32.0 Texas Mobile Generation Costs 29.4 17.6 Other Regulatory Assets Pending Final Regulatory Approval 21.4 19.3 Regulatory Assets Currently Not Earning a Return Storm-Related Costs (b)(c)(d) 395.4 407.2 2020-2022 Virginia Triennial Under-Earnings 35.0 37.9 Plant Retirement Costs – Asset Retirement Obligation Costs 25.9 25.9 Other Regulatory Assets Pending Final Regulatory Approval 49.3 55.6 Total Regulatory Assets Pending Final Regulatory Approval $ 917.0 $ 919.3 (a) Includes $37 million and $37 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of June 30, 2023 and December 31, 2022, respectively. See the “February 2021 Severe Winter Weather Impacts in SPP” section below for additional information. (b) In April 2023, OPCo filed a request with the PUCO for recovery of $34 million in Ohio storm-related costs. (c) In April 2023, the LPSC issued an order approving the prudence and future recovery of the Louisiana storm-related regulatory assets. See “2021 Louisiana Storm Cost Filing” section below for additional information. (d) In June 2023, storms in the Oklahoma, Louisiana and Texas service territories caused power outages and extensive damage resulting in the deferral of $52 million, $28 million and $20 million, respectively. Recovery of these storm costs will be addressed in a future request. AEP Texas June 30, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Texas Mobile Generation Costs $ 29.4 $ 17.6 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 34.9 26.7 Vegetation Management Program 5.2 5.2 Texas Retail Electric Provider Bad Debt Expense 4.1 4.1 Other Regulatory Assets Pending Final Regulatory Approval 13.6 13.4 Total Regulatory Assets Pending Final Regulatory Approval $ 87.2 $ 67.0 APCo June 30, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return COVID-19 – Virginia $ 7.2 $ 7.0 Regulatory Assets Currently Not Earning a Return Storm-Related Costs - West Virginia 72.0 72.6 2020-2022 Virginia Triennial Under-Earnings 35.0 37.9 Plant Retirement Costs – Asset Retirement Obligation Costs 25.9 25.9 Other Regulatory Assets Pending Final Regulatory Approval 5.5 1.1 Total Regulatory Assets Pending Final Regulatory Approval $ 145.6 $ 144.5 I&M June 30, December 31, 2023 2022 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 Storm-Related Costs - Indiana 23.9 21.6 Other Regulatory Assets Pending Final Regulatory Approval 2.7 2.0 Total Regulatory Assets Pending Final Regulatory Approval $ 26.7 $ 23.7 OPCo June 30, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Not Earning a Return Storm-Related Costs (a) $ 52.7 $ 33.8 Other Regulatory Assets Pending Final Regulatory Approval 0.1 — Total Regulatory Assets Pending Final Regulatory Approval $ 52.8 $ 33.8 (a) In April 2023, OPCo filed a request with the PUCO for recovery of $34 million in storm costs. PSO June 30, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Not Earning a Return Storm-Related Costs (a) $ 84.6 $ 25.5 Other Regulatory Assets Pending Final Regulatory Approval 0.2 0.1 Total Regulatory Assets Pending Final Regulatory Approval $ 84.8 $ 25.6 (a) In June 2023, storms caused power outages and extensive damage to the Oklahoma service territory, resulting in the deferral of $52 million. Recovery for these storm costs will be included in a future request. SWEPCo June 30, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Pirkey Plant Accelerated Depreciation $ 111.8 $ 116.5 Unrecovered Winter Storm Fuel Costs (a) 109.5 121.7 Welsh Plant, Units 1 and 3 Accelerated Depreciation 105.4 85.6 Dolet Hills Power Station Fuel Costs - Louisiana 33.9 32.0 Dolet Hills Power Station 12.1 9.7 Other Regulatory Assets Pending Final Regulatory Approval 1.9 2.5 Regulatory Assets Currently Not Earning a Return Storm-Related Costs (b)(c) 48.0 151.5 Asset Retirement Obligation - Louisiana — 11.8 Other Regulatory Assets Pending Final Regulatory Approval 15.9 16.0 Total Regulatory Assets Pending Final Regulatory Approval $ 438.5 $ 547.3 (a) Includes $37 million and $37 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of June 30, 2023 and December 31, 2022, respectively. See the “February 2021 Severe Winter Weather Impacts in SPP” section below for additional information. (b) In April 2023, the LPSC issued an order approving the prudence and future recovery of the Louisiana storm-related regulatory assets. See “2021 Louisiana Storm Cost Filing” section below for additional information. (c) In June 2023, additional storms in the Louisiana and Texas service territories caused power outages and extensive damage resulting in the deferral of $28 million and $20 million, respectively. Recovery of these storm costs will be addressed in a future request. 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 June 30, 2023, AEP Texas’ cumulative revenues from interim base rate increases that are subject to review is approximately $791 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) 2020-2022 Virginia Triennial Review In March 2023, APCo submitted its 2020-2022 Virginia triennial review filing and base rate case with the Virginia SCC as required by state law. APCo requested a $213 million annual increase in Virginia base rates based upon a proposed 10.6% return on common equity. The requested annual increase includes $47 million related to vegetation management and a $35 million increase in depreciation expense. The requested increase in depreciation expense reflects, among other things, the impacts of incremental investments made since APCo’s last depreciation study using property balances as of December 31, 2022. Effective January 1, 2023 and in accordance with past Virginia SCC directives, APCo implemented updated Virginia depreciation rates. APCo’s proposed revenue requirement also includes the recovery of certain costs incurred that partially contributed to APCo’s calculated earnings shortfall for the 2020-2022 triennial 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 certain categories of costs, including major storm costs for severe weather events. As of June 30, 2023, APCo deferred approximately $35 million related to previously incurred major storm costs as a result of APCo’s calculation of Virginia earnings below the bottom of its authorized ROE band during the 2020-2022 Triennial Review period. In July 2023, intervening parties submitted testimony recommending a $69 million annual Virginia base rate increase based on the following significant adjustments: (a) a 9.2% ROE, (b) a $36 million decrease in depreciation expense using a 2040 estimated Amos Plant retirement date for Virginia ratemaking purposes rather than the 2032/2033 retirement date requested by APCo, (c) the removal of $40 million of APCo’s requested increase in vegetation management expense, (d) the removal of $23 million in major storm expenses incurred during the 2020-2022 triennial period, and (e) the removal of $15 million of forecasted spending related to boiler maintenance and generation consumables expense. Virginia staff testimony is due in the third quarter of 2023 and a Virginia SCC order will be issued in the fourth quarter of 2023. Any APCo Virginia jurisdictional costs that are not recoverable or any refunds of revenues collected from customers during the triennial review period that are ordered by the Virginia SCC for the 2020-2022 Triennial Review period could reduce future net income and cash flows and impact financial condition. ENEC (Expanded Net Energy Cost) Filings In April 2021, APCo and WPCo (the Companies) requested a combined $73 million annual increase in ENEC rates based on a cumulative $55 million ENEC under-recovery as of February 28, 2021 and an $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. In February 2023, the WVPSC issued an order stating that the commission will not grant additional rate increases for fuel costs until the WVPSC staff completes its prudency review. In April 2023, the Companies submitted their 2023 annual ENEC filing with the WVPSC, proposing two alternatives to increase ENEC rates effective September 1, 2023. The first alternative is a $293 million annual increase in ENEC rates comprised of an $89 million increase for current year ENEC expense and a $200 million annual increase for the recovery of the Companies’ February 28, 2023 ENEC under-recovery balances over three years, including debt and equity carrying costs. The second alternative is an $89 million annual increase in ENEC rates with the Companies securitizing approximately $1.9 billion of assets, including: (a) $553 million relating to ENEC under-recoveries as of February 28, 2023, (b) $88 million relating to major storm expense deferrals and (c) $1.2 billion relating to APCo’s West Virginia jurisdictional book values of the Amos and Mountaineer Plants and forecasted CCR and ELG investments at these generating facilities. The Companies continue to reflect ENEC under-recovery balances as current on their balance sheets since management cannot assert whether the WVPSC will approve recovery of ENEC under-recovery balances over a time frame different from the traditional one-year period. Additionally, in April 2023, the Staff submitted the prudency review prepared by an independent consultant retained by the WVPSC staff of the Companies’ operation of the Amos, Mountaineer and Mitchell coal plants that Staff was directed to conduct by the WVPSC in May 2022 (Consultant’s Report). The Consultant’s Report states the opinion of the consultant that the Companies acted imprudently by not taking steps to achieve a 69% capacity factor at their coal-fired plants and recommends applying a disallowance factor of 52.9% to the Companies’ cumulative, September 30, 2022 ENEC under-recovery balance of approximately $430 million. The Consultant’s Report further states the consultant’s opinion that this disallowance factor could also be utilized in future ENEC filings. Adoption of the Consultant’s Report’s findings by the WVPSC could result in a disallowance of up to $285 million. The Companies disagree with the conclusions and recommendations contained in the Consultant’s Report and intend to dispute them in the appropriate proceedings before the WVPSC. In May 2023, the WVPSC established a procedural schedule for the 2021, 2022 and 2023 ENEC cases to begin in the third quarter of 2023, including APCo’s response to the independent consultant’s prudency review. If any deferred ENEC 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 June 30, 2023, AEP’s share of ETT’s cumulative revenues that are subject to review is approximately $1.6 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, 2025, during which the $1.6 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) In April 2023, I&M received intervenor testimony in I&M’s 2021 PSCR Reconciliation for the 12-month period ending December 31, 2021 recommending disallowances of purchased power costs of $18 million associated with the OVEC Inter-Company Power Agreement (ICPA) and the AEGCo Unit Power Agreement (UPA) that were alleged to be above market in applying the MPSC’s Code of Conduct rules. Michigan staff submitted testimony in I&M’s 2021 PSCR Reconciliation with no recommended disallowances for PSCR costs incurred, including those associated with the OVEC ICPA and the AEGCo UPA. Michigan staff also recommended several options to address I&M’s shortfall in achieving Michigan’s annual one percent energy waste reduction savings level, resulting in potential future disallowed costs of up to approximately $14 million. In June 2023, Michigan staff submitted rebuttal testimony to update their calculation of the 2021 market proxy price resulting in a recommended disallowance of approximately $1 million related to the OVEC ICPA. An MPSC order on I&M’s 2021 PSCR Reconciliation is expected in the fourth quarter of 2023. If any PSCR costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. KPCo Rate Matters (Applies to AEP) Fuel Adjustment Clause (FAC) Purchased Power Limitation In May 2023, KPCo filed an application seeking authority to defer, for future recovery, approximately $12 million of December 2022 purchased power costs not recoverable through its FAC. This requested deferral accounting authority would have enabled KPCo to pursue securitization of these costs. In June 2023, the KPSC denied KPCo’s request for deferral accounting authority. Also in June 2023, following its order denying KPCo’s request for deferral accounting authority, the KPSC issued an order directing KPCo to show cause why it should not be subject to Kentucky statutory remedies, including fines and penalties, for failure to provide adequate service in its service territory. The KPSC’s show cause order did not make any determination regarding the adequacy of KPCo’s service. In July 2023, KPCo filed a response to the show cause order demonstrating that it has provided adequate service. KPCo is requesting a prudency determination and recovery mechanism for these costs in its 2023 base rate. Unless and until KPCo is granted a recovery mechanism for these purchased power costs from the KPSC it will impact cash flows and financial condition. Additionally, if any fines or penalties are levied against KPCo relating to the show cause order, it will reduce net income and cash flows and impact financial condition. 2023 Kentucky Base Rate and Securitization Case In June 2023, KPCo filed a request with the KPSC for a $94 million net annual increase in base rates based upon a proposed 9.9% ROE with the increase to be implemented no earlier than January 2024. The filing proposes no changes in depreciation rates and an annual level of storm restoration expense in base rates of approximately $1 million. KPCo also proposed to discontinue tracking of PJM transmission costs through a rider, and to instead collect an annual level of costs through base rates. In addition, KPCo has proposed a rider to recover certain distribution reliability investments and related incremental operation and maintenance expenses. KPCo also requested a prudency determination and recovery mechanism for approximately $16 million of purchased power costs not recoverable through its FAC since its last base case. In conjunction with its June 2023 filing, KPCo further requested to finance, through the issuance of securitization bonds, approximately $471 million of regulatory assets recorded as of June 2023 including: (a) $289 million of plant retirement costs, (b) $79 million of deferred storm costs related to 2020, 2021, 2022 and 2023 major storms, (c) $52 million of deferred purchased power expenses and (d) $51 million of under-recovered purchased power rider costs. Plant retirement costs and deferred purchased power expenses have been deemed prudent in prior KPSC decisions. KPCo has requested a prudency determination for the deferred storm costs and under-recovered purchase power rider costs since the last base case in this proceeding. Consistent with Kentucky statutory requirements, the present value of the return on accumulated deferred income tax benefits related to plant retirement costs and deferred purchase power expenses were proposed to reduce the amount authorized to be financed through securitization. Intervenor testimony is due in the third quarter of 2023 and an order from the KPSC is expected in January 2024. If any of these costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. OPCo Rate Matters (Applies to AEP and OPCo) OVEC Cost Recovery Audits In December 2021, as part of OVEC cost recovery audits pending before the PUCO, intervenors filed positions claiming that costs incurred by OPCo during the 2018-2019 audit period were imprudent and should be disallowed. In May 2022, intervenors filed for rehearing on the 2016-2017 OVEC cost recovery audit period claiming the PUCO’s April 2022 order to adopt the findings of the audit report were unjust, unlawful and unreasonable for multiple reasons, including the position that OPCo recovered imprudently incurred costs. In June 2022, the PUCO granted rehearing on the 2016-2017 audit period for purposes of further consideration. Management disagrees with these claims and is unable to predict the impact of these disputes, however, if any costs are disallowed or refunds are ordered it could reduce future net income and cash flows and impact financial condition. See "OVEC" section of Note 17 in the 2022 Annual Report for additional information on AEP and OPCo’s investment in OVEC. Ohio ESP Filings In January 2023, OPCo filed an application with the PUCO to approve an ESP that included proposed rate adjustments, proposed new riders and the continuation and modification of certain existing riders, including the Distribution Investment Rider, effective June 2024 through May 2030. The proposal includes a return on common equity of 10.65% on capital costs for certain riders. In June 2023, intervenors filed testimony opposing OPCo’s plan for various new riders and modifications to existing riders, including the DIR. Staff testimony and a hearing is expected in the third quarter of 2023. If OPCo is ultimately not permitted to fully collect its ESP rates it could reduce future net income and cash flows and impact financial condition. PSO Rate Matters (Applies to AEP and PSO) 2022 Oklahoma Base Rate Case In November 2022, PSO filed a request with the OCC for a $173 million annual increase in rates based upon a 10.4% ROE with a capital structure of 45.4% debt and 54.6% common equity, net of existing rider revenues and certain incremental renewable facility benefits expected to be provided to customers through riders. The requested annual revenue increase includes a $47 million annual depreciation expense increase related to the accelerated depreciation recovery of the Northeastern Plant, Unit 3 through 2026, and a $16 million annual amortization expense increase to recover intangible plant over a 5-year useful life instead of a 10-year useful life. PSO’s request also includes recovery of the 154 MW Rock Falls Wind Facility through base rates to aid PSO’s near-term capacity needs and support compliance with SPP’s 2023 increased capacity planning reserve margin requirements. In N

Commitments, Guarantees and Con

Commitments, Guarantees and Contingencies	6 Months Ended
Commitments, Guarantees and Contingencies	Jun. 30, 2023
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 2022 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 2025, respectively, under which up to $1.2 billion may be issued as letters of credit on behalf of subsidiaries. As of June 30, 2023, 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 six uncommitted facilities totaling $450 million. The Registrants’ maximum future payments for letters of credit issued under the uncommitted facilities as of June 30, 2023 were as follows: Company Amount Maturity (in millions) AEP $ 288.8 July 2023 to June 2024 AEP Texas 1.8 July 2023 Guarantees of Equity Method Investees (Applies to AEP) Parent has issued guarantees over the performance of certain non-consolidated joint ventures included within the competitive contracted renewables portfolio and NM Renewable Development, LLC. 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 June 30, 2023, the maximum potential amount of future payments associated with the remaining guarantees was $78 million, with the last guarantee expiring in December 2045. The non-contingent liability recorded associated with these guarantees was $5 million, with an additional $1 million 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 June 30, 2023, 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 June 30, 2023, 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 $ 45.0 AEP Texas 10.9 APCo 5.6 I&M 4.2 OPCo 7.0 PSO 4.7 SWEPCo 5.4 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 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 U. S. District Court for the Southern District of Ohio against AEP and certain of its officers for alleged violations of securities laws. 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 U.S. 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 substantive and forum-based motions to dismiss on April 29, 2022. On September 13, 2022, the New York state court granted the forum-based motion to dismiss with prejudice and the plaintiff subsequently filed a notice of appeal with the New York appellate court. On January 20, 2023, the New York plaintiff filed a motion to intervene in the pending Ohio federal court action and withdrew his appeal in New York. 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 the amended complaint and subsequently filed a brief in opposition to the New York plaintiffs’ motion to intervene in the consolidated action in Ohio. On March 20, 2023, the federal district court issued an order granting the motion to dismiss with prejudice and denying the New York plaintiffs’ motion to intervene. On April 20, 2023, one of the plaintiffs filed a notice of appeal to the U.S. Court of Appeals for the Sixth Circuit of the Ohio federal district court order dismissing the consolidated action and denying the intervention. On June 15, 2022, the Ohio state court entered an order continuing the stays of that case until the final 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 was directed to the Board of Directors of AEP (AEP Board) and contained factual allegations involving HB 6 that were generally consistent with those in the derivative litigation filed in state and federal court. The shareholder that sent the letter has since withdrawn the litigation demand, which is now terminated and of no further effect. In April 2023, AEP received a litigation demand from counsel representing the purported AEP shareholder who filed the dismissed derivative action in New York state court and unsuccessfully tried to intervene in the consolidated derivative actions in Ohio federal court. The litigation demand letter is directed to the AEP Board 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 certain current and former directors and officers, and that AEP commence a civil action for breaches of fiduciary duty and related claims against any individuals who allegedly harmed AEP. The AEP Board will act in response to the letter as appropriate. Management is unable to determine a range of potential losses that is reasonably possible of occurring. In May 2021, AEP received a subpoena from the SEC’s Division of Enforcement seeking various documents, including documents relating to the 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 investigation. AEP is cooperating fully with the SEC’s investigation, which has included taking testimony from certain individuals and inquiries regarding Empowering Ohio’s Economy, Inc., which is a 501(c)(4) social welfare organization, and related disclosures. Although the outcome of the SEC’s investigation cannot be predicted, management does not believe the results of this investigation will have a material impact on financial condition, results of operations or cash flows. Claims for Indemnification Made by Owners of the Gavin Power Station In November 2022, the Federal EPA issued a final decision denying Gavin Power LLC’s requested extension to allow a CCR surface impoundment at the Gavin Power Station to continue to receive CCR and non-CCR waste streams after April 11, 2021 until May 4, 2023 (the Gavin Denial). As part of the Gavin Denial, the Federal EPA made several determinations related to the CCR Rule (see “Environmental Issues - Coal Combustion Residual (CCR) Rule” section of Management’s Discussion and Analysis of Financial Condition and Results of Operations for additional information), including a determination that the closure of the 300 acre unlined fly ash reservoir (FAR) is noncompliant with the CCR Rule in multiple respects. The Gavin Power Station was formerly owned and operated by AEP and was sold to Gavin Power LLC and Lightstone Generation LLC in 2017. Pursuant to the PSA, AEP maintained responsibility to complete closure of the FAR in accordance with the closure plan approved by the Ohio EPA which was completed in July 2021. The PSA contains indemnification provisions, pursuant to which the owners of the Gavin Power Station have notified AEP they believe they are entitled to indemnification for any damages that may result from these claims, including any future enforcement or litigation resulting from the Federal EPA’s determinations of noncompliance with various aspects of the CCR Rule as part of the Gavin Denial. The owners of the Gavin Power Station have also sought indemnification for landowner claims for property damage allegedly caused by modifications to the FAR. Management does not believe that the owners of the Gavin Power Station have any valid claim for indemnity or otherwise against AEP under the PSA. In addition, Gavin Power LLC, several AEP subsidiaries, and other parties have filed Petitions for Review of the Gavin Denial with the U.S. Court of Appeals for the District of Columbia Circuit. Management is unable to determine a range of potential losses that is reasonably possible of occurring. Claims for Damages Related to Sabine Lignite Mining Agreement In May 2023, North American Coal Corporation (NACC) and Sabine, a subsidiary of NACC, filed suit against SWEPCo in Texas state court for breach of the Lignite Mining Agreement (LMA) between Sabine and SWEPCo. NACC and Sabine assert that the terms of the LMA require SWEPCo to continue operating the Pirkey Plant and obtaining coal from the Sabine mine through 2035 and that SWEPCo has breached the agreement by closing the plant. The complaint seeks both injunctive relief ordering SWEPCo to cease demolition and reclamation activities at the Pirkey Plant and the Sabine mine and damages, which Sabine has asserted are $85 million in lost fees. The parties have entered into a standstill agreement staying both the litigation and certain demolition and reclamation activities at the Pirkey Plant and the Sabine mine. SWEPCo will continue to defend against the claims. Management is unable to determine a range of potential losses that is reasonably possible of occurring.

Acquisitions and Dispositions

Acquisitions and Dispositions	6 Months Ended
Acquisitions and Dispositions	Jun. 30, 2023
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 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. 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 until the 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 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. PSO and SWEPCo apply the joint plant accounting model to account for their respective undivided interests in the assets, liabilities, revenues and expenses of the NCWF projects. Rock Falls Wind Facility (Vertically Integrated Utilities Segment) (Applies to AEP and PSO) In November 2022, PSO entered into an agreement to acquire the Rock Falls Wind Facility. In February 2023, the FERC approved PSO’s acquisition of the Rock Falls Wind Facility under Section 203 of the Federal Power Act. In March 2023, PSO acquired an ownership interest in the entity that owned Rock Falls during its development and construction for $146 million. In accordance with the guidance for “Business Combinations,” management determined that the acquisition of the Rock Falls Wind Facility represents an asset acquisition. The current and noncurrent Obligations Under Operating Leases related to Rock Falls were not material as of June 30, 2023. See the “2022 Oklahoma Base Rate Case” section of Note 4 for additional information. ASSETS AND LIABILITIES HELD FOR SALE Termination of Planned 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. The SPA was subsequently amended in September 2022 to reduce the purchase price to approximately $2.646 billion. The sale required approval from the KPSC and from the FERC under Section 203 of the Federal Power Act. The SPA contained certain termination rights if the closing of the sale did not occur by April 26, 2023. In May 2022, the KPSC approved the sale of KPCo to Liberty subject to certain conditions contingent upon the closing of the sale. In December 2022, the FERC issued an order denying, without prejudice, authorization of the proposed sale stating the applicants failed to demonstrate the proposed transaction will not have an adverse effect on rates. In February 2023, a new filing for approval under Section 203 of the Federal Power Act was submitted. In March 2023, the KPSC and other intervenors made filings recommending the FERC reject AEP and Liberty’s new Section 203 application seeking approval of the sale. In April 2023, AEP, AEPTCo and Liberty entered into a Mutual Termination Agreement (Termination Agreement) terminating the SPA. The parties entered into the Termination Agreement as all of the conditions precedent to closing the sale could not be satisfied prior to April 26, 2023. The impact of the Termination Agreement did not have a material impact on AEP’s statements of income for the three and six months ended June 30, 2023. Upon reverting to a held and used model in the first quarter of 2023, AEP was required to present its investment in the Kentucky Operations at the lower of fair value or historical carrying value which resulted in a $335 million reduction recorded in Property, Plant and Equipment. The reduced investment in KPCo’s assets is being amortized over the 30 year average useful life of the KPCo assets. Planned Disposition of the Competitive Contracted Renewables Portfolio (Generation & Marketing Segment) (Applies to AEP) In February 2022, AEP management announced the initiation of a process to sell all or a portion of AEP Renewables’ competitive contracted renewables portfolio within the Generation & Marketing segment. As of June 30, 2023, the competitive contracted renewable portfolio assets totaled 1.4 gigawatts of generation resources representing consolidated solar and wind assets, with a net book value of $1.2 billion, and a 50% interest in four joint venture wind farms, totaling $246 million, accounted for as equity method investments. In late January 2023, AEP received final bids from interested parties. In February 2023, AEP’s Board of Directors approved management’s plan to sell the competitive contracted renewables portfolio and AEP signed an agreement to sell the competitive contracted renewables portfolio to a nonaffiliated party for $1.5 billion including the assumption of project debt. AEP expects to close on the sale in the third quarter of 2023, pending approval from the Committee on Foreign Investment in the United States. AEP expects to receive cash proceeds, net of taxes, transaction fees and other customary closing adjustments, of approximately $1.2 billion. Management concluded the consolidated assets within the competitive contracted renewables portfolio met the accounting requirements to be presented as Held for Sale in the first quarter of 2023 based on the receipt of final bids, Board of Director approval to consummate a sale transaction and the signing of the sale agreement. AEP recorded a pretax loss of $112 million ($88 million after-tax) in the first quarter of 2023 as a result of reaching Held for Sale status. Management concluded the impact of any other than temporary decline in the fair value of the four joint venture wind farms was not material. Any changes to the book value or carrying value of these assets, or the anticipated sale price, could further reduce future net income and impact financial condition. The Income Before Income Tax Expense (Benefit) of the competitive contracted renewables portfolio was not material to AEP for the three and six months ended June 30, 2023 and 2022. In March 2023, AEP ceased recognition of depreciation on the competitive contracted renewable portfolio assets due to their classification as Held for Sale on the balance sheets. The major classes of the assets and liabilities presented in Assets Held for Sale and Liabilities Held for Sale on the balance sheets of AEP are shown in the following table: June 30, 2023 (in millions) ASSETS Accounts Receivable and Accrued Unbilled Revenues $ 10.0 Property, Plant and Equipment, Net 1,394.0 Other Classes of Assets that are not Major 67.3 Total Major Classes of Assets Held for Sale 1,471.3 Loss on the Expected Sale of the Competitive Contracted Renewables Portfolio (net of $23.5 million of Income Taxes) (88.5) Assets Held for Sale $ 1,382.8 LIABILITIES Accounts Payable $ 4.6 Asset Retirement Obligations 31.0 Obligations Under Operating Leases 21.6 Other Classes of Liabilities that are not Major 7.6 Liabilities Held for Sale $ 64.8 The four joint venture wind farms totaling $246 million as of June 30, 2023, which are included in the plan of sale, continue to be classified as Deferred Charges and Other Noncurrent Assets and $183 million attributable to noncontrolling interests continues to be classified as Noncontrolling Interests on AEP’s consolidated balance sheets. DISPOSITIONS 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 June 2022, as a result of Flat Ridge 2’s deteriorating financial performance, sale negotiations and AEP’s ongoing evaluation and ultimate decision to exit the investment in the near term, AEP determined a decline in the fair value of AEP’s investment in Flat Ridge 2 was other than temporary. In accordance with the accounting guidance for “Investments - Equity Method and Joint Ventures”, in the second quarter of 2022 AEP recorded a pretax other than temporary impairment charge of $186 million which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s Statement of Income. AEP’s determination of fair value utilized the accounting guidance for Fair Value Measurement market approach to valuation and was based on negotiations to sell the investment to a non-affiliate. In September 2022, AEP signed a Purchase and Sale Agreement with a nonaffiliate for AEP’s interest in Flat Ridge 2. The transaction closed in the fourth quarter of 2022 and had an immaterial impact on the financial statements at closing.

Benefit Plans

Benefit Plans	6 Months Ended
Benefit Plans	Jun. 30, 2023
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 (Credit) Pension Plans Three Months Ended June 30, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 23.6 $ 2.1 $ 2.2 $ 3.0 $ 2.1 $ 1.4 $ 1.9 Interest Cost 54.8 4.6 6.6 6.2 5.0 2.7 3.5 Expected Return on Plan Assets (84.8) (7.0) (11.1) (11.1) (8.5) (4.6) (4.9) Amortization of Net Actuarial Loss 0.4 — — — — — — Net Periodic Benefit Cost (Credit) $ (6.0) $ (0.3) $ (2.3) $ (1.9) $ (1.4) $ (0.5) $ 0.5 Three Months Ended June 30, 2022 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 30.8 $ 2.8 $ 2.8 $ 4.1 $ 2.9 $ 1.8 $ 2.7 Interest Cost 37.1 3.0 4.4 4.2 3.2 1.7 2.3 Expected Return on Plan Assets (63.3) (5.2) (8.1) (8.1) (6.2) (3.4) (3.6) Amortization of Net Actuarial Loss 15.7 1.3 1.8 1.7 1.4 0.8 0.9 Net Periodic Benefit Cost $ 20.3 $ 1.9 $ 0.9 $ 1.9 $ 1.3 $ 0.9 $ 2.3 Six Months Ended June 30, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 47.2 $ 4.1 $ 4.5 $ 6.0 $ 4.2 $ 2.8 $ 3.8 Interest Cost 109.6 9.2 13.2 12.4 9.9 5.4 7.0 Expected Return on Plan Assets (169.6) (14.0) (22.3) (22.1) (17.0) (9.2) (9.7) Amortization of Net Actuarial Loss 0.7 — — — — — — Net Periodic Benefit Cost (Credit) $ (12.1) $ (0.7) $ (4.6) $ (3.7) $ (2.9) $ (1.0) $ 1.1 Six Months Ended June 30, 2022 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 61.6 $ 5.6 $ 5.7 $ 8.1 $ 5.6 $ 3.7 $ 5.3 Interest Cost 74.1 6.0 8.8 8.4 6.6 3.5 4.6 Expected Return on Plan Assets (126.7) (10.5) (16.2) (16.1) (12.4) (6.8) (7.3) Amortization of Net Actuarial Loss 31.5 2.6 3.6 3.5 2.8 1.5 1.9 Net Periodic Benefit Cost $ 40.5 $ 3.7 $ 1.9 $ 3.9 $ 2.6 $ 1.9 $ 4.5 OPEB Three Months Ended June 30, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 1.2 $ 0.1 $ 0.2 $ 0.2 $ 0.1 $ — $ 0.1 Interest Cost 11.5 0.9 1.9 1.4 1.1 0.6 0.7 Expected Return on Plan Assets (27.4) (2.2) (4.0) (3.4) (3.0) (1.4) (1.8) Amortization of Prior Service Credit (15.7) (1.4) (2.3) (2.1) (1.5) (1.0) (1.2) Amortization of Net Actuarial Loss 3.7 0.3 0.5 0.4 0.4 0.2 0.3 Net Periodic Benefit Credit $ (26.7) $ (2.3) $ (3.7) $ (3.5) $ (2.9) $ (1.6) $ (1.9) Three Months Ended June 30, 2022 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 1.9 $ 0.1 $ 0.2 $ 0.3 $ 0.1 $ 0.1 $ 0.2 Interest Cost 7.3 0.5 1.1 0.9 0.8 0.3 0.4 Expected Return on Plan Assets (27.5) (2.2) (4.0) (3.5) (2.9) (1.5) (1.8) Amortization of Prior Service Credit (17.9) (1.5) (2.6) (2.5) (1.8) (1.1) (1.3) Net Periodic Benefit Credit $ (36.2) $ (3.1) $ (5.3) $ (4.8) $ (3.8) $ (2.2) $ (2.5) Six Months Ended June 30, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 2.3 $ 0.2 $ 0.3 $ 0.4 $ 0.2 $ 0.1 $ 0.2 Interest Cost 23.1 1.8 3.7 2.7 2.3 1.2 1.4 Expected Return on Plan Assets (54.8) (4.5) (8.0) (6.8) (5.9) (2.9) (3.6) Amortization of Prior Service Credit (31.5) (2.7) (4.6) (4.3) (3.1) (2.0) (2.4) Amortization of Net Actuarial Loss 7.4 0.6 1.1 0.9 0.8 0.4 0.5 Net Periodic Benefit Credit $ (53.5) $ (4.6) $ (7.5) $ (7.1) $ (5.7) $ (3.2) $ (3.9) Six Months Ended June 30, 2022 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 3.7 $ 0.2 $ 0.4 $ 0.5 $ 0.3 $ 0.2 $ 0.3 Interest Cost 14.6 1.1 2.3 1.7 1.5 0.7 0.9 Expected Return on Plan Assets (55.0) (4.5) (8.1) (6.9) (5.9) (3.0) (3.7) Amortization of Prior Service Credit (35.7) (3.0) (5.2) (4.9) (3.6) (2.2) (2.6) Net Periodic Benefit Credit $ (72.4) $ (6.2) $ (10.6) $ (9.6) $ (7.7) $ (4.3) $ (5.1)

Business Segments

Business Segments	6 Months Ended
Business Segments	Jun. 30, 2023
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, MISO, PJM and SPP. • Competitive generation in PJM. The remainder of AEP’s activitie s are p resented as Corporate and Other. While not considered a reportable segment, Corporate and Other primarily includes the purchasing of receivables from certain AEP utility subsidiaries, Parent’s guarantee revenue received from affiliates, investment income, interest income and interest expense, and other nonallocated costs. The tables below represent AEP’s reportable segment income statement information for the three and six months ended June 30, 2023 and 2022 and reportable segment balance sheet information as of June 30, 2023 and December 31, 2022. Three Months Ended June 30, 2023 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) Revenues from: External Customers $ 2,629.0 $ 1,330.8 $ 88.3 $ 318.2 $ 6.2 $ — $ 4,372.5 Other Operating Segments 45.5 9.4 370.3 13.2 25.8 (464.2) — Total Revenues $ 2,674.5 $ 1,340.2 $ 458.6 $ 331.4 $ 32.0 $ (464.2) $ 4,372.5 Net Income (Loss) $ 278.4 $ 176.7 $ 197.3 $ (38.6) $ (97.7) $ — $ 516.1 Three Months Ended June 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 $ 2,595.0 $ 1,296.8 $ 79.1 $ 654.4 $ 14.4 $ — $ 4,639.7 Other Operating Segments 53.5 4.8 299.7 5.2 10.1 (373.3) — Total Revenues $ 2,648.5 $ 1,301.6 $ 378.8 $ 659.6 $ 24.5 $ (373.3) $ 4,639.7 Net Income (Loss) $ 303.3 $ 164.8 $ 142.7 $ 65.9 $ (155.9) $ — $ 520.8 Six Months Ended June 30, 2023 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) Revenues from: External Customers $ 5,445.3 $ 2,786.1 $ 178.4 $ 645.1 $ 8.5 $ — $ 9,063.4 Other Operating Segments 87.0 18.3 735.7 13.3 53.6 (907.9) — Total Revenues $ 5,532.3 $ 2,804.4 $ 914.1 $ 658.4 $ 62.1 $ (907.9) $ 9,063.4 Net Income (Loss) $ 540.6 $ 302.4 $ 379.7 $ (195.0) $ (111.2) $ — $ 916.5 Six Months Ended June 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 $ 5,241.8 $ 2,539.0 $ 162.5 $ 1,263.9 $ 25.1 $ — $ 9,232.3 Other Operating Segments 94.1 9.4 627.7 15.0 19.3 (765.5) — Total Revenues $ 5,335.9 $ 2,548.4 $ 790.2 $ 1,278.9 $ 44.4 $ (765.5) $ 9,232.3 Net Income (Loss) $ 602.5 $ 317.6 $ 316.4 $ 181.9 $ (179.5) $ — $ 1,238.9 June 30, 2023 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Consolidated (in millions) Total Assets (d) $ 51,047.3 $ 23,900.0 $ 16,023.5 $ 4,457.9 $ 6,451.4 (b) $ (5,878.0) (c) $ 96,002.1 December 31, 2022 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Consolidated (in millions) Total Assets $ 49,761.8 $ 22,920.2 $ 15,215.8 $ 4,520.1 $ 6,768.4 (b) $ (5,783.0) (c) $ 93,403.3 (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 “Planned Disposition of the Competitive Contracted Renewables Portfolio” 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 six months ended June 30, 2023 and 2022 and reportable segment balance sheet information as of June 30, 2023 and December 31, 2022. Three Months Ended June 30, 2023 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Revenues from: External Customers $ 87.4 $ — $ — $ 87.4 Sales to AEP Affiliates 357.5 — — 357.5 Total Revenues $ 444.9 $ — $ — $ 444.9 Net Income $ 174.2 $ 1.5 (a) $ — $ 175.7 Three Months Ended June 30, 2022 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Revenues from: External Customers $ 77.3 $ — $ — $ 77.3 Sales to AEP Affiliates 287.1 — — 287.1 Total Revenues $ 364.4 $ — $ — $ 364.4 Net Income $ 118.4 $ 0.1 (a) $ — $ 118.5 Six Months Ended June 30, 2023 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo Consolidated (in millions) Revenues from: External Customers $ 176.4 $ — $ — $ 176.4 Sales to AEP Affiliates 710.1 — — 710.1 Total Revenues $ 886.5 $ — $ — $ 886.5 Net Income $ 335.8 $ 2.6 (a) $ — $ 338.4 Six Months Ended June 30, 2022 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo Consolidated (in millions) Revenues from: External Customers $ 162.3 $ — $ — $ 162.3 Sales to AEP Affiliates 602.5 — — 602.5 Total Revenues $ 764.8 $ — $ — $ 764.8 Net Income $ 273.8 $ 0.1 (a) $ — $ 273.9 June 30, 2023 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Total Assets $ 14,626.3 $ 5,542.1 (b) $ (5,591.9) (c) $ 14,576.5 December 31, 2022 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Total Assets $ 13,875.6 $ 4,817.4 (b) $ (4,878.8) (c) $ 13,814.2 (a) Includes the elimination of AEPTCo Parent’s equity earnings in the State Transcos. (b) Primarily relates to Notes Receivable from the State Transcos. (c) Primarily relates to the elimination of Notes Receivable from the State Transcos.

Derivatives and Hedging

Derivatives and Hedging	6 Months Ended
Derivatives and Hedging	Jun. 30, 2023
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 June 30, 2023 Primary Risk Unit of AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power MWhs 269.9 — 29.1 9.2 2.3 8.7 6.9 Natural Gas MMBtus 136.8 — 5.2 — — 28.3 7.3 Heating Oil and Gasoline Gallons 6.7 1.8 1.0 0.6 1.4 0.9 0.9 Interest Rate USD $ 91.4 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt USD $ 950.0 $ — $ — $ — $ — $ — $ — December 31, 2022 Primary Risk Unit of AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power MWhs 226.8 — 17.9 4.2 2.5 2.9 2.2 Natural Gas MMBtus 77.1 — 1.9 — — 1.9 2.1 Heating Oil and Gasoline Gallons 6.9 1.9 1.0 0.7 1.4 0.9 1.0 Interest Rate USD $ 99.9 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt USD $ 1,650.0 $ — $ — $ — $ — $ 200.0 $ — Fair Value Hedging Strategies (Applies to AEP) Parent enters into interest rate derivative transactions as part of an overall strategy to manage the mix of fixed-rate and floating-rate debt. Certain interest rate derivative transactions effectively modify exposure to interest rate risk by converting a portion of fixed-rate debt to a floating-rate. Provided specific criteria are met, these interest rate derivatives may be designated as fair value hedges. Cash Flow Hedging Strategies The Registrants utilize cash flow hedges on certain derivative transactions for the purchase and sale of power (“Commodity”) in order to manage the variable price risk related to forecasted purchases and sales. Management monitors the potential impacts of commodity price changes and, where appropriate, enters into derivative transactions to protect profit margins for a portion of future electricity sales and purchases. The Registrants do not hedge all commodity price risk. The Registrants utilize a variety of interest rate derivative transactions in order to manage interest rate risk exposure. The Registrants also utilize interest rate derivative contracts to manage interest rate exposure related to future borrowings of fixed-rate debt. The Registrants do not hedge all interest rate exposure. ACCOUNTING FOR DERIVATIVE INSTRUMENTS AND THE IMPACT ON THE FINANCIAL STATEMENTS The accounting guidance for “Derivatives and Hedging” requires recognition of all qualifying derivative instruments as either assets or liabilities on the balance sheets at fair value. The fair values of derivative instruments accounted for using MTM accounting or hedge accounting are based on exchange prices and broker quotes. If a quoted market price is not available, the estimate of fair value is based on the best information available including valuation models that estimate future energy prices based on existing market and broker quotes and other assumptions. In order to determine the relevant fair values of the derivative instruments, the Registrants apply valuation adjustments for discounting, liquidity and credit quality. Credit risk is the risk that a counterparty will fail to perform on the contract or fail to pay amounts due. Liquidity risk represents the risk that imperfections in the market will cause the price to vary from estimated fair value based upon prevailing market supply and demand conditions. Since energy markets are imperfect and volatile, there are inherent risks related to the underlying assumptions in models used to fair value risk management contracts. Unforeseen events may cause reasonable price curves to differ from actual price curves throughout a contract’s term and at the time a contract settles. Consequently, there could be significant adverse or favorable effects on future net income and cash flows if market prices are not consistent with management’s estimates of current market consensus for forward prices in the current period. This is particularly true for longer term contracts. Cash flows may vary based on market conditions, margin requirements and the timing of settlement of risk management contracts. According to the accounting guidance for “Derivatives and Hedging,” the Registrants reflect the fair values of derivative instruments subject to netting agreements with the same counterparty net of related cash collateral. For certain risk management contracts, the Registrants are required to post or receive cash collateral based on third-party contractual agreements and risk profiles. AEP netted cash collateral received from third-parties against short-term and long-term risk management assets in the amounts of $73 million and $481 million as of June 30, 2023 and December 31, 2022, respectively. AEP netted cash collateral paid to third-parties against short-term and long-term risk management liabilities in the amounts of $35 million and $2 million as of June 30, 2023 and December 31, 2022, respectively. There was no cash collateral received from third-parties netted against short-term and long-term risk management assets for the Registrant Subsidiaries as of June 30, 2023 and December 31, 2022. The amount of cash collateral paid to third-parties netted against short-term and long-term risk management liabilities was immaterial for the Registrant Subsidiaries as of June 30, 2023 and December 31, 2022. 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 June 30, 2023 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 $ 721.6 $ 43.4 $ — $ 765.0 $ (485.5) $ 279.5 Long-term Risk Management Assets 466.4 95.1 — 561.5 (294.7) 266.8 Total Assets 1,188.0 138.5 — 1,326.5 (780.2) 546.3 Current Risk Management Liabilities 631.5 12.8 42.6 686.9 (510.7) 176.2 Long-term Risk Management Liabilities 418.5 6.7 82.1 507.3 (232.0) 275.3 Total Liabilities 1,050.0 19.5 124.7 1,194.2 (742.7) 451.5 Total MTM Derivative Contract Net Assets (Liabilities) $ 138.0 $ 119.0 $ (124.7) $ 132.3 $ (37.5) $ 94.8 December 31, 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 $ 965.4 $ 212.2 $ 1.8 $ 1,179.4 $ (830.6) $ 348.8 Long-term Risk Management Assets 565.6 148.9 14.3 728.8 (444.7) 284.1 Total Assets 1,531.0 361.1 16.1 1,908.2 (1,275.3) 632.9 Current Risk Management Liabilities 663.8 60.4 41.4 765.6 (620.4) 145.2 Long-term Risk Management Liabilities 412.0 17.4 91.1 520.5 (175.3) 345.2 Total Liabilities 1,075.8 77.8 132.5 1,286.1 (795.7) 490.4 Total MTM Derivative Contract Net Assets (Liabilities) $ 455.2 $ 283.3 $ (116.4) $ 622.1 $ (479.6) $ 142.5 AEP Texas June 30, 2023 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 $ — $ — $ — Long-term Risk Management Assets — — — Total Assets — — — Current Risk Management Liabilities 0.4 (0.4) — Long-term Risk Management Liabilities 0.1 (0.1) — Total Liabilities 0.5 (0.5) — Total MTM Derivative Contract Net Assets (Liabilities) $ (0.5) $ 0.5 $ — December 31, 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 $ — $ — $ — Long-term Risk Management Assets — — — Total Assets — — — Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — — — Total Liabilities — — — Total MTM Derivative Contract Net Assets $ — $ — $ — APCo June 30, 2023 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 $ 42.5 $ (3.3) $ 39.2 Long-term Risk Management Assets 0.6 (0.4) 0.2 Total Assets 43.1 (3.7) 39.4 Current Risk Management Liabilities 5.1 (4.0) 1.1 Long-term Risk Management Liabilities 0.4 (0.4) — Total Liabilities 5.5 (4.4) 1.1 Total MTM Derivative Contract Net Assets $ 37.6 $ 0.7 $ 38.3 December 31, 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 $ 69.3 $ (0.2) $ 69.1 Long-term Risk Management Assets 0.7 (0.7) — Total Assets 70.0 (0.9) 69.1 Current Risk Management Liabilities 4.1 (0.5) 3.6 Long-term Risk Management Liabilities 0.7 (0.6) 0.1 Total Liabilities 4.8 (1.1) 3.7 Total MTM Derivative Contract Net Assets $ 65.2 $ 0.2 $ 65.4 I&M June 30, 2023 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 $ 22.3 $ (0.9) $ 21.4 Long-term Risk Management Assets 11.8 (2.7) 9.1 Total Assets 34.1 (3.6) 30.5 Current Risk Management Liabilities 2.8 (1.4) 1.4 Long-term Risk Management Liabilities 2.7 (2.7) — Total Liabilities 5.5 (4.1) 1.4 Total MTM Derivative Contract Net Assets $ 28.6 $ 0.5 $ 29.1 December 31, 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 $ 16.0 $ (0.8) $ 15.2 Long-term Risk Management Assets 0.5 (0.3) 0.2 Total Assets 16.5 (1.1) 15.4 Current Risk Management Liabilities 0.9 (0.9) — Long-term Risk Management Liabilities 0.3 (0.3) — Total Liabilities 1.2 (1.2) — Total MTM Derivative Contract Net Assets $ 15.3 $ 0.1 $ 15.4 OPCo June 30, 2023 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 $ — $ — $ — Long-term Risk Management Assets — — — Total Assets — — — Current Risk Management Liabilities 6.6 (0.3) 6.3 Long-term Risk Management Liabilities 47.8 (0.1) 47.7 Total Liabilities 54.4 (0.4) 54.0 Total MTM Derivative Contract Net Assets (Liabilities) $ (54.4) $ 0.4 $ (54.0) December 31, 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 $ — $ — $ — Long-term Risk Management Assets — — — Total Assets — — — Current Risk Management Liabilities 2.1 (0.3) 1.8 Long-term Risk Management Liabilities 37.9 — 37.9 Total Liabilities 40.0 (0.3) 39.7 Total MTM Derivative Contract Net Assets (Liabilities) $ (40.0) $ 0.3 $ (39.7) PSO June 30, 2023 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 $ 47.4 $ (2.6) $ 44.8 Long-term Risk Management Assets 0.2 (0.2) — Total Assets 47.6 (2.8) 44.8 Current Risk Management Liabilities 5.4 (2.8) 2.6 Long-term Risk Management Liabilities 1.0 (0.2) 0.8 Total Liabilities 6.4 (3.0) 3.4 Total MTM Derivative Contract Net Assets $ 41.2 $ 0.2 $ 41.4 December 31, 2022 Risk Management Contracts – Hedging Contracts Gross Amounts of Risk Management Assets/Liabilities Recognized Gross Amounts Offset in the Statement of Financial Position (b) Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position (c) Balance Sheet Location Commodity (a) Interest Rate (a) (in millions) Current Risk Management Assets $ 24.1 $ 1.6 $ 25.7 $ (0.4) $ 25.3 Long-term Risk Management Assets — — — — — Total Assets 24.1 1.6 25.7 (0.4) 25.3 Current Risk Management Liabilities 2.1 — 2.1 (0.5) 1.6 Long-term Risk Management Liabilities — — — — — Total Liabilities 2.1 — 2.1 (0.5) 1.6 Total MTM Derivative Contract Net Assets $ 22.0 $ 1.6 $ 23.6 $ 0.1 $ 23.7 SWEPCo June 30, 2023 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 $ 28.5 $ (0.5) $ 28.0 Long-term Risk Management Assets — — — Total Assets 28.5 (0.5) 28.0 Current Risk Management Liabilities 2.4 (0.8) 1.6 Long-term Risk Management Liabilities 0.2 — 0.2 Total Liabilities 2.6 (0.8) 1.8 Total MTM Derivative Contract Net Assets $ 25.9 $ 0.3 $ 26.2 December 31, 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 $ 16.8 $ (0.4) $ 16.4 Long-term Risk Management Assets — — — Total Assets 16.8 (0.4) 16.4 Current Risk Management Liabilities 2.0 (0.6) 1.4 Long-term Risk Management Liabilities — — — Total Liabilities 2.0 (0.6) 1.4 Total MTM Derivative Contract Net Assets $ 14.8 $ 0.2 $ 15.0 (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. 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 June 30, 2023 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 17.0 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues (141.8) — — — — — — Electric Generation, Transmission and Distribution Revenues — — — 17.0 — — — Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 1.3 — 1.3 0.1 — — — Other Operation (0.1) — — — — — — Maintenance (0.3) (0.1) — — — — — Regulatory Assets (a) (12.4) (0.1) 5.9 (1.6) (12.8) (2.3) (0.9) Regulatory Liabilities (a) 102.0 — 17.4 3.6 — 42.4 33.6 Total Gain (Loss) on Risk Management Contracts $ (34.3) $ (0.2) $ 24.6 $ 19.1 $ (12.8) $ 40.1 $ 32.7 Three Months Ended June 30, 2022 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 0.1 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 121.0 — — — — — — Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 0.9 — 0.7 — — 0.1 — Other Operation 1.7 0.5 0.2 0.2 0.3 0.2 0.3 Maintenance 2.4 0.7 0.4 0.2 0.4 0.3 0.4 Regulatory Assets (a) 21.4 0.1 0.1 0.3 21.0 — (0.1) Regulatory Liabilities (a) 110.4 — 21.6 1.5 1.6 39.0 36.9 Total Gain on Risk Management Contracts $ 257.9 $ 1.3 $ 23.0 $ 2.2 $ 23.3 $ 39.6 $ 37.5 Six Months Ended June 30, 2023 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 11.7 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues (289.2) — — — — — — Electric Generation, Transmission and Distribution Revenues — — — 11.7 — — — Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 2.0 — 1.9 0.1 — — — Other Operation (0.1) — — — — — — Maintenance (0.2) (0.1) — — — — — Regulatory Assets (a) (37.2) (0.5) (1.2) (2.1) (25.1) (3.5) (2.4) Regulatory Liabilities (a) 100.5 — (8.8) 4.8 — 60.4 45.5 Total Gain (Loss) on Risk Management Contracts $ (212.5) $ (0.6) $ (8.1) $ 14.5 $ (25.1) $ 56.9 $ 43.1 Six Months Ended June 30, 2022 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 0.1 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 273.3 — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.1 (0.1) — — — Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 2.4 — 2.1 — — 0.1 — Other Operation 2.3 0.7 0.2 0.3 0.4 0.3 0.4 Maintenance 3.2 0.9 0.5 0.3 0.5 0.4 0.5 Regulatory Assets (a) 45.0 0.1 — (1.3) 44.9 3.6 (2.2) Regulatory Liabilities (a) 146.9 0.9 20.2 3.2 1.6 51.7 57.8 Total Gain on Risk Management Contracts $ 473.2 $ 2.6 $ 23.1 $ 2.4 $ 47.4 $ 56.1 $ 56.5 (a) Represents realized and unrealized gains and losses subject to regulatory accounting treatment recorded as either current or noncurrent on the balance sheets. Certain qualifying derivative instruments have been designated as normal purchase or normal sale contracts, as provided in the accounting guidance for “Derivatives and Hedging.” Derivative contracts that have been designated as normal purchases or normal sales under that accounting guidance are not subject to MTM accounting treatment and are recognized on the statements of income on an accrual basis. The accounting for the changes in the fair value of a derivative instrument depends on whether it qualifies for and has been designated as part of a hedging relationship and further, on the type of hedging relationship. Depending on the exposure, management designates a hedging instrument as a fair value hedge or a cash flow hedge. For contracts that have not been designated as part of a hedging relationship, the accounting for changes in fair value depends on whether the derivative instrument is held for trading purposes. Unrealized and realized gains and losses on derivative instruments held for trading purposes are included in revenues on a net basis on the statements of income. Unrealized and realized gains and losses on derivative instruments not held for trading purposes are included in revenues or expenses on the statements of income depending on the relevant facts and circumstances. Certain derivatives that economically hedge future commodity risk are recorded in the same line item on the statements of income as that of the associated risk being hedged. However, unrealized and some realized gains and losses in regulated jurisdictions for both trading and non-trading derivative instruments are recorded as regulatory assets (for losses) or regulatory liabilities (for gains) in accordance with the accounting guidance for “Regulated Operations.” Accounting for Fair Value Hedging Strategies (Applies to AEP) For fair value hedges (i.e. hedging the exposure to changes in the fair value of an asset, liability or an identified portion thereof attributable to a particular risk), the gain or loss on the derivative instrument as well as the offsetting gain or loss on the hedged item associated with the hedged risk impacts net income during the period of change. AEP records realized and unrealized gains or losses on interest rate swaps that are designated and qualify for fair value hedge accounting treatment and any offsetting changes in the fair value of the debt being hedged in Interest Expense on the statements of income. The following table shows the impacts recognized on the balance sheets related to the hedged items in fair value hedging relationships: Carrying Amount of the Hedged Liabilities Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of the Hedged Liabilities June 30, 2023 December 31, 2022 June 30, 2023 December 31, 2022 (in millions) Long-term Debt (a) (b) $ (855.1) $ (855.5) $ 90.8 $ 89.7 (a) Amounts included on the Balance Sheet within Noncurrent Liabilities line item Long-term Debt. (b) Amounts include $(34) million and $(38) million as of June 30, 2023 and December 31, 2022, 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 June 30, Six Months Ended June 30, 2023 2022 2023 2022 (in millions) Gain (Loss) on Interest Rate Contracts: Fair Value Hedging Instruments (a) $ (4.2) $ (17.6) $ 2.7 $ (62.4) Fair Value Portion of Long-term Debt (a) 4.2 17.6 (2.7) 62.4 (a) Gain (Loss) is included in Interest Expense on the statements of income. Accounting for Cash Flow Hedging Strategies (Applies to AEP, AEP Texas, APCo, I&M, PSO and SWEPCo) For cash flow hedges (i.e. hedging the exposure to variability in expected future cash flows that is attributable to a particular risk), the Registrants initially report the gain or loss on the derivative instrument as a component of Accumulated Other Comprehensive Income (Loss) on the balance sheets until the period the hedged item affects net income. Realized gains and losses on derivative contracts for the purchase and sale of power designated as cash flow hedges are included in Total Revenues or Purchased Electricity for Resale on the statements of income or in Regulatory Assets or Regulatory Liabilities on the balance sheets, depending on the specific nature of the risk being hedged. During the three and six months ended June 30, 2023 and 2022, 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 months ended June 30, 2023, AEP and AEP Texas applied cash flow hedging to outstanding interest rate derivatives and the other Registrant Subsidiaries did not. During the six months ended June 30, 2023, AEP, AEP Texas, I&M, PSO and SWEPCo applied cash flow hedging to outstanding interest rate derivatives and the other Registrant Subsidiaries did not. During the three and six months ended June 30, 2022, AEP applied cash flow hedging to outstanding interest rate derivatives and the 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 June 30, 2023 December 31, 2022 Commodity Interest Rate Commodity Interest Rate (in millions) AOCI Gain Net of Tax $ 93.5 $ 12.7 $ 223.5 $ 0.3 Portion Expected to be Reclassed to Net Income During the Next Twelve Months 24.1 4.3 119.9 0.3 As of June 30, 2023 the maximum length of time that AEP is hedging its exposure to variability in future cash flows related to forecasted transactions is 93 months and 90 months for commodity and interest rate hedges, respectively. Impact of Cash Flow Hedges on the Registrant Subsidiaries’ Balance Sheets June 30, 2023 December 31, 2022 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 $ 2.9 $ 0.3 $ (0.3) $ (0.2) APCo 6.3 0.8 6.7 0.8 I&M (5.7) (0.4) (5.1) (0.6) PSO (0.2) — 1.3 0.1 SWEPCo 1.4 0.3 1.1 0.2 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 $0 and $2 million as of June 30, 2023 and December 31, 2022, respectively. The Registrant Subsidiaries had no derivative contracts with collateral triggering events in a net liability position as of June 30, 2023 and December 31, 2022. 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 $125 million and $127 million as of June 30, 2023 and December 31, 2022, respectively. There was no cash collateral posted as of June 30, 2023 and December 31, 2022, 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 June 30, 2023 and December 31, 2022. Cross-Default Triggers (Applies to AEP, APCo, I&M, PSO 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 derivative liabilities subject to cross-default provisions in a net liability position of $178 million and $217 million as of June 30, 2023 and December 31, 2022, respectively, after considering contractual netting arrangements. There was no cash collateral posted as of June 30, 2023 and December 31, 2022. If a cross-default provision would have been triggered, settlement at fair value would have been required. The Registrant Subsidiaries’ derivative contracts with cross-default provisions outstanding as of June 30, 2023 and December 31, 2022 were not material.

Fair Value Measurements

Fair Value Measurements	6 Months Ended
Fair Value Measurements	Jun. 30, 2023
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: June 30, 2023 December 31, 2022 Company Book Value Fair Value Book Value Fair Value (in millions) AEP (a) $ 40,142.3 $ 36,351.3 $ 36,801.0 $ 32,915.9 AEP Texas 5,937.5 5,295.5 5,657.8 5,045.8 AEPTCo 5,473.0 4,719.2 4,782.8 3,940.5 APCo 5,599.7 5,298.4 5,410.5 5,079.2 I&M 3,464.1 3,174.2 3,260.8 2,929.0 OPCo 3,365.6 2,878.8 2,970.3 2,516.6 PSO 2,383.9 2,106.1 1,912.8 1,635.8 SWEPCo 3,645.6 3,135.3 3,391.6 2,870.9 (a) The fair value amounts include debt related to AEP’s Equity Units and had a fair value of $844 million and $877 million as of June 30, 2023 and December 31, 2022, respectively. See “Equity Units” section of Note 12 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: June 30, 2023 Gross Gross Unrealized Unrealized Fair Other Temporary Investments and Restricted Cash Cost Gains Losses Value (in millions) Restricted Cash (a) $ 45.8 $ — $ — $ 45.8 Other Cash Deposits 15.9 — — 15.9 Fixed Income Securities – Mutual Funds (b) 155.7 — (8.9) 146.8 Equity Securities – Mutual Funds 15.4 24.4 — 39.8 Total Other Temporary Investments and Restricted Cash $ 232.8 $ 24.4 $ (8.9) $ 248.3 December 31, 2022 Gross Gross Unrealized Unrealized Fair Other Temporary Investments and Restricted Cash Cost Gains Losses Value (in millions) Restricted Cash (a) $ 47.1 $ — $ — $ 47.1 Other Cash Deposits 9.0 — — 9.0 Fixed Income Securities – Mutual Funds (b) 152.4 — (8.3) 144.1 Equity Securities – Mutual Funds 15.1 19.4 — 34.5 Total Other Temporary Investments and Restricted Cash $ 223.6 $ 19.4 $ (8.3) $ 234.7 (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 June 30, Six Months Ended June 30, 2023 2022 2023 2022 (in millions) Proceeds from Investment Sales $ — $ 11.1 $ — $ 15.0 Purchases of Investments 1.3 0.8 2.3 1.6 Gross Realized Gains on Investment Sales — 3.3 — 3.6 Gross Realized Losses on Investment Sales — 0.4 — 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: June 30, 2023 December 31, 2022 Gross Gross Other-Than- Gross Gross Other-Than- Fair Unrealized Unrealized Temporary Fair Unrealized Unrealized Temporary Value Gains Losses Impairments Value Gains Losses Impairments (in millions) Cash and Cash Equivalents $ 24.2 $ — $ — $ — $ 21.2 $ — $ — $ — Fixed Income Securities: United States Government 1,191.9 9.9 (13.8) (25.6) 1,123.8 11.8 (14.9) (18.8) Corporate Debt 68.8 0.8 (6.6) (1.7) 61.6 0.7 (7.7) (9.6) State and Local Government 3.3 — — — 3.3 0.1 — (0.1) Subtotal Fixed Income Securities 1,264.0 10.7 (20.4) (27.3) 1,188.7 12.6 (22.6) (28.5) Equity Securities - Domestic 2,360.6 1,725.7 (4.6) — 2,131.3 1,483.7 (6.4) — Spent Nuclear Fuel and Decommissioning Trusts $ 3,648.8 $ 1,736.4 $ (25.0) $ (27.3) $ 3,341.2 $ 1,496.3 $ (29.0) $ (28.5) The following table provides the securities activity within the decommissioning and SNF trusts: Three Months Ended June 30, Six Months Ended June 30, 2023 2022 2023 2022 (in millions) Proceeds from Investment Sales $ 688.7 $ 736.4 $ 1,206.3 $ 1,229.9 Purchases of Investments 697.0 745.5 1,233.3 1,253.2 Gross Realized Gains on Investment Sales 6.4 10.9 54.8 16.7 Gross Realized Losses on Investment Sales 3.7 17.9 12.3 25.1 The base cost of fixed income securities was $1.3 billion and $1.2 billion as of June 30, 2023 and December 31, 2022, respectively. The base cost of equity securities was $640 million and $654 million as of June 30, 2023 and December 31, 2022, respectively. The fair value of fixed income securities held in the nuclear trust funds, summarized by contractual maturities, as of June 30, 2023 was as follows: Fair Value of Fixed Income Securities (in millions) Within 1 year $ 325.0 After 1 year through 5 years 496.9 After 5 years through 10 years 219.2 After 10 years 222.9 Total $ 1,264.0 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 June 30, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments and Restricted Cash Restricted Cash $ 45.8 $ — $ — $ — $ 45.8 Other Cash Deposits (a) — — — 15.9 15.9 Fixed Income Securities – Mutual Funds 146.8 — — — 146.8 Equity Securities – Mutual Funds (b) 39.8 — — — 39.8 Total Other Temporary Investments and Restricted Cash 232.4 — — 15.9 248.3 Risk Management Assets Risk Management Commodity Contracts (c) (d) 12.5 893.6 276.5 (756.9) 425.7 Cash Flow Hedges: Commodity Hedges (c) — 118.4 19.4 (17.2) 120.6 Total Risk Management Assets 12.5 1,012.0 295.9 (774.1) 546.3 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 13.3 — — 10.9 24.2 Fixed Income Securities: United States Government — 1,191.9 — — 1,191.9 Corporate Debt — 68.8 — — 68.8 State and Local Government — 3.3 — — 3.3 Subtotal Fixed Income Securities — 1,264.0 — — 1,264.0 Equity Securities – Domestic (b) 2,360.6 — — — 2,360.6 Total Spent Nuclear Fuel and Decommissioning Trusts 2,373.9 1,264.0 — 10.9 3,648.8 Total Assets $ 2,618.8 $ 2,276.0 $ 295.9 $ (747.3) $ 4,443.4 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (d) $ 26.5 $ 848.3 $ 169.8 $ (719.4) $ 325.2 Cash Flow Hedges: Commodity Hedges (c) — 18.8 — (17.2) 1.6 Fair Value Hedges — 124.7 — — 124.7 Total Risk Management Liabilities $ 26.5 $ 991.8 $ 169.8 $ (736.6) $ 451.5 AEP Assets and Liabilities Measured at Fair Value on a Recurring Basis December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments and Restricted Cash Restricted Cash $ 47.1 $ — $ — $ — $ 47.1 Other Cash Deposits (a) — — — 9.0 9.0 Fixed Income Securities – Mutual Funds 144.1 — — — 144.1 Equity Securities – Mutual Funds (b) 34.5 — — — 34.5 Total Other Temporary Investments and Restricted Cash 225.7 — — 9.0 234.7 Risk Management Assets Risk Management Commodity Contracts (c) (f) 15.0 1,197.5 314.4 (1,211.5) 315.4 Cash Flow Hedges: Commodity Hedges (c) — 332.6 26.7 (52.8) 306.5 Interest Rate Hedges — 11.0 — — 11.0 Total Risk Management Assets 15.0 1,541.1 341.1 (1,264.3) 632.9 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 11.3 — — 9.9 21.2 Fixed Income Securities: United States Government — 1,123.8 — — 1,123.8 Corporate Debt — 61.6 — — 61.6 State and Local Government — 3.3 — — 3.3 Subtotal Fixed Income Securities — 1,188.7 — — 1,188.7 Equity Securities – Domestic (b) 2,131.3 — — — 2,131.3 Total Spent Nuclear Fuel and Decommissioning Trusts 2,142.6 1,188.7 — 9.9 3,341.2 Total Assets $ 2,383.3 $ 2,729.8 $ 341.1 $ (1,245.4) $ 4,208.8 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (f) $ 21.8 $ 870.9 $ 179.0 $ (731.9) $ 339.8 Cash Flow Hedges: Commodity Hedges (c) — 74.3 1.7 (52.8) 23.2 Fair Value Hedges — 127.4 — — 127.4 Total Risk Management Liabilities $ 21.8 $ 1,072.6 $ 180.7 $ (784.7) $ 490.4 AEP Texas Assets and Liabilities Measured at Fair Value on a Recurring Basis June 30, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 30.7 $ — $ — $ — $ 30.7 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 0.5 $ — $ (0.5) $ — December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 32.7 $ — $ — $ — $ 32.7 APCo Assets and Liabilities Measured at Fair Value on a Recurring Basis June 30, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 15.1 $ — $ — $ — $ 15.1 Risk Management Assets Risk Management Commodity Contracts (c) (g) — 1.6 41.1 (3.3) 39.4 Total Assets $ 15.1 $ 1.6 $ 41.1 $ (3.3) $ 54.5 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 3.4 $ 1.7 $ (4.0) $ 1.1 December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 14.4 $ — $ — $ — $ 14.4 Risk Management Assets Risk Management Commodity Contracts (c) (g) — 0.7 69.4 (1.0) 69.1 Total Assets $ 14.4 $ 0.7 $ 69.4 $ (1.0) $ 83.5 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 4.6 $ 0.3 $ (1.4) $ 3.5 I&M Assets and Liabilities Measured at Fair Value on a Recurring Basis June 30, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 25.6 $ 8.2 $ (3.3) $ 30.5 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 13.3 — — 10.9 24.2 Fixed Income Securities: United States Government — 1,191.9 — — 1,191.9 Corporate Debt — 68.8 — — 68.8 State and Local Government — 3.3 — — 3.3 Subtotal Fixed Income Securities — 1,264.0 — — 1,264.0 Equity Securities - Domestic (b) 2,360.6 — — — 2,360.6 Total Spent Nuclear Fuel and Decommissioning Trusts 2,373.9 1,264.0 — 10.9 3,648.8 Total Assets $ 2,373.9 $ 1,289.6 $ 8.2 $ 7.6 $ 3,679.3 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 3.8 $ 1.4 $ (3.8) $ 1.4 December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 11.3 $ 5.3 $ (1.2) $ 15.4 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 11.3 — — 9.9 21.2 Fixed Income Securities: United States Government — 1,123.8 — — 1,123.8 Corporate Debt — 61.6 — — 61.6 State and Local Government — 3.3 — — 3.3 Subtotal Fixed Income Securities — 1,188.7 — — 1,188.7 Equity Securities - Domestic (b) 2,131.3 — — — 2,131.3 Total Spent Nuclear Fuel and Decommissioning Trusts 2,142.6 1,188.7 — 9.9 3,341.2 Total Assets $ 2,142.6 $ 1,200.0 $ 5.3 $ 8.7 $ 3,356.6 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 0.6 $ 0.7 $ (1.3) $ — OPCo Assets and Liabilities Measured at Fair Value on a Recurring Basis June 30, 2023 Level 1 Level 2 Level 3 Other Total Liabilities: (in millions) Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 0.4 $ 54.0 $ (0.4) $ 54.0 December 31, 2022 Level 1 Level 2 Level 3 Other Total Liabilities: (in millions) Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 40.0 $ (0.3) $ 39.7 PSO Assets and Liabilities Measured at Fair Value on a Recurring Basis June 30, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 2.9 $ 44.7 $ (2.8) $ 44.8 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 4.8 $ 1.6 $ (3.0) $ 3.4 December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ — $ 24.0 $ 1.3 $ 25.3 Cash Flow Hedges: Interest Rate Hedges — 1.6 — (1.6) — Total Assets $ — $ 1.6 $ 24.0 $ (0.3) $ 25.3 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 1.7 $ 0.3 $ (0.4) $ 1.6 SWEPCo Assets and Liabilities Measured at Fair Value on a Recurring Basis June 30, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.4 $ 28.1 $ (0.5) $ 28.0 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 0.5 $ 2.1 $ (0.8) $ 1.8 December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 2.2 $ 14.6 $ (0.4) $ 16.4 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 1.6 $ 0.4 $ (0.6) $ 1.4 (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 June 30, 2023 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $(6) million in 2023 and $(8) million in periods 2024-2026; Level 2 matures $(27) million in 2023, $59 million in periods 2024-2026, $12 million in periods 2027-2028 and $2 million in periods 2029-2033; Level 3 matures $63 million in 2023, $56 million in periods 2024-2026, $1 million in periods 2027-2028 and $(14) million in periods 2029-2033. 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, 2022 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $(7) million in 2023; Level 2 matures $182 million in 2023, $134 million in periods 2024-2026, $10 million in periods 2027-2028 and $1 million in periods 2029-2033; Level 3 matures $128 million in 2023, $6 million in periods 2024-2026, $6 million in periods 2027-2028 and $(5) million in periods 2029-2033. Risk management commodity contracts are substantially comprised of power contracts. (g) Substantially comprised of power contracts for the Registrant Subsidiaries. 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 June 30, 2023 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of March 31, 2023 $ 45.1 $ 5.7 $ 1.1 $ (46.9) $ 9.3 $ 5.8 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) (86.8) (11.9) (3.2) (1.4) (42.1) (32.8) Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (15.8) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 4.7 — — — — — Settlements 62.3 6.2 2.0 1.3 32.8 27.0 Transfers out of Level 3 (e) (3.1) — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 119.7 39.4 6.9 (7.0) 43.1 26.0 Balance as of June 30, 2023 $ 126.1 $ 39.4 $ 6.8 $ (54.0) $ 43.1 $ 26.0 Three Months Ended June 30, 2022 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of March 31, 2022 $ 82.8 $ 6.6 $ 1.0 $ (68.5) $ 6.5 $ 15.7 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 38.6 5.7 (0.3) 0.9 11.9 19.9 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (16.8) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 5.7 — — — — — Settlements (69.3) (12.4) (0.7) — (18.4) (27.9) Transfers into Level 3 (d) (e) 2.4 — — — — — Transfers out of Level 3 (e) 5.8 — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 234.7 79.7 9.8 19.2 64.5 37.7 Balance as of June 30, 2022 $ 283.9 $ 79.6 $ 9.8 $ (48.4) $ 64.5 $ 45.4 Six Months Ended June 30, 2023 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of December 31, 2022 $ 160.4 $ 69.1 $ 4.6 $ (40.0) $ 23.7 $ 14.2 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) (97.5) (47.9) (2.3) (1.7) (25.5) (20.3) Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (3.0) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) (15.0) — — — — — Settlements (23.0) (21.1) (2.2) 2.4 1.8 6.1 Transfers into Level 3 (d) (e) (6.1) — — — — — Transfers out of Level 3 (e) (1.3) — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 111.6 39.3 6.7 (14.7) 43.1 26.0 Balance as of June 30, 2023 $ 126.1 $ 39.4 $ 6.8 $ (54.0) $ 43.1 $ 26.0 Six Months Ended June 30, 2022 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of December 31, 2021 $ 103.1 $ 41.7 $ (0.7) $ (92.5) $ 12.1 $ 10.9 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 68.1 3.0 3.7 2.4 24.2 32.5 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (35.7) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 22.5 — — — — — Settlements (149.0) (44.7) (3.0) 1.4 (36.3) (41.0) Transfers into Level 3 (d) (e) 4.4 — — — — — Transfers out of Level 3 (e) 9.6 — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 260.9 79.6 9.8 40.3 64.5 43.0 Balance as of June 30, 2022 $ 283.9 $ 79.6 $ 9.8 $ (48.4) $ 64.5 $ 45.4 (a) Included in revenues on the statements of income. (b) Represents the change in fair value between the beginning of the reporting period and the settlement of the risk management commodity contract. (c) Included in cash flow hedges on the statements of comprehensive income. (d) Represents existing assets or liabilities that were previously categorized as Level 2. (e) Transfers are recognized based on their value at the beginning of the reporting period that the transfer occurred. (f) Relates to the net gains (losses) of those contracts that are not reflected on the statements of income. These changes in fair value are recorded as regulatory liabilities for net gains and as regulatory assets for net losses or accounts payable. The following tables quantify the significant unobservable inputs used in developing the fair value of Level 3 positions: Significant Unobservable Inputs June 30, 2023 Significant Input/Range Type of Fair Value Valuation Unobservable Weighted Company Input Assets Liabilities Technique Input Low High Average (c) (in millions) AEP Energy Contracts $ 158.4 $ 158.1 Discounted Cash Flow Forward Market Price (a) $ 1.89 $ 90.40 $ 44.95 AEP Natural Gas Contracts 0.2 0.2 Discounted Cash Flow Forward Market Price (b) 2.14 4.21 3.21 AEP FTRs 137.3 11.5 Discounted Cash Flow Forward Market Price (a) (17.92) 11.35 (0.20) APCo Natural Gas Contracts 0.2 — Discounted Cash Flow Forward Market Price (b) 2.91 4.19 3.35 APCo FTRs 40.9 1.7 Discounted Cash Flow Forward Market Price (a) (3.60) 9.53 1.37 I&M FTRs 8.2 1.4 Discounted Cash Flow Forward Market Price (a) (6.02) 9.11 1.07 OPCo Energy Contracts — 54.0 Discounted Cash Flow Forward Market Price (a) 16.97 71.80 41.40 PSO FTRs 44.7 1.6 Discounted Cash Flow Forward Market Price (a) (17.92) 0.87 (4.44) SWEPCo Natural Gas Contracts — 0.2 Discounted Cash Flow Forward Market Price (b) 2.91 4.19 3.35 SWEPCo FTRs 28.1 1.9 Discounted Cash Flow Forward Market Price (a) (17.92) 0.87 (4.44) December 31, 2022 Significant Input/Range Type of Fair Value Valuation Unobservable Weighted Company Input Assets Liabilities Technique Input (a) Low High Average (c) (in millions) AEP Energy Contracts $ 204.0 $ 167.4 Discounted Cash Flow Forward Market Price $ 2.91 $ 187.34 $ 49.14 AEP FTRs 137.1 13.3 Discounted Cash Flow Forward Market Price (36.45) 20.72 1.18 APCo FTRs 69.4 0.3 Discounted Cash Flow Forward Market Price (2.82) 18.88 3.89 I&M FTRs 5.3 0.7 Discounted Cash Flow Forward Market Price 0.16 18.79 1.23 OPCo Energy Contracts — 40.0 Discounted Cash Flow Forward Market Price 2.91 187.34 48.76 PSO FTRs 24.0 0.3 Discounted Cash Flow Forward Market Price (36.45) 3.40 (7.55) SWEPCo FTRs 14.6 0.4 Discounted Cash Flow Forward Market Price (36.45) 3.40 (7.55) (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. The following table provides the measurement uncertainty of fair value measurements to increases (decreases) in significant unobservable inputs related to Energy Contracts and FTRs for the Registrants as of June 30, 2023 and December 31, 2022: 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

Income Taxes	6 Months Ended
Income Taxes	Jun. 30, 2023
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 2023 and 2022, 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 June 30, 2023 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 2.1 % 0.6 % 2.6 % 3.2 % 0.7 % 0.8 % 2.0 % (1.6) % Tax Reform Excess ADIT Reversal (6.2) % (1.3) % 0.1 % (4.5) % (6.1) % (8.5) % (17.2) % (4.2) % Production and Investment Tax Credits (9.9) % (0.2) % — % (0.1) % 0.1 % — % (55.1) % (29.2) % Flow Through (1.0) % 0.1 % 0.2 % (5.1) % (4.4) % 1.2 % 0.3 % (0.8) % AFUDC Equity (1.2) % (0.9) % (2.1) % (1.5) % (0.1) % (0.7) % (1.4) % — % Other 0.4 % 0.3 % — % (0.4) % 0.1 % 0.1 % — % 0.7 % Effective Income Tax Rate 5.2 % 19.6 % 21.8 % 12.6 % 11.3 % 13.9 % (50.4) % (14.1) % Three Months Ended June 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 1.3 % 0.7 % 2.9 % (1.0) % (1.3) % 1.0 % 3.9 % 2.5 % Tax Reform Excess ADIT Reversal (7.1) % (2.1) % 0.3 % (20.4) % (17.2) % (7.8) % (19.2) % (5.2) % Production and Investment Tax Credits (6.1) % (0.6) % — % — % (3.4) % — % (32.2) % (19.8) % Flow Through (0.1) % 0.2 % 0.4 % (1.4) % (1.2) % 0.2 % 0.3 % — % AFUDC Equity (1.1) % (1.4) % (2.3) % (1.5) % (1.3) % (0.7) % (0.4) % (0.5) % Discrete Tax Adjustments 0.3 % — % — % (6.0) % — % — % — % 0.8 % Other 1.1 % 0.1 % 0.1 % (0.2) % 1.3 % 0.1 % 0.5 % (0.1) % Effective Income Tax Rate 9.3 % 17.9 % 22.4 % (9.5) % (2.1) % 13.8 % (26.1) % (1.3) % Six Months Ended June 30, 2023 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 2.0 % 0.5 % 2.6 % 2.6 % 2.4 % 0.9 % 2.0 % (1.2) % Tax Reform Excess ADIT Reversal (6.2) % (1.4) % 0.2 % (4.5) % (7.2) % (7.6) % (17.1) % (4.0) % Production and Investment Tax Credits (9.8) % (0.2) % — % (0.1) % (0.6) % — % (55.2) % (28.2) % Flow Through (0.5) % 0.2 % 0.2 % (0.8) % (2.9) % 0.8 % 0.3 % (0.3) % AFUDC Equity (1.3) % (1.1) % (1.8) % (0.9) % (0.3) % (0.8) % (1.4) % (0.3) % Discrete Tax Adjustments (1.4) % — % — % 2.4 % 1.0 % — % — % — % Other 0.3 % 0.2 % — % (0.1) % 0.1 % 0.1 % 0.1 % 0.1 % Effective Income Tax Rate 4.1 % 19.2 % 22.2 % 19.6 % 13.5 % 14.4 % (50.3) % (12.9) % Six Months Ended June 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 1.4 % 0.5 % 2.7 % 1.5 % 0.4 % 0.9 % 3.5 % 2.4 % Tax Reform Excess ADIT Reversal (6.8) % (2.0) % 0.3 % (11.0) % (17.2) % (7.8) % (18.6) % (5.1) % Production and Investment Tax Credits (7.1) % (0.4) % — % — % (2.3) % — % (31.4) % (20.8) % Flow Through 0.1 % 0.2 % 0.3 % 0.6 % (1.6) % 0.6 % 0.3 % (0.2) % AFUDC Equity (1.0) % (1.1) % (1.9) % (1.0) % (0.9) % (0.6) % (0.5) % (0.5) % Discrete Tax Adjustments (0.2) % — % — % (2.6) % — % — % — % 0.5 % Other 0.5 % (0.1) % 0.2 % — % 0.4 % (0.1) % 0.3 % — % Effective Income Tax Rate 7.9 % 18.1 % 22.6 % 8.5 % (0.2) % 14.0 % (25.4) % (2.7) % 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. AEP has agreed to extend the statute of limitations on the 2017-2019 tax returns to October 31, 2024, to allow time for the current IRS audit to be completed including a refund claim approval by the Congressional Joint Committee on Taxation. The statute of limitations for the 2020 return is set to naturally expire in October 2024 as well. The current IRS audit and associated refund claim evolved from a net operating loss carryback to 2015 that originated in the 2017 return. AEP has received and agreed to two IRS proposed adjustments on the 2017 tax return, which were immaterial. The exam is nearly complete, and AEP is currently working with the IRS to submit the refund claim to the Congressional Joint Committee on Taxation for resolution and final approval. 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 In August 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. As further 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. In December 2022, the IRS released Notice 2023-7 addressing time sensitive issues related to the CAMT. The notice provided initial guidance that AEP can begin to rely on in 2023 and also stated that additional guidance is expected, of which AEP will continue to monitor and assess. Notably, the interim guidance in Notice 2023-7 confirmed the CAMT depreciation adjustment includes tax depreciation that is capitalized to inventory under §263A and recovered as part of cost of goods sold, providing significant relief to AEP’s potential CAMT exposure. AEP and subsidiaries expect to be applicable corporations for purposes of the CAMT beginning in 2023. CAMT cash taxes are expected to be partially offset by regulatory recovery, the utilization of tax credits and additionally the cash inflow generated by the sale of tax credits. The sale of tax credits will be presented in the operating section of the statements of cash flows consistent with the presentation of cash taxes paid. AEP will present the gain or loss on sale of tax credits through income tax expense.

Financing Activities

Financing Activities	6 Months Ended
Financing Activities	Jun. 30, 2023
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 six months ended June 30, 2023. 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 June 30, 2023 December 31, 2022 (in millions) Senior Unsecured Notes $ 33,491.5 $ 30,174.8 Pollution Control Bonds 1,770.9 1,770.2 Notes Payable 165.8 269.7 Securitization Bonds 432.1 487.8 Spent Nuclear Fuel Obligation (a) 292.3 285.6 Junior Subordinated Notes (b) 2,385.0 2,381.3 Other Long-term Debt 1,604.7 1,431.6 Total Long-term Debt Outstanding 40,142.3 36,801.0 Long-term Debt Due Within One Year 3,380.3 2,486.4 Long-term Debt $ 36,762.0 $ 34,314.6 (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 $341 million and $330 million as of June 30, 2023 and December 31, 2022, respectively, and are included in Spent Nuclear Fuel and Decommissioning Trusts on the balance sheets. (b) See “Equity Units” section below for additional information. Long-term Debt Activity Long-term debt and other securities issued, retired and principal payments made during the first six months of 2023 are shown in the following tables: Principal Interest Company Type of Debt Amount (a) Rate Due Date Issuances: (in millions) (%) AEP Senior Unsecured Notes $ 850.0 5.63 2033 AEPTCo Senior Unsecured Notes 700.0 5.40 2053 AEP Texas Senior Unsecured Notes 450.0 5.40 2033 APCo Other Long-term Debt 200.0 Variable 2024 I&M Senior Unsecured Notes 500.0 5.63 2053 OPCo Senior Unsecured Notes 400.0 5.00 2033 PSO Senior Unsecured Notes 475.0 5.25 2033 SWEPCo Senior Unsecured Notes 350.0 5.30 2033 Non-Registrant: KPCo Pollution Control Bonds 65.0 4.70 2026 Transource Energy Other Long-term Debt 13.0 Variable 2025 Total Issuances $ 4,003.0 (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 Senior Unsecured Notes $ 125.0 3.09 2023 AEP Texas Securitization Bonds 31.5 2.85 2024 AEP Texas Securitization Bonds 11.7 2.06 2025 APCo Securitization Bonds 9.7 2.01 2023 APCo Securitization Bonds 3.3 3.77 2028 I&M Senior Unsecured Notes 250.0 3.20 2023 I&M Notes Payable 1.2 Variable 2023 I&M Notes Payable 2.4 Variable 2024 I&M Notes Payable 9.2 Variable 2025 I&M Notes Payable 7.9 0.93 2025 I&M Notes Payable 13.7 3.44 2026 I&M Notes Payable 13.6 5.93 2027 I&M Other Long-term Debt 1.2 6.00 2025 OPCo Other Long-term Debt 0.6 1.15 2028 PSO Other Long-term Debt 0.3 3.00 2027 SWEPCo Notes Payable 25.0 6.37 2024 SWEPCo Notes Payable 30.9 4.58 2032 SWEPCo Other Long-term Debt 38.2 4.68 2028 Non-Registrant: KPCo Pollution Control Bonds 65.0 2.35 2023 Transource Energy Senior Unsecured Notes 1.3 2.75 2050 Total Retirements and Principal Payments $ 641.7 Long-term Debt Subsequent Event In July 2023, I&M retired $8 million of Notes Payable related to DCC Fuel. 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 due in 2025 and a forward equity purchase contract which settles after three years in August 2023. In June 2023, AEP successfully remarketed the Junior Subordinated Notes on behalf of holders of the corporate units. AEP did not receive any proceeds from the remarketing which were used to purchase a portfolio of treasury securities maturing on August 14, 2023. On August 15, 2023, the proceeds from the maturing treasury portfolio, currently held by the collateral agent, will be used to settle the forward equity purchase contract entered into as part of the Equity Units transaction. The interest rate on the Junior Subordinated Notes was reset to 5.699% with the maturity remaining in 2025. 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. 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). 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 0.6% of consolidated tangible net assets as of June 30, 2023. 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 June 30, 2023 and December 31, 2022 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 six months ended June 30, 2023 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 June 30, 2023 Limit (in millions) AEP Texas $ 477.5 $ — $ 279.9 $ — $ (135.9) $ 500.0 AEPTCo 471.3 309.4 153.1 85.9 26.9 820.0 (a) APCo 388.6 19.8 295.0 18.9 (247.2) 500.0 I&M 475.3 100.3 174.0 43.0 40.5 500.0 OPCo 485.7 64.7 266.4 40.2 (72.3) 500.0 PSO 375.0 121.5 127.5 74.8 (68.1) 400.0 SWEPCo 401.6 (b) — 220.6 — (32.6) 400.0 (a) Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions. (b) SWEPCo’s maximum borrowings from the Utility Money Pool exceeded the authorized short-term borrowing limit by $1.6 million on March 15, 2023. On March 16, 2023, SWEPCo’s borrowings from the Utility Money Pool were reduced below the $400 million authorized limit and borrowings have continued to remain below the authorized limit. 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 June 30, 2023 and December 31, 2022 are included in Advances to Affiliates on the subsidiaries’ balance sheets. The Nonutility Money Pool participants’ activity for the six months ended June 30, 2023 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 June 30, 2023 (in millions) AEP Texas $ 6.9 $ 6.8 $ 6.9 SWEPCo 2.2 2.1 2.2 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 June 30, 2023 and December 31, 2022 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 six months ended June 30, 2023 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 June 30, 2023 June 30, 2023 Borrowing Limit (in millions) $ 29.4 $ 158.1 $ 2.9 $ 70.2 $ 21.9 $ — $ 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: Six Months Ended June 30, 2023 2022 Maximum Interest Rate 5.69 % 2.11 % Minimum Interest Rate 4.66 % 0.10 % 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 Six Months Ended June 30, for Six Months Ended June 30, Company 2023 2022 2023 2022 AEP Texas 5.35 % 0.90 % — % 1.48 % AEPTCo 5.16 % 0.93 % 5.46 % 1.49 % APCo 5.36 % 1.08 % 5.35 % 0.95 % I&M 5.13 % 0.92 % 5.42 % 0.96 % OPCo 5.30 % 0.83 % 5.60 % 1.20 % PSO 5.47 % 1.17 % 5.11 % 0.65 % SWEPCo 5.22 % 1.25 % — % 0.55 % Maximum, minimum and average interest rates for funds loaned to the Nonutility Money Pool are summarized in the following table: Six Months Ended June 30, 2023 Six Months Ended June 30, 2022 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 5.69 % 4.66 % 5.35 % 2.11 % 0.46 % 0.98 % SWEPCo 5.69 % 4.66 % 5.35 % 2.11 % 0.46 % 0.98 % 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 Six Months for Funds for Funds for Funds for Funds for Funds for Funds Ended Borrowed Borrowed Loaned Loaned Borrowed Loaned June 30, from AEP from AEP to AEP to AEP from AEP to AEP 2023 5.69 % 4.53 % 5.69 % 4.53 % 5.27 % 5.35 % 2022 2.11 % 0.46 % 2.11 % 0.46 % 1.02 % 0.89 % Short-term Debt (Applies to AEP and SWEPCo) Outstanding short-term debt was as follows: June 30, 2023 December 31, 2022 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 5.45 % $ 750.0 4.67 % AEP Commercial Paper 2,238.7 5.50 % 2,862.2 4.80 % AEP Term Loan 500.0 6.08 % — — % AEP Term Loan 150.0 5.94 % 150.0 5.17 % AEP Term Loan 125.0 5.94 % 125.0 5.17 % AEP Term Loan 100.0 5.94 % 100.0 5.23 % AEP Term Loan — — % 125.0 4.87 % SWEPCo Notes Payable 3.9 7.53 % — — % AEP Total Short-term Debt $ 3,867.6 $ 4,112.2 (a) Weighted-average rate as of June 30, 2023 and December 31, 2022, respectively. (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 includes a $125 million and a $625 million facility, both of which expire in September 2024. As of June 30, 2023, the affiliated utility subsidiaries were in compliance with all requirements under the agreement. Accounts receivable information for AEP Credit was as follows: Three Months Ended June 30, Six Months Ended June 30, 2023 2022 2023 2022 (dollars in millions) Effective Interest Rates on Securitization of Accounts Receivable 5.25 % 0.91 % 5.06 % 0.61 % Net Uncollectible Accounts Receivable Written-Off $ 7.3 $ 6.2 $ 14.1 $ 13.6 June 30, 2023 December 31, 2022 (in millions) Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts $ 1,184.9 $ 1,167.7 Short-term – Securitized Debt of Receivables 750.0 750.0 Delinquent Securitized Accounts Receivable 49.4 44.2 Bad Debt Reserves Related to Securitization 41.7 39.7 Unbilled Receivables Related to Securitization 392.4 360.9 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 expected 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 June 30, 2023 December 31, 2022 (in millions) APCo $ 181.9 $ 194.4 I&M 177.3 166.9 OPCo 477.4 478.6 PSO 177.8 155.5 SWEPCo 191.6 194.0 The fees paid to AEP Credit for customer accounts receivable sold were: Three Months Ended June 30, Six Months Ended June 30, Company 2023 2022 2023 2022 (in millions) APCo $ 4.3 $ 1.5 $ 9.2 $ 2.8 I&M 3.9 2.0 7.8 3.7 OPCo 7.6 7.5 14.9 14.9 PSO 3.5 1.3 6.7 2.2 SWEPCo 4.4 1.5 8.7 2.8 The proceeds on the sale of receivables to AEP Credit were: Three Months Ended June 30, Six Months Ended June 30, Company 2023 2022 2023 2022 (in millions) APCo $ 414.9 $ 339.0 $ 921.1 $ 754.5 I&M 497.2 502.4 1,022.6 1,015.8 OPCo 783.9 693.3 1,668.3 1,409.9 PSO 460.2 428.5 876.5 791.9 SWEPCo 460.5 437.2 898.1 831.7

Variable Interest Entities

Variable Interest Entities	6 Months Ended
Variable Interest Entities	Jun. 30, 2023
Variable Interest Entities	VARIABLE INTEREST ENTITIES The disclosures in this note apply to AEP unless indicated otherwise. The accounting guidance for “Variable Interest Entities” is a consolidation model that considers if a company has a variable interest in a VIE. A VIE is a legal entity that possesses any of the following conditions: the entity’s equity at risk is not sufficient to permit the legal entity to finance its activities without additional subordinated financial support, equity owners are unable to direct the activities that most significantly impact the legal entity’s economic performance (or they possess disproportionate voting rights in relation to the economic interest in the legal entity), or the equity owners lack the obligation to absorb the legal entity’s expected losses or the right to receive the legal entity’s expected residual returns. Entities are required to consolidate a VIE when it is determined that they have a controlling financial interest in a VIE and therefore, are the primary beneficiary of that VIE, as defined by the accounting guidance for “Variable Interest Entities.” In determining whether AEP is the primary beneficiary of a VIE, management considers whether AEP has the power to direct the most significant activities of the VIE and is obligated to absorb losses or receive the expected residual returns that are significant to the VIE. AEP holds ownership interests in businesses with varying ownership structures. AEP has not provided material financial or other support that was not previously contractually required to any of its consolidated VIEs. If an entity is determined not to be a VIE, or if the entity is determined to be a VIE and AEP is not deemed to be the primary beneficiary, the entity is accounted for under the equity method of accounting. Consolidated Variable Interests Entities The Annual Report on Form 10-K for the year ended December 31, 2022 includes a detailed discussion of the Registrants’ consolidated VIEs. There were no reconsideration events with respect to those VIEs in the second quarter of 2023. The balances below represent the assets and liabilities of consolidated VIEs. These balances include intercompany transactions that are eliminated upon consolidation. American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities June 30, 2023 Registrant Subsidiaries SWEPCo I&M AEP Texas Transition Funding AEP Texas Restoration Funding APCo (in millions) ASSETS Current Assets $ 5.8 $ 72.5 $ 26.9 $ 25.4 $ 13.3 Net Property, Plant and Equipment — 129.3 — — — Other Noncurrent Assets 129.7 63.6 109.5 (a) 157.2 (b) 151.8 (c) Total Assets $ 135.5 $ 265.4 $ 136.4 $ 182.6 $ 165.1 LIABILITIES AND EQUITY Current Liabilities $ 19.8 $ 72.4 $ 74.5 $ 36.7 $ 29.6 Noncurrent Liabilities 115.6 193.0 57.5 144.7 133.6 Equity 0.1 — 4.4 1.2 1.9 Total Liabilities and Equity $ 135.5 $ 265.4 $ 136.4 $ 182.6 $ 165.1 (a) Includes an intercompany item eliminated in consolidation of $12 million. (b) Includes an intercompany item eliminated in consolidation of $7 million. (c) Includes an intercompany item eliminated in consolidation of $2 million . American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities June 30, 2023 Other Consolidated VIEs AEP Credit Protected Transource Energy (in millions) ASSETS Current Assets $ 1,186.0 $ 195.1 $ 29.3 Net Property, Plant and Equipment — — 496.6 Other Noncurrent Assets 9.4 — 5.3 Total Assets $ 1,195.4 $ 195.1 $ 531.2 LIABILITIES AND EQUITY Current Liabilities $ 1,132.8 $ 39.7 $ 21.1 Noncurrent Liabilities 0.9 81.9 232.0 Equity 61.7 73.5 278.1 Total Liabilities and Equity $ 1,195.4 $ 195.1 $ 531.2 Apple Blossom, Black Oak, Santa Rita East and Dry Lake are consolidated VIEs included in the plan of sale of the Competitive Contracted Renewables Portfolio. See the “Planned Disposition of the Competitive Contracted Renewables Portfolio” section of Note 6 for the assets and liabilities classified Held for Sale as of June 30, 2023 inclusive of the assets and liabilities of the aforementioned consolidated VIEs. American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities December 31, 2022 Registrant Subsidiaries SWEPCo I&M AEP Texas Transition Funding AEP Texas Restoration Funding APCo (in millions) ASSETS Current Assets $ 108.3 $ 90.2 $ 27.0 $ 21.1 $ 13.5 Net Property, Plant and Equipment 7.2 179.1 — — — Other Noncurrent Assets 130.0 94.0 140.9 (a) 168.8 (b) 164.6 (c) Total Assets $ 245.5 $ 363.3 $ 167.9 $ 189.9 $ 178.1 LIABILITIES AND EQUITY Current Liabilities $ 25.4 $ 90.0 $ 73.2 $ 31.3 $ 29.3 Noncurrent Liabilities 219.4 273.3 90.4 157.4 146.9 Equity 0.7 — 4.3 1.2 1.9 Total Liabilities and Equity $ 245.5 $ 363.3 $ 167.9 $ 189.9 $ 178.1 (a) Includes an intercompany item eliminated in consolidation of $16 million . (b) Includes an intercompany item eliminated in consolidation of $7 million . (c) Includes an intercompany item eliminated in consolidation of $2 million . American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities December 31, 2022 Other Consolidated VIEs AEP Credit Protected Transource Energy Apple Blossom and Black Oak Santa Rita East Dry Lake (in millions) ASSETS Current Assets $ 1,181.0 $ 194.5 $ 23.5 $ 8.3 $ 21.3 $ 4.0 Net Property, Plant and Equipment — — 482.3 216.5 421.6 142.6 Other Noncurrent Assets 9.0 0.3 2.7 13.6 0.1 0.3 Total Assets $ 1,190.0 $ 194.8 $ 508.5 $ 238.4 $ 443.0 $ 146.9 LIABILITIES AND EQUITY Current Liabilities $ 1,087.8 $ 46.4 $ 22.8 $ 4.5 $ 9.6 $ 1.0 Noncurrent Liabilities 0.9 79.1 218.6 5.4 7.3 0.7 Equity 101.3 69.3 267.1 228.5 426.1 145.2 Total Liabilities and Equity $ 1,190.0 $ 194.8 $ 508.5 $ 238.4 $ 443.0 $ 146.9 Significant Variable Interests in Non-Consolidated VIEs and Significant Equity Method Investments The Annual Report on Form 10-K for the year ended December 31, 2022 includes a detailed discussion of significant variable interests in non-consolidated VIEs and other significant equity method investments. There were no reconsideration events or material changes in carrying values as of June 30, 2023.

Revenue from Contracts with Cus

Revenue from Contracts with Customers	6 Months Ended
Revenue from Contracts with Customers	Jun. 30, 2023
Revenue from Contract with Customer	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 June 30, 2023 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 $ 962.0 $ 574.1 $ — $ — $ — $ — $ 1,536.1 Commercial Revenues 642.7 358.3 — — — — 1,001.0 Industrial Revenues 698.9 152.1 — — — (0.1) 850.9 Other Retail Revenues 58.9 12.3 — — — — 71.2 Total Retail Revenues 2,362.5 1,096.8 — — — (0.1) 3,459.2 Wholesale and Competitive Retail Revenues: Generation Revenues 141.4 — — 19.6 — 0.1 161.1 Transmission Revenues (a) 113.5 184.1 455.8 — — (402.8) 350.6 Renewable Generation Revenues (b) — — — 33.1 — (3.1) 30.0 Retail, Trading and Marketing Revenues (b) — — — 407.7 1.2 (10.1) 398.8 Total Wholesale and Competitive Retail Revenues 254.9 184.1 455.8 460.4 1.2 (415.9) 940.5 Other Revenues from Contracts with Customers (c) 61.9 56.1 4.3 6.2 28.6 (39.9) 117.2 Total Revenues from Contracts with Customers 2,679.3 1,337.0 460.1 466.6 29.8 (455.9) 4,516.9 Other Revenues: Alternative Revenue Programs (b) (d) (4.9) (2.9) (1.5) — — (6.3) (15.6) Other Revenues (b) (e) 0.1 6.1 — (135.2) 2.2 (2.0) (128.8) Total Other Revenues (4.8) 3.2 (1.5) (135.2) 2.2 (8.3) (144.4) Total Revenues $ 2,674.5 $ 1,340.2 $ 458.6 $ 331.4 $ 32.0 $ (464.2) $ 4,372.5 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $360 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 $26 million. The remaining affiliated amounts were immaterial. (d) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. (e) Generation & Marketing includes economic hedge activity. Three Months Ended June 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 $ 979.3 $ 561.6 $ — $ — $ — $ — $ 1,540.9 Commercial Revenues 624.8 331.7 — — — — 956.5 Industrial Revenues 641.8 162.5 — — — — 804.3 Other Retail Revenues 52.9 12.8 — — — — 65.7 Total Retail Revenues 2,298.8 1,068.6 — — — — 3,367.4 Wholesale and Competitive Retail Revenues: Generation Revenues 188.3 — — 83.0 — 0.1 271.4 Transmission Revenues (a) 108.8 164.9 421.6 — — (332.0) 363.3 Renewable Generation Revenues (b) — — — 38.2 — (2.9) 35.3 Retail, Trading and Marketing Revenues (b) — — — 408.3 1.3 (2.3) 407.3 Total Wholesale and Competitive Retail Revenues 297.1 164.9 421.6 529.5 1.3 (337.1) 1,077.3 Other Revenues from Contracts with Customers (c) 49.2 65.9 0.2 1.6 20.9 (21.1) 116.7 Total Revenues from Contracts with Customers 2,645.1 1,299.4 421.8 531.1 22.2 (358.2) 4,561.4 Other Revenues: Alternative Revenue Programs (b) (d) 3.3 (4.6) (43.0) — — (13.1) (57.4) Other Revenues (b) (e) 0.1 6.8 — 128.5 2.3 (2.0) 135.7 Total Other Revenues 3.4 2.2 (43.0) 128.5 2.3 (15.1) 78.3 Total Revenues $ 2,648.5 $ 1,301.6 $ 378.8 $ 659.6 $ 24.5 $ (373.3) $ 4,639.7 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $334 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 Vertically Integrated Utilities was $5 million. The remaining affiliated amounts were immaterial. (d) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. (e) Generation & Marketing includes economic hedge activity. Three Months Ended June 30, 2023 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 144.9 $ — $ 324.8 $ 185.2 $ 429.3 $ 186.5 $ 185.1 Commercial Revenues 100.6 — 163.6 141.4 257.8 131.7 153.8 Industrial Revenues 35.2 — 192.5 155.9 116.8 107.8 110.6 Other Retail Revenues 8.7 — 25.2 1.2 3.6 28.3 2.6 Total Retail Revenues 289.4 — 706.1 483.7 807.5 454.3 452.1 Wholesale Revenues: Generation Revenues (a) — — 64.2 63.5 — 4.3 43.9 Transmission Revenues (b) 163.1 444.7 43.9 9.6 21.0 9.9 38.3 Total Wholesale Revenues 163.1 444.7 108.1 73.1 21.0 14.2 82.2 Other Revenues from Contracts with Customers (c) 10.7 4.1 11.8 45.0 45.5 7.2 7.0 Total Revenues from Contracts with Customers 463.2 448.8 826.0 601.8 874.0 475.7 541.3 Other Revenues: Alternative Revenue Programs (d) (e) (2.0) (3.9) 0.5 (2.6) (0.9) (1.0) (3.5) Other Revenues (e) — — — — 6.0 — — Total Other Revenues (2.0) (3.9) 0.5 (2.6) 5.1 (1.0) (3.5) Total Revenues $ 461.2 $ 444.9 $ 826.5 $ 599.2 $ 879.1 $ 474.7 $ 537.8 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $38 million primarily related to the PPA with KGPCo. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $357 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) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. (e) Amounts include affiliated and nonaffiliated revenues. Three Months Ended June 30, 2022 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 174.9 $ — $ 313.2 $ 195.2 $ 386.7 $ 185.2 $ 188.6 Commercial Revenues 110.6 — 152.6 138.6 221.1 121.2 146.0 Industrial Revenues 36.6 — 161.9 160.0 126.0 92.5 97.1 Other Retail Revenues 9.5 — 20.2 1.2 3.4 25.8 4.4 Total Retail Revenues 331.6 — 647.9 495.0 737.2 424.7 436.1 Wholesale Revenues: Generation Revenues (a) — — 63.5 94.2 — 0.3 57.4 Transmission Revenues (b) 143.8 406.1 40.8 8.7 21.1 9.1 39.3 Total Wholesale Revenues 143.8 406.1 104.3 102.9 21.1 9.4 96.7 Other Revenues from Contracts with Customers (c) 5.6 0.2 20.6 25.8 60.2 9.6 6.0 Total Revenues from Contracts with Customers 481.0 406.3 772.8 623.7 818.5 443.7 538.8 Other Revenues: Alternative Revenue Programs (d) (e) (2.2) (41.9) 0.8 7.3 (2.4) (0.8) (2.2) Other Revenues (e) — — — — 6.8 — — Total Other Revenues (2.2) (41.9) 0.8 7.3 4.4 (0.8) (2.2) Total Revenues $ 478.8 $ 364.4 $ 773.6 $ 631.0 $ 822.9 $ 442.9 $ 536.6 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $42 million primarily related to the PPA with KGPCo. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $330 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $19 million primarily related to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. (e) Amounts include affiliated and nonaffiliated revenues. Six Months Ended June 30, 2023 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 $ 2,132.4 $ 1,230.9 $ — $ — $ — $ — $ 3,363.3 Commercial Revenues 1,276.1 734.2 — — — — 2,010.3 Industrial Revenues (a) 1,369.2 365.0 — — — (0.3) 1,733.9 Other Retail Revenues 115.7 24.4 — — — — 140.1 Total Retail Revenues 4,893.4 2,354.5 — — — (0.3) 7,247.6 Wholesale and Competitive Retail Revenues: Generation Revenues 324.2 — — 52.0 — 0.1 376.3 Transmission Revenues (b) 228.2 348.3 905.9 — — (804.6) 677.8 Renewable Generation Revenues (a) — — — 54.4 — (3.2) 51.2 Retail, Trading and Marketing Revenues (c) — — — 821.4 0.9 (10.0) 812.3 Total Wholesale and Competitive Retail Revenues 552.4 348.3 905.9 927.8 0.9 (817.7) 1,917.6 Other Revenues from Contracts with Customers (d) 94.5 98.9 7.9 6.8 58.0 (83.6) 182.5 Total Revenues from Contracts with Customers 5,540.3 2,801.7 913.8 934.6 58.9 (901.6) 9,347.7 Other Revenues: Alternative Revenue Programs (a) (e) (8.0) (14.5) 0.3 — — (3.4) (25.6) Other Revenues (a) (f) — 17.2 — (276.2) 3.2 (2.9) (258.7) Total Other Revenues (8.0) 2.7 0.3 (276.2) 3.2 (6.3) (284.3) Total Revenues $ 5,532.3 $ 2,804.4 $ 914.1 $ 658.4 $ 62.1 $ (907.9) $ 9,063.4 (a) Amounts include affiliated and nonaffiliated revenues. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $712 million. The affiliated revenue for Vertically Integrated Utilities was $80 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $10 million. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $55 million. The remaining affiliated amounts were immaterial. (e) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. (f) Generation & Marketing includes economic hedge activity. Six Months Ended June 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 $ 2,130.1 $ 1,162.2 $ — $ — $ — $ — $ 3,292.3 Commercial Revenues 1,197.7 621.4 — — — — 1,819.1 Industrial Revenues 1,204.8 295.8 — — — (0.4) 1,500.2 Other Retail Revenues 100.3 24.4 — — — — 124.7 Total Retail Revenues 4,632.9 2,103.8 — — — (0.4) 6,736.3 Wholesale and Competitive Retail Revenues: Generation Revenues 375.5 — — 123.3 — 0.1 498.9 Transmission Revenues (a) 214.1 319.8 836.1 — — (693.8) 676.2 Renewable Generation Revenues (b) — — — 60.6 — (3.7) 56.9 Retail, Trading and Marketing Revenues (c) — — — 797.1 4.5 (11.3) 790.3 Total Wholesale and Competitive Retail Revenues 589.6 319.8 836.1 981.0 4.5 (708.7) 2,022.3 Other Revenues from Contracts with Customers (d) 110.8 119.7 — 10.2 34.8 (39.7) 235.8 Total Revenues from Contracts with Customers 5,333.3 2,543.3 836.1 991.2 39.3 (748.8) 8,994.4 Other Revenues: Alternative Revenue Programs (b) (e) 2.5 (8.0) (45.9) — — (11.8) (63.2) Other Revenues (b) (f) 0.1 13.1 — 287.7 5.1 (4.9) 301.1 Total Other Revenues 2.6 5.1 (45.9) 287.7 5.1 (16.7) 237.9 Total Revenues $ 5,335.9 $ 2,548.4 $ 790.2 $ 1,278.9 $ 44.4 $ (765.5) $ 9,232.3 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $661 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 $19 million. The remaining affiliated amounts were immaterial. (e) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. (f) Generation & Marketing includes economic hedge activity. Six Months Ended June 30, 2023 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 275.6 $ — $ 795.3 $ 424.8 $ 955.3 $ 357.4 $ 361.0 Commercial Revenues 197.9 — 334.9 280.3 536.3 240.8 297.3 Industrial Revenues (a) 74.5 — 378.3 308.5 290.4 206.1 214.8 Other Retail Revenues 17.0 — 51.4 2.5 7.4 52.5 5.2 Total Retail Revenues 565.0 — 1,559.9 1,016.1 1,789.4 856.8 878.3 Wholesale Revenues: Generation Revenues (b) — — 144.4 167.5 — 5.2 83.5 Transmission Revenues (c) 309.4 883.4 85.3 17.7 38.9 21.2 81.2 Total Wholesale Revenues 309.4 883.4 229.7 185.2 38.9 26.4 164.7 Other Revenues from Contracts with Customers (d) 20.4 7.8 24.8 66.4 78.7 9.5 14.9 Total Revenues from Contracts with Customers 894.8 891.2 1,814.4 1,267.7 1,907.0 892.7 1,057.9 Other Revenues: Alternative Revenue Program (a) (e) (4.1) (4.7) (0.2) (5.5) (10.4) (1.0) (4.2) Other Revenues (a) — — — — 17.1 — — Total Other Revenues (4.1) (4.7) (0.2) (5.5) 6.7 (1.0) (4.2) Total Revenues $ 890.7 $ 886.5 $ 1,814.2 $ 1,262.2 $ 1,913.7 $ 891.7 $ 1,053.7 (a) Amounts include affiliated and nonaffiliated revenues. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $85 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $706 million. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $35 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (e) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. Six Months Ended June 30, 2022 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 316.8 $ — $ 771.2 $ 427.0 $ 845.4 $ 351.1 $ 364.5 Commercial Revenues 205.5 — 306.5 265.2 415.8 218.7 276.5 Industrial Revenues 67.2 — 315.7 296.5 228.7 171.1 181.8 Other Retail Revenues 17.7 — 40.8 2.5 6.7 47.0 6.8 Total Retail Revenues 607.2 — 1,434.2 991.2 1,496.6 787.9 829.6 Wholesale Revenues: Generation Revenues (a) — — 119.7 184.6 — 9.8 118.6 Transmission Revenues (b) 276.9 806.4 81.9 17.5 42.9 18.7 74.5 Total Wholesale Revenues 276.9 806.4 201.6 202.1 42.9 28.5 193.1 Other Revenues from Contracts with Customers (c) 14.9 (0.1) 44.9 55.7 104.8 15.0 11.3 Total Revenues from Contracts with Customers 899.0 806.3 1,680.7 1,249.0 1,644.3 831.4 1,034.0 Other Revenues: Alternative Revenue Program (d) (e) (3.5) (41.5) 0.1 7.3 (4.5) (0.9) (2.6) Other Revenues (e) — — 0.1 (0.1) 13.1 — — Total Other Revenues (3.5) (41.5) 0.2 7.2 8.6 (0.9) (2.6) Total Revenues $ 895.5 $ 764.8 $ 1,680.9 $ 1,256.2 $ 1,652.9 $ 830.5 $ 1,031.4 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $78 million primarily relating to the PPA with KGPCo. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $653 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $29 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. (e) Amounts include affiliated and nonaffiliated revenues. Fixed Performance Obligations (Applies to AEP, APCo and I&M) The following table represents the Registrants’ remaining fixed performance obligations satisfied over time as of June 30, 2023. Fixed performance obligations primarily include electricity sales for fixed amounts of energy and stand ready services into PJM’s RPM market. The Registrants elected to apply the exemption to not disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less. Due to the annual establishment of revenue requirements, transmission revenues are excluded from the table below. The Registrant Subsidiaries amounts shown in the table below include affiliated and nonaffiliated revenues. Company 2023 2024-2025 2026-2027 After 2027 Total (in millions) AEP $ 43.6 $ 161.4 $ 137.1 $ 60.9 $ 403.0 APCo 8.1 32.2 25.4 11.6 77.3 I&M 2.2 8.8 8.8 4.5 24.3 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 June 30, 2023 and December 31, 2022. 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 June 30, 2023 and December 31, 2022. 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 June 30, 2023 and December 31, 2022. 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 June 30, 2023 December 31, 2022 (in millions) AEP Texas $ — $ 0.1 AEPTCo 123.1 113.8 APCo 68.1 64.5 I&M 47.3 75.3 OPCo 68.6 49.9 PSO 30.6 18.8 SWEPCo 42.4 19.1

Pay vs Performance Disclosure

Pay vs Performance Disclosure - USD ($) $ in Millions	3 Months Ended		6 Months Ended
Pay vs Performance Disclosure - USD ($) $ in Millions	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Pay vs Performance Disclosure
Net Income (Loss)	$ 516.1	$ 520.8	$ 916.5	$ 1,238.9

Insider Trading Arrangements

Insider Trading Arrangements	3 Months Ended
Insider Trading Arrangements	Jun. 30, 2023
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

Significant Accounting Matters

Significant Accounting Matters (Policies)	6 Months Ended
Significant Accounting Matters (Policies)	Jun. 30, 2023
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 six months ended June 30, 2023 is not necessarily indicative of results that may be expected for the year ending December 31, 2023. The condensed financial statements are unaudited and should be read in conjunction with the audited 2022 financial statements and notes thereto, which are included in the Registrants’ Annual Reports on Form 10-K as filed with the SEC on February 23, 2023.
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)	6 Months Ended
Derivatives and Hedging (Policies)	Jun. 30, 2023
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, PSO and SWEPCo) For cash flow hedges (i.e. hedging the exposure to variability in expected future cash flows that is attributable to a particular risk), the Registrants initially report the gain or loss on the derivative instrument as a component of Accumulated Other Comprehensive Income (Loss) on the balance sheets until the period the hedged item affects net income. Credit Risk Management mitigates credit risk in wholesale marketing and trading activities by assessing the creditworthiness of potential counterparties before entering into transactions with them and continuing to evaluate their creditworthiness on an ongoing basis. Management uses credit agency ratings and current market-based qualitative and quantitative data as well as financial statements to assess the financial health of counterparties on an ongoing basis. Master agreements are typically used to facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Collateral requirements in the form of cash, letters of credit 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)	6 Months Ended
Fair Value Measurements (Policies)	Jun. 30, 2023
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)	6 Months Ended
Income Taxes (Policies)	Jun. 30, 2023
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.

Variable Interest Entities (Pol

Variable Interest Entities (Policies)	6 Months Ended
Variable Interest Entities (Policies)	Jun. 30, 2023
Variable Interest Entities	The accounting guidance for “Variable Interest Entities” is a consolidation model that considers if a company has a variable interest in a VIE. A VIE is a legal entity that possesses any of the following conditions: the entity’s equity at risk is not sufficient to permit the legal entity to finance its activities without additional subordinated financial support, equity owners are unable to direct the activities that most significantly impact the legal entity’s economic performance (or they possess disproportionate voting rights in relation to the economic interest in the legal entity), or the equity owners lack the obligation to absorb the legal entity’s expected losses or the right to receive the legal entity’s expected residual returns. Entities are required to consolidate a VIE when it is determined that they have a controlling financial interest in a VIE and therefore, are the primary beneficiary of that VIE, as defined by the accounting guidance for “Variable Interest Entities.” In determining whether AEP is the primary beneficiary of a VIE, management considers whether AEP has the power to direct the most significant activities of the VIE and is obligated to absorb losses or receive the expected residual returns that are significant to the VIE. AEP holds ownership interests in businesses with varying ownership structures. AEP has not provided material financial or other support that was not previously contractually required to any of its consolidated VIEs. If an entity is determined not to be a VIE, or if the entity is determined to be a VIE and AEP is not deemed to be the primary beneficiary, the entity is accounted for under the equity method of accounting.

Significant Accounting Matter_2

Significant Accounting Matters (Tables)	6 Months Ended
Significant Accounting Matters (Tables)	Jun. 30, 2023
Reconciliation of Cash, Cash Equivalents and Restricted Cash	June 30, 2023 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 304.9 $ 0.1 $ 6.8 Restricted Cash 45.8 30.7 15.1 Total Cash, Cash Equivalents and Restricted Cash $ 350.7 $ 30.8 $ 21.9 December 31, 2022 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 509.4 $ 0.1 $ 7.5 Restricted Cash 47.1 32.7 14.4 Total Cash, Cash Equivalents and Restricted Cash $ 556.5 $ 32.8 $ 21.9
Earnings Per Share	Three Months Ended June 30, 2023 2022 (in millions, except per share data) $/share $/share Earnings Attributable to AEP Common Shareholders $ 521.2 $ 524.5 Weighted-Average Number of Basic AEP Common Shares Outstanding 514.9 $ 1.01 513.6 $ 1.02 Weighted-Average Dilutive Effect of Stock-Based Awards 1.3 — 1.6 — Weighted-Average Number of Diluted AEP Common Shares Outstanding 516.2 $ 1.01 515.2 $ 1.02 Six Months Ended June 30, 2023 2022 (in millions, except per share data) $/share $/share Earnings Attributable to AEP Common Shareholders $ 918.2 $ 1,239.2 Weighted-Average Number of Basic AEP Common Shares Outstanding 514.5 $ 1.78 509.9 $ 2.43 Weighted-Average Dilutive Effect of Stock-Based Awards 1.4 — 1.5 (0.01) Weighted-Average Number of Diluted AEP Common Shares Outstanding 515.9 $ 1.78 511.4 $ 2.42

Comprehensive Income (Tables)

Comprehensive Income (Tables)	6 Months Ended
Comprehensive Income (Tables)	Jun. 30, 2023
Changes in Accumulated Other Comprehensive Income (Loss) by Component	Cash Flow Hedges Pension Three Months Ended June 30, 2023 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of March 31, 2023 $ 65.3 $ 6.1 $ (139.5) $ (68.1) Change in Fair Value Recognized in AOCI, Net of Tax 5.9 7.0 — 12.9 Amount of (Gain) Loss Reclassified from AOCI Purchased Electricity, Fuel and Other Consumables Used for Electric Generation (a) 28.3 — — 28.3 Interest Expense (a) — (0.5) — (0.5) Amortization of Prior Service Cost (Credit) — — (5.3) (5.3) Amortization of Actuarial (Gains) Losses — — 1.4 1.4 Reclassifications from AOCI, before Income Tax (Expense) Benefit 28.3 (0.5) (3.9) 23.9 Income Tax (Expense) Benefit 6.0 (0.1) (0.8) 5.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 22.3 (0.4) (3.1) 18.8 Net Current Period Other Comprehensive Income (Loss) 28.2 6.6 (3.1) 31.7 Balance in AOCI as of June 30, 2023 $ 93.5 $ 12.7 $ (142.6) $ (36.4) Cash Flow Hedges Pension Three Months Ended June 30, 2022 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of March 31, 2022 $ 404.0 $ (13.6) $ 40.2 $ 430.6 Change in Fair Value Recognized in AOCI, Net of Tax 257.3 2.0 — 259.3 Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (a) 0.1 — — 0.1 Purchased Electricity, Fuel and Other Consumables Used for Electric Generation (a) (161.8) — — (161.8) Interest Expense (a) — 1.1 — 1.1 Amortization of Prior Service Cost (Credit) — — (5.4) (5.4) Amortization of Actuarial (Gains) Losses — — 2.1 2.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit (161.7) 1.1 (3.3) (163.9) Income Tax (Expense) Benefit (34.0) 0.3 (0.7) (34.4) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (127.7) 0.8 (2.6) (129.5) 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) 129.6 2.8 (11.6) 120.8 Balance in AOCI as of June 30, 2022 $ 533.6 $ (10.8) $ 28.6 $ 551.4 Cash Flow Hedges Pension Six Months Ended June 30, 2023 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2022 $ 223.5 $ 0.3 $ (140.1) $ 83.7 Change in Fair Value Recognized in AOCI, Net of Tax (189.4) 12.2 (12.9) (190.1) Amount of (Gain) Loss Reclassified from AOCI Purchased Electricity, Fuel and Other Consumables Used for Electric Generation (a) 75.3 — — 75.3 Interest Expense (a) — 0.2 — 0.2 Amortization of Prior Service Cost (Credit) — — (10.6) (10.6) Amortization of Actuarial (Gains) Losses — — 2.6 2.6 Reclassifications from AOCI, before Income Tax (Expense) Benefit 75.3 0.2 (8.0) 67.5 Income Tax (Expense) Benefit 15.9 — (1.7) 14.2 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 59.4 0.2 (6.3) 53.3 Reclassifications of KPCo Pension and OPEB Regulatory Assets from AOCI — — 21.1 21.1 Income Tax (Expense) Benefit — — 4.4 4.4 Reclassifications of KPCo Pension and OPEB Regulatory Assets from AOCI, Net of Income Tax (Expense) Benefit — — 16.7 16.7 Net Current Period Other Comprehensive Income (Loss) (130.0) 12.4 (2.5) (120.1) Balance in AOCI as of June 30, 2023 $ 93.5 $ 12.7 $ (142.6) $ (36.4) Cash Flow Hedges Pension Six Months Ended June 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, Net of Tax 535.5 8.8 — 544.3 Amount of (Gain) Loss Reclassified from AOCI Purchased Electricity, Fuel and Other Consumables Used for Electric Generation (a) (209.7) — — (209.7) Interest Expense (a) — 2.2 — 2.2 Amortization of Prior Service Cost (Credit) — — (10.3) (10.3) Amortization of Actuarial (Gains) Losses — — 4.2 4.2 Reclassifications from AOCI, before Income Tax (Expense) Benefit (209.7) 2.2 (6.1) (213.6) Income Tax (Expense) Benefit (44.1) 0.5 (1.3) (44.9) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (165.6) 1.7 (4.8) (168.7) 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) 369.9 10.5 (13.8) 366.6 Balance in AOCI as of June 30, 2022 $ 533.6 $ (10.8) $ 28.6 $ 551.4 (a) Amounts reclassified to the referenced line item on the statements of income.

Rate Matters (Tables)

Rate Matters (Tables)	6 Months Ended
Rate Matters (Tables)	Jun. 30, 2023
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 $ 120.5 $ 154.9 $ 20.4 (b) 2026 (c) $ 14.9 Welsh Plant, Units 1 and 3 384.3 105.4 58.2 (d) 2028 (e) (f) 38.6 (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 the removal of Northeastern Plant, Unit 3, after retirement. (c) Northeastern Plant, Unit 3 is currently being recovered through 2040. (d) Includes Welsh Plant, Unit 2, which was retired in 2016. Removal of Welsh Plant, Unit 2, will be performed with the removal of Welsh Plant, Units 1 and 3, after retirement. (e) Represents projected retirement date of coal assets, units are being evaluated for conversion to natural gas after 2028.
Regulatory Assets Pending Final Regulatory Approval	AEP June 30, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Pirkey Plant Accelerated Depreciation $ 111.8 $ 116.5 Unrecovered Winter Storm Fuel Costs (a) 109.5 121.7 Welsh Plant, Units 1 and 3 Accelerated Depreciation 105.4 85.6 Dolet Hills Power Station Fuel Costs - Louisiana 33.9 32.0 Texas Mobile Generation Costs 29.4 17.6 Other Regulatory Assets Pending Final Regulatory Approval 21.4 19.3 Regulatory Assets Currently Not Earning a Return Storm-Related Costs (b)(c)(d) 395.4 407.2 2020-2022 Virginia Triennial Under-Earnings 35.0 37.9 Plant Retirement Costs – Asset Retirement Obligation Costs 25.9 25.9 Other Regulatory Assets Pending Final Regulatory Approval 49.3 55.6 Total Regulatory Assets Pending Final Regulatory Approval $ 917.0 $ 919.3 (a) Includes $37 million and $37 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of June 30, 2023 and December 31, 2022, respectively. See the “February 2021 Severe Winter Weather Impacts in SPP” section below for additional information. (b) In April 2023, OPCo filed a request with the PUCO for recovery of $34 million in Ohio storm-related costs. (c) In April 2023, the LPSC issued an order approving the prudence and future recovery of the Louisiana storm-related regulatory assets. See “2021 Louisiana Storm Cost Filing” section below for additional information. (d) In June 2023, storms in the Oklahoma, Louisiana and Texas service territories caused power outages and extensive damage resulting in the deferral of $52 million, $28 million and $20 million, respectively. Recovery of these storm costs will be addressed in a future request. AEP Texas June 30, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Texas Mobile Generation Costs $ 29.4 $ 17.6 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 34.9 26.7 Vegetation Management Program 5.2 5.2 Texas Retail Electric Provider Bad Debt Expense 4.1 4.1 Other Regulatory Assets Pending Final Regulatory Approval 13.6 13.4 Total Regulatory Assets Pending Final Regulatory Approval $ 87.2 $ 67.0 APCo June 30, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return COVID-19 – Virginia $ 7.2 $ 7.0 Regulatory Assets Currently Not Earning a Return Storm-Related Costs - West Virginia 72.0 72.6 2020-2022 Virginia Triennial Under-Earnings 35.0 37.9 Plant Retirement Costs – Asset Retirement Obligation Costs 25.9 25.9 Other Regulatory Assets Pending Final Regulatory Approval 5.5 1.1 Total Regulatory Assets Pending Final Regulatory Approval $ 145.6 $ 144.5 I&M June 30, December 31, 2023 2022 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 Storm-Related Costs - Indiana 23.9 21.6 Other Regulatory Assets Pending Final Regulatory Approval 2.7 2.0 Total Regulatory Assets Pending Final Regulatory Approval $ 26.7 $ 23.7 OPCo June 30, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Not Earning a Return Storm-Related Costs (a) $ 52.7 $ 33.8 Other Regulatory Assets Pending Final Regulatory Approval 0.1 — Total Regulatory Assets Pending Final Regulatory Approval $ 52.8 $ 33.8 (a) In April 2023, OPCo filed a request with the PUCO for recovery of $34 million in storm costs. PSO June 30, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Not Earning a Return Storm-Related Costs (a) $ 84.6 $ 25.5 Other Regulatory Assets Pending Final Regulatory Approval 0.2 0.1 Total Regulatory Assets Pending Final Regulatory Approval $ 84.8 $ 25.6 (a) In June 2023, storms caused power outages and extensive damage to the Oklahoma service territory, resulting in the deferral of $52 million. Recovery for these storm costs will be included in a future request. SWEPCo June 30, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Pirkey Plant Accelerated Depreciation $ 111.8 $ 116.5 Unrecovered Winter Storm Fuel Costs (a) 109.5 121.7 Welsh Plant, Units 1 and 3 Accelerated Depreciation 105.4 85.6 Dolet Hills Power Station Fuel Costs - Louisiana 33.9 32.0 Dolet Hills Power Station 12.1 9.7 Other Regulatory Assets Pending Final Regulatory Approval 1.9 2.5 Regulatory Assets Currently Not Earning a Return Storm-Related Costs (b)(c) 48.0 151.5 Asset Retirement Obligation - Louisiana — 11.8 Other Regulatory Assets Pending Final Regulatory Approval 15.9 16.0 Total Regulatory Assets Pending Final Regulatory Approval $ 438.5 $ 547.3 (a) Includes $37 million and $37 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of June 30, 2023 and December 31, 2022, respectively. See the “February 2021 Severe Winter Weather Impacts in SPP” section below for additional information. (b) In April 2023, the LPSC issued an order approving the prudence and future recovery of the Louisiana storm-related regulatory assets. See “2021 Louisiana Storm Cost Filing” section below for additional information. (c) In June 2023, additional storms in the Louisiana and Texas service territories caused power outages and extensive damage resulting in the deferral of $28 million and $20 million, respectively. Recovery of these storm costs will be addressed in a future request.
Southwestern Electric Power Co [Member] \| February 2021 Severe Storm Fuel Costs
Natural Gas Expenses and Purchases of Electricity to be Recovered from Customers [Table Text Block]	Jurisdiction June 30, 2023 December 31, 2022 Approved Recovery Period Approved Carrying Charge (in millions) Arkansas $ 66.4 $ 74.9 6 years (a) Louisiana 109.5 121.7 (b) (b) Texas 117.8 132.4 5 years 1.65% Total $ 293.7 $ 329.0 (a) SWEPCo is permitted to record carrying costs on the unrecovered balance of fuel costs at a weighted-cost of capital approved by the APSC. (b) In March 2021, the LPSC approved a special order granting a temporary modification to the FAC and shortly after SWEPCo began recovery of its Louisiana jurisdictional share of these fuel costs based on a five-year recovery period inclusive of an interim carrying charge equal to the prime rate. The special order states the fuel and purchased power costs incurred will be subject to a future LPSC audit.

Commitments, Guarantees and C_2

Commitments, Guarantees and Contingencies (Tables)	6 Months Ended
Commitments, Guarantees and Contingencies (Tables)	Jun. 30, 2023
Maximum Future Payments for Letters of Credit Uncommitted Facilities	Company Amount Maturity (in millions) AEP $ 288.8 July 2023 to June 2024 AEP Texas 1.8 July 2023
Max Potential Loss on Master Lease Agreements	Company Maximum (in millions) AEP $ 45.0 AEP Texas 10.9 APCo 5.6 I&M 4.2 OPCo 7.0 PSO 4.7 SWEPCo 5.4

Discontinued Operations and Dis

Discontinued Operations and Disposal Groups (Tables)	6 Months Ended
Discontinued Operations and Disposal Groups (Tables)	Jun. 30, 2023
Discontinued Operations and Disposal Groups [Abstract]
Assets and Liabilities HFS - Contracted Renewables	June 30, 2023 (in millions) ASSETS Accounts Receivable and Accrued Unbilled Revenues $ 10.0 Property, Plant and Equipment, Net 1,394.0 Other Classes of Assets that are not Major 67.3 Total Major Classes of Assets Held for Sale 1,471.3 Loss on the Expected Sale of the Competitive Contracted Renewables Portfolio (net of $23.5 million of Income Taxes) (88.5) Assets Held for Sale $ 1,382.8 LIABILITIES Accounts Payable $ 4.6 Asset Retirement Obligations 31.0 Obligations Under Operating Leases 21.6 Other Classes of Liabilities that are not Major 7.6 Liabilities Held for Sale $ 64.8

Benefit Plans (Tables)

Benefit Plans (Tables)	6 Months Ended
Benefit Plans (Tables)	Jun. 30, 2023
Components of Net Periodic Benefit Cost	Pension Plans Three Months Ended June 30, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 23.6 $ 2.1 $ 2.2 $ 3.0 $ 2.1 $ 1.4 $ 1.9 Interest Cost 54.8 4.6 6.6 6.2 5.0 2.7 3.5 Expected Return on Plan Assets (84.8) (7.0) (11.1) (11.1) (8.5) (4.6) (4.9) Amortization of Net Actuarial Loss 0.4 — — — — — — Net Periodic Benefit Cost (Credit) $ (6.0) $ (0.3) $ (2.3) $ (1.9) $ (1.4) $ (0.5) $ 0.5 Three Months Ended June 30, 2022 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 30.8 $ 2.8 $ 2.8 $ 4.1 $ 2.9 $ 1.8 $ 2.7 Interest Cost 37.1 3.0 4.4 4.2 3.2 1.7 2.3 Expected Return on Plan Assets (63.3) (5.2) (8.1) (8.1) (6.2) (3.4) (3.6) Amortization of Net Actuarial Loss 15.7 1.3 1.8 1.7 1.4 0.8 0.9 Net Periodic Benefit Cost $ 20.3 $ 1.9 $ 0.9 $ 1.9 $ 1.3 $ 0.9 $ 2.3 Six Months Ended June 30, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 47.2 $ 4.1 $ 4.5 $ 6.0 $ 4.2 $ 2.8 $ 3.8 Interest Cost 109.6 9.2 13.2 12.4 9.9 5.4 7.0 Expected Return on Plan Assets (169.6) (14.0) (22.3) (22.1) (17.0) (9.2) (9.7) Amortization of Net Actuarial Loss 0.7 — — — — — — Net Periodic Benefit Cost (Credit) $ (12.1) $ (0.7) $ (4.6) $ (3.7) $ (2.9) $ (1.0) $ 1.1 Six Months Ended June 30, 2022 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 61.6 $ 5.6 $ 5.7 $ 8.1 $ 5.6 $ 3.7 $ 5.3 Interest Cost 74.1 6.0 8.8 8.4 6.6 3.5 4.6 Expected Return on Plan Assets (126.7) (10.5) (16.2) (16.1) (12.4) (6.8) (7.3) Amortization of Net Actuarial Loss 31.5 2.6 3.6 3.5 2.8 1.5 1.9 Net Periodic Benefit Cost $ 40.5 $ 3.7 $ 1.9 $ 3.9 $ 2.6 $ 1.9 $ 4.5 OPEB Three Months Ended June 30, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 1.2 $ 0.1 $ 0.2 $ 0.2 $ 0.1 $ — $ 0.1 Interest Cost 11.5 0.9 1.9 1.4 1.1 0.6 0.7 Expected Return on Plan Assets (27.4) (2.2) (4.0) (3.4) (3.0) (1.4) (1.8) Amortization of Prior Service Credit (15.7) (1.4) (2.3) (2.1) (1.5) (1.0) (1.2) Amortization of Net Actuarial Loss 3.7 0.3 0.5 0.4 0.4 0.2 0.3 Net Periodic Benefit Credit $ (26.7) $ (2.3) $ (3.7) $ (3.5) $ (2.9) $ (1.6) $ (1.9) Three Months Ended June 30, 2022 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 1.9 $ 0.1 $ 0.2 $ 0.3 $ 0.1 $ 0.1 $ 0.2 Interest Cost 7.3 0.5 1.1 0.9 0.8 0.3 0.4 Expected Return on Plan Assets (27.5) (2.2) (4.0) (3.5) (2.9) (1.5) (1.8) Amortization of Prior Service Credit (17.9) (1.5) (2.6) (2.5) (1.8) (1.1) (1.3) Net Periodic Benefit Credit $ (36.2) $ (3.1) $ (5.3) $ (4.8) $ (3.8) $ (2.2) $ (2.5) Six Months Ended June 30, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 2.3 $ 0.2 $ 0.3 $ 0.4 $ 0.2 $ 0.1 $ 0.2 Interest Cost 23.1 1.8 3.7 2.7 2.3 1.2 1.4 Expected Return on Plan Assets (54.8) (4.5) (8.0) (6.8) (5.9) (2.9) (3.6) Amortization of Prior Service Credit (31.5) (2.7) (4.6) (4.3) (3.1) (2.0) (2.4) Amortization of Net Actuarial Loss 7.4 0.6 1.1 0.9 0.8 0.4 0.5 Net Periodic Benefit Credit $ (53.5) $ (4.6) $ (7.5) $ (7.1) $ (5.7) $ (3.2) $ (3.9) Six Months Ended June 30, 2022 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 3.7 $ 0.2 $ 0.4 $ 0.5 $ 0.3 $ 0.2 $ 0.3 Interest Cost 14.6 1.1 2.3 1.7 1.5 0.7 0.9 Expected Return on Plan Assets (55.0) (4.5) (8.1) (6.9) (5.9) (3.0) (3.7) Amortization of Prior Service Credit (35.7) (3.0) (5.2) (4.9) (3.6) (2.2) (2.6) Net Periodic Benefit Credit $ (72.4) $ (6.2) $ (10.6) $ (9.6) $ (7.7) $ (4.3) $ (5.1)

Business Segments (Tables)

Business Segments (Tables)	6 Months Ended
Business Segments (Tables)	Jun. 30, 2023
Segment Reporting Information [Line Items]
Reportable Segment Information	Three Months Ended June 30, 2023 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) Revenues from: External Customers $ 2,629.0 $ 1,330.8 $ 88.3 $ 318.2 $ 6.2 $ — $ 4,372.5 Other Operating Segments 45.5 9.4 370.3 13.2 25.8 (464.2) — Total Revenues $ 2,674.5 $ 1,340.2 $ 458.6 $ 331.4 $ 32.0 $ (464.2) $ 4,372.5 Net Income (Loss) $ 278.4 $ 176.7 $ 197.3 $ (38.6) $ (97.7) $ — $ 516.1 Three Months Ended June 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 $ 2,595.0 $ 1,296.8 $ 79.1 $ 654.4 $ 14.4 $ — $ 4,639.7 Other Operating Segments 53.5 4.8 299.7 5.2 10.1 (373.3) — Total Revenues $ 2,648.5 $ 1,301.6 $ 378.8 $ 659.6 $ 24.5 $ (373.3) $ 4,639.7 Net Income (Loss) $ 303.3 $ 164.8 $ 142.7 $ 65.9 $ (155.9) $ — $ 520.8 Six Months Ended June 30, 2023 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) Revenues from: External Customers $ 5,445.3 $ 2,786.1 $ 178.4 $ 645.1 $ 8.5 $ — $ 9,063.4 Other Operating Segments 87.0 18.3 735.7 13.3 53.6 (907.9) — Total Revenues $ 5,532.3 $ 2,804.4 $ 914.1 $ 658.4 $ 62.1 $ (907.9) $ 9,063.4 Net Income (Loss) $ 540.6 $ 302.4 $ 379.7 $ (195.0) $ (111.2) $ — $ 916.5 Six Months Ended June 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 $ 5,241.8 $ 2,539.0 $ 162.5 $ 1,263.9 $ 25.1 $ — $ 9,232.3 Other Operating Segments 94.1 9.4 627.7 15.0 19.3 (765.5) — Total Revenues $ 5,335.9 $ 2,548.4 $ 790.2 $ 1,278.9 $ 44.4 $ (765.5) $ 9,232.3 Net Income (Loss) $ 602.5 $ 317.6 $ 316.4 $ 181.9 $ (179.5) $ — $ 1,238.9 June 30, 2023 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Consolidated (in millions) Total Assets (d) $ 51,047.3 $ 23,900.0 $ 16,023.5 $ 4,457.9 $ 6,451.4 (b) $ (5,878.0) (c) $ 96,002.1 December 31, 2022 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Consolidated (in millions) Total Assets $ 49,761.8 $ 22,920.2 $ 15,215.8 $ 4,520.1 $ 6,768.4 (b) $ (5,783.0) (c) $ 93,403.3 (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 “Planned Disposition of the Competitive Contracted Renewables Portfolio” section of Note 6 for additional information. Three Months Ended June 30, 2023 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Revenues from: External Customers $ 87.4 $ — $ — $ 87.4 Sales to AEP Affiliates 357.5 — — 357.5 Total Revenues $ 444.9 $ — $ — $ 444.9 Net Income $ 174.2 $ 1.5 (a) $ — $ 175.7 Three Months Ended June 30, 2022 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Revenues from: External Customers $ 77.3 $ — $ — $ 77.3 Sales to AEP Affiliates 287.1 — — 287.1 Total Revenues $ 364.4 $ — $ — $ 364.4 Net Income $ 118.4 $ 0.1 (a) $ — $ 118.5 Six Months Ended June 30, 2023 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo Consolidated (in millions) Revenues from: External Customers $ 176.4 $ — $ — $ 176.4 Sales to AEP Affiliates 710.1 — — 710.1 Total Revenues $ 886.5 $ — $ — $ 886.5 Net Income $ 335.8 $ 2.6 (a) $ — $ 338.4 Six Months Ended June 30, 2022 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo Consolidated (in millions) Revenues from: External Customers $ 162.3 $ — $ — $ 162.3 Sales to AEP Affiliates 602.5 — — 602.5 Total Revenues $ 764.8 $ — $ — $ 764.8 Net Income $ 273.8 $ 0.1 (a) $ — $ 273.9 June 30, 2023 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Total Assets $ 14,626.3 $ 5,542.1 (b) $ (5,591.9) (c) $ 14,576.5 December 31, 2022 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Total Assets $ 13,875.6 $ 4,817.4 (b) $ (4,878.8) (c) $ 13,814.2 (a) Includes the elimination of AEPTCo Parent’s equity earnings in the State Transcos. (b) Primarily relates to Notes Receivable from the State Transcos. (c) Primarily relates to the elimination of Notes Receivable from the State Transcos.

Derivatives and Hedging (Tables

Derivatives and Hedging (Tables)	6 Months Ended
Derivatives and Hedging (Tables)	Jun. 30, 2023
Notional Volume of Derivative Instruments	Notional Volume of Derivative Instruments June 30, 2023 Primary Risk Unit of AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power MWhs 269.9 — 29.1 9.2 2.3 8.7 6.9 Natural Gas MMBtus 136.8 — 5.2 — — 28.3 7.3 Heating Oil and Gasoline Gallons 6.7 1.8 1.0 0.6 1.4 0.9 0.9 Interest Rate USD $ 91.4 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt USD $ 950.0 $ — $ — $ — $ — $ — $ — December 31, 2022 Primary Risk Unit of AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power MWhs 226.8 — 17.9 4.2 2.5 2.9 2.2 Natural Gas MMBtus 77.1 — 1.9 — — 1.9 2.1 Heating Oil and Gasoline Gallons 6.9 1.9 1.0 0.7 1.4 0.9 1.0 Interest Rate USD $ 99.9 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt USD $ 1,650.0 $ — $ — $ — $ — $ 200.0 $ —
Fair Value of Derivative Instruments	AEP June 30, 2023 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 $ 721.6 $ 43.4 $ — $ 765.0 $ (485.5) $ 279.5 Long-term Risk Management Assets 466.4 95.1 — 561.5 (294.7) 266.8 Total Assets 1,188.0 138.5 — 1,326.5 (780.2) 546.3 Current Risk Management Liabilities 631.5 12.8 42.6 686.9 (510.7) 176.2 Long-term Risk Management Liabilities 418.5 6.7 82.1 507.3 (232.0) 275.3 Total Liabilities 1,050.0 19.5 124.7 1,194.2 (742.7) 451.5 Total MTM Derivative Contract Net Assets (Liabilities) $ 138.0 $ 119.0 $ (124.7) $ 132.3 $ (37.5) $ 94.8 December 31, 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 $ 965.4 $ 212.2 $ 1.8 $ 1,179.4 $ (830.6) $ 348.8 Long-term Risk Management Assets 565.6 148.9 14.3 728.8 (444.7) 284.1 Total Assets 1,531.0 361.1 16.1 1,908.2 (1,275.3) 632.9 Current Risk Management Liabilities 663.8 60.4 41.4 765.6 (620.4) 145.2 Long-term Risk Management Liabilities 412.0 17.4 91.1 520.5 (175.3) 345.2 Total Liabilities 1,075.8 77.8 132.5 1,286.1 (795.7) 490.4 Total MTM Derivative Contract Net Assets (Liabilities) $ 455.2 $ 283.3 $ (116.4) $ 622.1 $ (479.6) $ 142.5 AEP Texas June 30, 2023 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 $ — $ — $ — Long-term Risk Management Assets — — — Total Assets — — — Current Risk Management Liabilities 0.4 (0.4) — Long-term Risk Management Liabilities 0.1 (0.1) — Total Liabilities 0.5 (0.5) — Total MTM Derivative Contract Net Assets (Liabilities) $ (0.5) $ 0.5 $ — December 31, 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 $ — $ — $ — Long-term Risk Management Assets — — — Total Assets — — — Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — — — Total Liabilities — — — Total MTM Derivative Contract Net Assets $ — $ — $ — APCo June 30, 2023 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 $ 42.5 $ (3.3) $ 39.2 Long-term Risk Management Assets 0.6 (0.4) 0.2 Total Assets 43.1 (3.7) 39.4 Current Risk Management Liabilities 5.1 (4.0) 1.1 Long-term Risk Management Liabilities 0.4 (0.4) — Total Liabilities 5.5 (4.4) 1.1 Total MTM Derivative Contract Net Assets $ 37.6 $ 0.7 $ 38.3 December 31, 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 $ 69.3 $ (0.2) $ 69.1 Long-term Risk Management Assets 0.7 (0.7) — Total Assets 70.0 (0.9) 69.1 Current Risk Management Liabilities 4.1 (0.5) 3.6 Long-term Risk Management Liabilities 0.7 (0.6) 0.1 Total Liabilities 4.8 (1.1) 3.7 Total MTM Derivative Contract Net Assets $ 65.2 $ 0.2 $ 65.4 I&M June 30, 2023 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 $ 22.3 $ (0.9) $ 21.4 Long-term Risk Management Assets 11.8 (2.7) 9.1 Total Assets 34.1 (3.6) 30.5 Current Risk Management Liabilities 2.8 (1.4) 1.4 Long-term Risk Management Liabilities 2.7 (2.7) — Total Liabilities 5.5 (4.1) 1.4 Total MTM Derivative Contract Net Assets $ 28.6 $ 0.5 $ 29.1 December 31, 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 $ 16.0 $ (0.8) $ 15.2 Long-term Risk Management Assets 0.5 (0.3) 0.2 Total Assets 16.5 (1.1) 15.4 Current Risk Management Liabilities 0.9 (0.9) — Long-term Risk Management Liabilities 0.3 (0.3) — Total Liabilities 1.2 (1.2) — Total MTM Derivative Contract Net Assets $ 15.3 $ 0.1 $ 15.4 OPCo June 30, 2023 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 $ — $ — $ — Long-term Risk Management Assets — — — Total Assets — — — Current Risk Management Liabilities 6.6 (0.3) 6.3 Long-term Risk Management Liabilities 47.8 (0.1) 47.7 Total Liabilities 54.4 (0.4) 54.0 Total MTM Derivative Contract Net Assets (Liabilities) $ (54.4) $ 0.4 $ (54.0) December 31, 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 $ — $ — $ — Long-term Risk Management Assets — — — Total Assets — — — Current Risk Management Liabilities 2.1 (0.3) 1.8 Long-term Risk Management Liabilities 37.9 — 37.9 Total Liabilities 40.0 (0.3) 39.7 Total MTM Derivative Contract Net Assets (Liabilities) $ (40.0) $ 0.3 $ (39.7) PSO June 30, 2023 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 $ 47.4 $ (2.6) $ 44.8 Long-term Risk Management Assets 0.2 (0.2) — Total Assets 47.6 (2.8) 44.8 Current Risk Management Liabilities 5.4 (2.8) 2.6 Long-term Risk Management Liabilities 1.0 (0.2) 0.8 Total Liabilities 6.4 (3.0) 3.4 Total MTM Derivative Contract Net Assets $ 41.2 $ 0.2 $ 41.4 December 31, 2022 Risk Management Contracts – Hedging Contracts Gross Amounts of Risk Management Assets/Liabilities Recognized Gross Amounts Offset in the Statement of Financial Position (b) Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position (c) Balance Sheet Location Commodity (a) Interest Rate (a) (in millions) Current Risk Management Assets $ 24.1 $ 1.6 $ 25.7 $ (0.4) $ 25.3 Long-term Risk Management Assets — — — — — Total Assets 24.1 1.6 25.7 (0.4) 25.3 Current Risk Management Liabilities 2.1 — 2.1 (0.5) 1.6 Long-term Risk Management Liabilities — — — — — Total Liabilities 2.1 — 2.1 (0.5) 1.6 Total MTM Derivative Contract Net Assets $ 22.0 $ 1.6 $ 23.6 $ 0.1 $ 23.7 SWEPCo June 30, 2023 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 $ 28.5 $ (0.5) $ 28.0 Long-term Risk Management Assets — — — Total Assets 28.5 (0.5) 28.0 Current Risk Management Liabilities 2.4 (0.8) 1.6 Long-term Risk Management Liabilities 0.2 — 0.2 Total Liabilities 2.6 (0.8) 1.8 Total MTM Derivative Contract Net Assets $ 25.9 $ 0.3 $ 26.2 December 31, 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 $ 16.8 $ (0.4) $ 16.4 Long-term Risk Management Assets — — — Total Assets 16.8 (0.4) 16.4 Current Risk Management Liabilities 2.0 (0.6) 1.4 Long-term Risk Management Liabilities — — — Total Liabilities 2.0 (0.6) 1.4 Total MTM Derivative Contract Net Assets $ 14.8 $ 0.2 $ 15.0 (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.”
Amount of Gain (Loss) Recognized on Risk Management Contracts	Amount of Gain (Loss) Recognized on Risk Management Contracts Three Months Ended June 30, 2023 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 17.0 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues (141.8) — — — — — — Electric Generation, Transmission and Distribution Revenues — — — 17.0 — — — Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 1.3 — 1.3 0.1 — — — Other Operation (0.1) — — — — — — Maintenance (0.3) (0.1) — — — — — Regulatory Assets (a) (12.4) (0.1) 5.9 (1.6) (12.8) (2.3) (0.9) Regulatory Liabilities (a) 102.0 — 17.4 3.6 — 42.4 33.6 Total Gain (Loss) on Risk Management Contracts $ (34.3) $ (0.2) $ 24.6 $ 19.1 $ (12.8) $ 40.1 $ 32.7 Three Months Ended June 30, 2022 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 0.1 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 121.0 — — — — — — Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 0.9 — 0.7 — — 0.1 — Other Operation 1.7 0.5 0.2 0.2 0.3 0.2 0.3 Maintenance 2.4 0.7 0.4 0.2 0.4 0.3 0.4 Regulatory Assets (a) 21.4 0.1 0.1 0.3 21.0 — (0.1) Regulatory Liabilities (a) 110.4 — 21.6 1.5 1.6 39.0 36.9 Total Gain on Risk Management Contracts $ 257.9 $ 1.3 $ 23.0 $ 2.2 $ 23.3 $ 39.6 $ 37.5 Six Months Ended June 30, 2023 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 11.7 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues (289.2) — — — — — — Electric Generation, Transmission and Distribution Revenues — — — 11.7 — — — Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 2.0 — 1.9 0.1 — — — Other Operation (0.1) — — — — — — Maintenance (0.2) (0.1) — — — — — Regulatory Assets (a) (37.2) (0.5) (1.2) (2.1) (25.1) (3.5) (2.4) Regulatory Liabilities (a) 100.5 — (8.8) 4.8 — 60.4 45.5 Total Gain (Loss) on Risk Management Contracts $ (212.5) $ (0.6) $ (8.1) $ 14.5 $ (25.1) $ 56.9 $ 43.1 Six Months Ended June 30, 2022 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 0.1 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 273.3 — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.1 (0.1) — — — Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 2.4 — 2.1 — — 0.1 — Other Operation 2.3 0.7 0.2 0.3 0.4 0.3 0.4 Maintenance 3.2 0.9 0.5 0.3 0.5 0.4 0.5 Regulatory Assets (a) 45.0 0.1 — (1.3) 44.9 3.6 (2.2) Regulatory Liabilities (a) 146.9 0.9 20.2 3.2 1.6 51.7 57.8 Total Gain on Risk Management Contracts $ 473.2 $ 2.6 $ 23.1 $ 2.4 $ 47.4 $ 56.1 $ 56.5 (a) Represents realized and unrealized gains and losses subject to regulatory accounting treatment recorded as either current or noncurrent on the balance sheets.
Impact of Fair Value Hedges on 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 June 30, 2023 December 31, 2022 June 30, 2023 December 31, 2022 (in millions) Long-term Debt (a) (b) $ (855.1) $ (855.5) $ 90.8 $ 89.7 (a) Amounts included on the Balance Sheet within Noncurrent Liabilities line item Long-term Debt.
Gain (Loss) on Hedging Instruments	Three Months Ended June 30, Six Months Ended June 30, 2023 2022 2023 2022 (in millions) Gain (Loss) on Interest Rate Contracts: Fair Value Hedging Instruments (a) $ (4.2) $ (17.6) $ 2.7 $ (62.4) Fair Value Portion of Long-term Debt (a) 4.2 17.6 (2.7) 62.4 (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 June 30, 2023 December 31, 2022 Commodity Interest Rate Commodity Interest Rate (in millions) AOCI Gain Net of Tax $ 93.5 $ 12.7 $ 223.5 $ 0.3 Portion Expected to be Reclassed to Net Income During the Next Twelve Months 24.1 4.3 119.9 0.3 Impact of Cash Flow Hedges on the Registrant Subsidiaries’ Balance Sheets June 30, 2023 December 31, 2022 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 $ 2.9 $ 0.3 $ (0.3) $ (0.2) APCo 6.3 0.8 6.7 0.8 I&M (5.7) (0.4) (5.1) (0.6) PSO (0.2) — 1.3 0.1 SWEPCo 1.4 0.3 1.1 0.2

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
Fair Value Measurements (Tables)	Jun. 30, 2023
Book Values and Fair Values of Long-term Debt	June 30, 2023 December 31, 2022 Company Book Value Fair Value Book Value Fair Value (in millions) AEP (a) $ 40,142.3 $ 36,351.3 $ 36,801.0 $ 32,915.9 AEP Texas 5,937.5 5,295.5 5,657.8 5,045.8 AEPTCo 5,473.0 4,719.2 4,782.8 3,940.5 APCo 5,599.7 5,298.4 5,410.5 5,079.2 I&M 3,464.1 3,174.2 3,260.8 2,929.0 OPCo 3,365.6 2,878.8 2,970.3 2,516.6 PSO 2,383.9 2,106.1 1,912.8 1,635.8 SWEPCo 3,645.6 3,135.3 3,391.6 2,870.9
Other Temporary Investments	June 30, 2023 Gross Gross Unrealized Unrealized Fair Other Temporary Investments and Restricted Cash Cost Gains Losses Value (in millions) Restricted Cash (a) $ 45.8 $ — $ — $ 45.8 Other Cash Deposits 15.9 — — 15.9 Fixed Income Securities – Mutual Funds (b) 155.7 — (8.9) 146.8 Equity Securities – Mutual Funds 15.4 24.4 — 39.8 Total Other Temporary Investments and Restricted Cash $ 232.8 $ 24.4 $ (8.9) $ 248.3 December 31, 2022 Gross Gross Unrealized Unrealized Fair Other Temporary Investments and Restricted Cash Cost Gains Losses Value (in millions) Restricted Cash (a) $ 47.1 $ — $ — $ 47.1 Other Cash Deposits 9.0 — — 9.0 Fixed Income Securities – Mutual Funds (b) 152.4 — (8.3) 144.1 Equity Securities – Mutual Funds 15.1 19.4 — 34.5 Total Other Temporary Investments and Restricted Cash $ 223.6 $ 19.4 $ (8.3) $ 234.7 (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 June 30, Six Months Ended June 30, 2023 2022 2023 2022 (in millions) Proceeds from Investment Sales $ — $ 11.1 $ — $ 15.0 Purchases of Investments 1.3 0.8 2.3 1.6 Gross Realized Gains on Investment Sales — 3.3 — 3.6 Gross Realized Losses on Investment Sales — 0.4 — 0.5
Nuclear Trust Fund Investments	June 30, 2023 December 31, 2022 Gross Gross Other-Than- Gross Gross Other-Than- Fair Unrealized Unrealized Temporary Fair Unrealized Unrealized Temporary Value Gains Losses Impairments Value Gains Losses Impairments (in millions) Cash and Cash Equivalents $ 24.2 $ — $ — $ — $ 21.2 $ — $ — $ — Fixed Income Securities: United States Government 1,191.9 9.9 (13.8) (25.6) 1,123.8 11.8 (14.9) (18.8) Corporate Debt 68.8 0.8 (6.6) (1.7) 61.6 0.7 (7.7) (9.6) State and Local Government 3.3 — — — 3.3 0.1 — (0.1) Subtotal Fixed Income Securities 1,264.0 10.7 (20.4) (27.3) 1,188.7 12.6 (22.6) (28.5) Equity Securities - Domestic 2,360.6 1,725.7 (4.6) — 2,131.3 1,483.7 (6.4) — Spent Nuclear Fuel and Decommissioning Trusts $ 3,648.8 $ 1,736.4 $ (25.0) $ (27.3) $ 3,341.2 $ 1,496.3 $ (29.0) $ (28.5)
Securities Activity Within the Decommissioning and SNF Trusts	Three Months Ended June 30, Six Months Ended June 30, 2023 2022 2023 2022 (in millions) Proceeds from Investment Sales $ 688.7 $ 736.4 $ 1,206.3 $ 1,229.9 Purchases of Investments 697.0 745.5 1,233.3 1,253.2 Gross Realized Gains on Investment Sales 6.4 10.9 54.8 16.7 Gross Realized Losses on Investment Sales 3.7 17.9 12.3 25.1
Contractual Maturities, Fair Value of Debt Securities in Nuclear Trusts	Fair Value of Fixed Income Securities (in millions) Within 1 year $ 325.0 After 1 year through 5 years 496.9 After 5 years through 10 years 219.2 After 10 years 222.9 Total $ 1,264.0
Fair Value, Assets and Liabilities Measured on Recurring Basis	AEP Assets and Liabilities Measured at Fair Value on a Recurring Basis June 30, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments and Restricted Cash Restricted Cash $ 45.8 $ — $ — $ — $ 45.8 Other Cash Deposits (a) — — — 15.9 15.9 Fixed Income Securities – Mutual Funds 146.8 — — — 146.8 Equity Securities – Mutual Funds (b) 39.8 — — — 39.8 Total Other Temporary Investments and Restricted Cash 232.4 — — 15.9 248.3 Risk Management Assets Risk Management Commodity Contracts (c) (d) 12.5 893.6 276.5 (756.9) 425.7 Cash Flow Hedges: Commodity Hedges (c) — 118.4 19.4 (17.2) 120.6 Total Risk Management Assets 12.5 1,012.0 295.9 (774.1) 546.3 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 13.3 — — 10.9 24.2 Fixed Income Securities: United States Government — 1,191.9 — — 1,191.9 Corporate Debt — 68.8 — — 68.8 State and Local Government — 3.3 — — 3.3 Subtotal Fixed Income Securities — 1,264.0 — — 1,264.0 Equity Securities – Domestic (b) 2,360.6 — — — 2,360.6 Total Spent Nuclear Fuel and Decommissioning Trusts 2,373.9 1,264.0 — 10.9 3,648.8 Total Assets $ 2,618.8 $ 2,276.0 $ 295.9 $ (747.3) $ 4,443.4 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (d) $ 26.5 $ 848.3 $ 169.8 $ (719.4) $ 325.2 Cash Flow Hedges: Commodity Hedges (c) — 18.8 — (17.2) 1.6 Fair Value Hedges — 124.7 — — 124.7 Total Risk Management Liabilities $ 26.5 $ 991.8 $ 169.8 $ (736.6) $ 451.5 AEP Assets and Liabilities Measured at Fair Value on a Recurring Basis December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments and Restricted Cash Restricted Cash $ 47.1 $ — $ — $ — $ 47.1 Other Cash Deposits (a) — — — 9.0 9.0 Fixed Income Securities – Mutual Funds 144.1 — — — 144.1 Equity Securities – Mutual Funds (b) 34.5 — — — 34.5 Total Other Temporary Investments and Restricted Cash 225.7 — — 9.0 234.7 Risk Management Assets Risk Management Commodity Contracts (c) (f) 15.0 1,197.5 314.4 (1,211.5) 315.4 Cash Flow Hedges: Commodity Hedges (c) — 332.6 26.7 (52.8) 306.5 Interest Rate Hedges — 11.0 — — 11.0 Total Risk Management Assets 15.0 1,541.1 341.1 (1,264.3) 632.9 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 11.3 — — 9.9 21.2 Fixed Income Securities: United States Government — 1,123.8 — — 1,123.8 Corporate Debt — 61.6 — — 61.6 State and Local Government — 3.3 — — 3.3 Subtotal Fixed Income Securities — 1,188.7 — — 1,188.7 Equity Securities – Domestic (b) 2,131.3 — — — 2,131.3 Total Spent Nuclear Fuel and Decommissioning Trusts 2,142.6 1,188.7 — 9.9 3,341.2 Total Assets $ 2,383.3 $ 2,729.8 $ 341.1 $ (1,245.4) $ 4,208.8 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (f) $ 21.8 $ 870.9 $ 179.0 $ (731.9) $ 339.8 Cash Flow Hedges: Commodity Hedges (c) — 74.3 1.7 (52.8) 23.2 Fair Value Hedges — 127.4 — — 127.4 Total Risk Management Liabilities $ 21.8 $ 1,072.6 $ 180.7 $ (784.7) $ 490.4 AEP Texas Assets and Liabilities Measured at Fair Value on a Recurring Basis June 30, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 30.7 $ — $ — $ — $ 30.7 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 0.5 $ — $ (0.5) $ — December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 32.7 $ — $ — $ — $ 32.7 APCo Assets and Liabilities Measured at Fair Value on a Recurring Basis June 30, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 15.1 $ — $ — $ — $ 15.1 Risk Management Assets Risk Management Commodity Contracts (c) (g) — 1.6 41.1 (3.3) 39.4 Total Assets $ 15.1 $ 1.6 $ 41.1 $ (3.3) $ 54.5 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 3.4 $ 1.7 $ (4.0) $ 1.1 December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 14.4 $ — $ — $ — $ 14.4 Risk Management Assets Risk Management Commodity Contracts (c) (g) — 0.7 69.4 (1.0) 69.1 Total Assets $ 14.4 $ 0.7 $ 69.4 $ (1.0) $ 83.5 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 4.6 $ 0.3 $ (1.4) $ 3.5 I&M Assets and Liabilities Measured at Fair Value on a Recurring Basis June 30, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 25.6 $ 8.2 $ (3.3) $ 30.5 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 13.3 — — 10.9 24.2 Fixed Income Securities: United States Government — 1,191.9 — — 1,191.9 Corporate Debt — 68.8 — — 68.8 State and Local Government — 3.3 — — 3.3 Subtotal Fixed Income Securities — 1,264.0 — — 1,264.0 Equity Securities - Domestic (b) 2,360.6 — — — 2,360.6 Total Spent Nuclear Fuel and Decommissioning Trusts 2,373.9 1,264.0 — 10.9 3,648.8 Total Assets $ 2,373.9 $ 1,289.6 $ 8.2 $ 7.6 $ 3,679.3 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 3.8 $ 1.4 $ (3.8) $ 1.4 December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 11.3 $ 5.3 $ (1.2) $ 15.4 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 11.3 — — 9.9 21.2 Fixed Income Securities: United States Government — 1,123.8 — — 1,123.8 Corporate Debt — 61.6 — — 61.6 State and Local Government — 3.3 — — 3.3 Subtotal Fixed Income Securities — 1,188.7 — — 1,188.7 Equity Securities - Domestic (b) 2,131.3 — — — 2,131.3 Total Spent Nuclear Fuel and Decommissioning Trusts 2,142.6 1,188.7 — 9.9 3,341.2 Total Assets $ 2,142.6 $ 1,200.0 $ 5.3 $ 8.7 $ 3,356.6 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 0.6 $ 0.7 $ (1.3) $ — OPCo Assets and Liabilities Measured at Fair Value on a Recurring Basis June 30, 2023 Level 1 Level 2 Level 3 Other Total Liabilities: (in millions) Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 0.4 $ 54.0 $ (0.4) $ 54.0 December 31, 2022 Level 1 Level 2 Level 3 Other Total Liabilities: (in millions) Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 40.0 $ (0.3) $ 39.7 PSO Assets and Liabilities Measured at Fair Value on a Recurring Basis June 30, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 2.9 $ 44.7 $ (2.8) $ 44.8 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 4.8 $ 1.6 $ (3.0) $ 3.4 December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ — $ 24.0 $ 1.3 $ 25.3 Cash Flow Hedges: Interest Rate Hedges — 1.6 — (1.6) — Total Assets $ — $ 1.6 $ 24.0 $ (0.3) $ 25.3 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 1.7 $ 0.3 $ (0.4) $ 1.6 SWEPCo Assets and Liabilities Measured at Fair Value on a Recurring Basis June 30, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.4 $ 28.1 $ (0.5) $ 28.0 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 0.5 $ 2.1 $ (0.8) $ 1.8 December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 2.2 $ 14.6 $ (0.4) $ 16.4 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 1.6 $ 0.4 $ (0.6) $ 1.4 (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 June 30, 2023 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $(6) million in 2023 and $(8) million in periods 2024-2026; Level 2 matures $(27) million in 2023, $59 million in periods 2024-2026, $12 million in periods 2027-2028 and $2 million in periods 2029-2033; Level 3 matures $63 million in 2023, $56 million in periods 2024-2026, $1 million in periods 2027-2028 and $(14) million in periods 2029-2033. 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, 2022 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $(7) million in 2023; Level 2 matures $182 million in 2023, $134 million in periods 2024-2026, $10 million in periods 2027-2028 and $1 million in periods 2029-2033; Level 3 matures $128 million in 2023, $6 million in periods 2024-2026, $6 million in periods 2027-2028 and $(5) million in periods 2029-2033. Risk management commodity contracts are substantially comprised of power contracts. (g) Substantially comprised of power contracts for the Registrant Subsidiaries.
Changes in Fair Value of Net Trading Derivatives and Other Investments	Three Months Ended June 30, 2023 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of March 31, 2023 $ 45.1 $ 5.7 $ 1.1 $ (46.9) $ 9.3 $ 5.8 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) (86.8) (11.9) (3.2) (1.4) (42.1) (32.8) Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (15.8) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 4.7 — — — — — Settlements 62.3 6.2 2.0 1.3 32.8 27.0 Transfers out of Level 3 (e) (3.1) — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 119.7 39.4 6.9 (7.0) 43.1 26.0 Balance as of June 30, 2023 $ 126.1 $ 39.4 $ 6.8 $ (54.0) $ 43.1 $ 26.0 Three Months Ended June 30, 2022 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of March 31, 2022 $ 82.8 $ 6.6 $ 1.0 $ (68.5) $ 6.5 $ 15.7 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 38.6 5.7 (0.3) 0.9 11.9 19.9 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (16.8) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 5.7 — — — — — Settlements (69.3) (12.4) (0.7) — (18.4) (27.9) Transfers into Level 3 (d) (e) 2.4 — — — — — Transfers out of Level 3 (e) 5.8 — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 234.7 79.7 9.8 19.2 64.5 37.7 Balance as of June 30, 2022 $ 283.9 $ 79.6 $ 9.8 $ (48.4) $ 64.5 $ 45.4 Six Months Ended June 30, 2023 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of December 31, 2022 $ 160.4 $ 69.1 $ 4.6 $ (40.0) $ 23.7 $ 14.2 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) (97.5) (47.9) (2.3) (1.7) (25.5) (20.3) Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (3.0) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) (15.0) — — — — — Settlements (23.0) (21.1) (2.2) 2.4 1.8 6.1 Transfers into Level 3 (d) (e) (6.1) — — — — — Transfers out of Level 3 (e) (1.3) — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 111.6 39.3 6.7 (14.7) 43.1 26.0 Balance as of June 30, 2023 $ 126.1 $ 39.4 $ 6.8 $ (54.0) $ 43.1 $ 26.0 Six Months Ended June 30, 2022 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of December 31, 2021 $ 103.1 $ 41.7 $ (0.7) $ (92.5) $ 12.1 $ 10.9 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 68.1 3.0 3.7 2.4 24.2 32.5 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (35.7) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 22.5 — — — — — Settlements (149.0) (44.7) (3.0) 1.4 (36.3) (41.0) Transfers into Level 3 (d) (e) 4.4 — — — — — Transfers out of Level 3 (e) 9.6 — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 260.9 79.6 9.8 40.3 64.5 43.0 Balance as of June 30, 2022 $ 283.9 $ 79.6 $ 9.8 $ (48.4) $ 64.5 $ 45.4 (a) Included in revenues on the statements of income. (b) Represents the change in fair value between the beginning of the reporting period and the settlement of the risk management commodity contract. (c) Included in cash flow hedges on the statements of comprehensive income. (d) Represents existing assets or liabilities that were previously categorized as Level 2. (e) Transfers are recognized based on their value at the beginning of the reporting period that the transfer occurred. (f) Relates to the net gains (losses) of those contracts that are not reflected on the statements of income. These changes in fair value are recorded as regulatory liabilities for net gains and as regulatory assets for net losses or accounts payable.
Significant Unobservable Inputs for Level 3	Significant Unobservable Inputs June 30, 2023 Significant Input/Range Type of Fair Value Valuation Unobservable Weighted Company Input Assets Liabilities Technique Input Low High Average (c) (in millions) AEP Energy Contracts $ 158.4 $ 158.1 Discounted Cash Flow Forward Market Price (a) $ 1.89 $ 90.40 $ 44.95 AEP Natural Gas Contracts 0.2 0.2 Discounted Cash Flow Forward Market Price (b) 2.14 4.21 3.21 AEP FTRs 137.3 11.5 Discounted Cash Flow Forward Market Price (a) (17.92) 11.35 (0.20) APCo Natural Gas Contracts 0.2 — Discounted Cash Flow Forward Market Price (b) 2.91 4.19 3.35 APCo FTRs 40.9 1.7 Discounted Cash Flow Forward Market Price (a) (3.60) 9.53 1.37 I&M FTRs 8.2 1.4 Discounted Cash Flow Forward Market Price (a) (6.02) 9.11 1.07 OPCo Energy Contracts — 54.0 Discounted Cash Flow Forward Market Price (a) 16.97 71.80 41.40 PSO FTRs 44.7 1.6 Discounted Cash Flow Forward Market Price (a) (17.92) 0.87 (4.44) SWEPCo Natural Gas Contracts — 0.2 Discounted Cash Flow Forward Market Price (b) 2.91 4.19 3.35 SWEPCo FTRs 28.1 1.9 Discounted Cash Flow Forward Market Price (a) (17.92) 0.87 (4.44) December 31, 2022 Significant Input/Range Type of Fair Value Valuation Unobservable Weighted Company Input Assets Liabilities Technique Input (a) Low High Average (c) (in millions) AEP Energy Contracts $ 204.0 $ 167.4 Discounted Cash Flow Forward Market Price $ 2.91 $ 187.34 $ 49.14 AEP FTRs 137.1 13.3 Discounted Cash Flow Forward Market Price (36.45) 20.72 1.18 APCo FTRs 69.4 0.3 Discounted Cash Flow Forward Market Price (2.82) 18.88 3.89 I&M FTRs 5.3 0.7 Discounted Cash Flow Forward Market Price 0.16 18.79 1.23 OPCo Energy Contracts — 40.0 Discounted Cash Flow Forward Market Price 2.91 187.34 48.76 PSO FTRs 24.0 0.3 Discounted Cash Flow Forward Market Price (36.45) 3.40 (7.55) SWEPCo FTRs 14.6 0.4 Discounted Cash Flow Forward Market Price (36.45) 3.40 (7.55) (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.
Sensitivity 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)	6 Months Ended
Income Taxes (Tables)	Jun. 30, 2023
Schedule of Effective Income Tax Rate Reconciliation	Three Months Ended June 30, 2023 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 2.1 % 0.6 % 2.6 % 3.2 % 0.7 % 0.8 % 2.0 % (1.6) % Tax Reform Excess ADIT Reversal (6.2) % (1.3) % 0.1 % (4.5) % (6.1) % (8.5) % (17.2) % (4.2) % Production and Investment Tax Credits (9.9) % (0.2) % — % (0.1) % 0.1 % — % (55.1) % (29.2) % Flow Through (1.0) % 0.1 % 0.2 % (5.1) % (4.4) % 1.2 % 0.3 % (0.8) % AFUDC Equity (1.2) % (0.9) % (2.1) % (1.5) % (0.1) % (0.7) % (1.4) % — % Other 0.4 % 0.3 % — % (0.4) % 0.1 % 0.1 % — % 0.7 % Effective Income Tax Rate 5.2 % 19.6 % 21.8 % 12.6 % 11.3 % 13.9 % (50.4) % (14.1) % Three Months Ended June 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 1.3 % 0.7 % 2.9 % (1.0) % (1.3) % 1.0 % 3.9 % 2.5 % Tax Reform Excess ADIT Reversal (7.1) % (2.1) % 0.3 % (20.4) % (17.2) % (7.8) % (19.2) % (5.2) % Production and Investment Tax Credits (6.1) % (0.6) % — % — % (3.4) % — % (32.2) % (19.8) % Flow Through (0.1) % 0.2 % 0.4 % (1.4) % (1.2) % 0.2 % 0.3 % — % AFUDC Equity (1.1) % (1.4) % (2.3) % (1.5) % (1.3) % (0.7) % (0.4) % (0.5) % Discrete Tax Adjustments 0.3 % — % — % (6.0) % — % — % — % 0.8 % Other 1.1 % 0.1 % 0.1 % (0.2) % 1.3 % 0.1 % 0.5 % (0.1) % Effective Income Tax Rate 9.3 % 17.9 % 22.4 % (9.5) % (2.1) % 13.8 % (26.1) % (1.3) % Six Months Ended June 30, 2023 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 2.0 % 0.5 % 2.6 % 2.6 % 2.4 % 0.9 % 2.0 % (1.2) % Tax Reform Excess ADIT Reversal (6.2) % (1.4) % 0.2 % (4.5) % (7.2) % (7.6) % (17.1) % (4.0) % Production and Investment Tax Credits (9.8) % (0.2) % — % (0.1) % (0.6) % — % (55.2) % (28.2) % Flow Through (0.5) % 0.2 % 0.2 % (0.8) % (2.9) % 0.8 % 0.3 % (0.3) % AFUDC Equity (1.3) % (1.1) % (1.8) % (0.9) % (0.3) % (0.8) % (1.4) % (0.3) % Discrete Tax Adjustments (1.4) % — % — % 2.4 % 1.0 % — % — % — % Other 0.3 % 0.2 % — % (0.1) % 0.1 % 0.1 % 0.1 % 0.1 % Effective Income Tax Rate 4.1 % 19.2 % 22.2 % 19.6 % 13.5 % 14.4 % (50.3) % (12.9) % Six Months Ended June 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 1.4 % 0.5 % 2.7 % 1.5 % 0.4 % 0.9 % 3.5 % 2.4 % Tax Reform Excess ADIT Reversal (6.8) % (2.0) % 0.3 % (11.0) % (17.2) % (7.8) % (18.6) % (5.1) % Production and Investment Tax Credits (7.1) % (0.4) % — % — % (2.3) % — % (31.4) % (20.8) % Flow Through 0.1 % 0.2 % 0.3 % 0.6 % (1.6) % 0.6 % 0.3 % (0.2) % AFUDC Equity (1.0) % (1.1) % (1.9) % (1.0) % (0.9) % (0.6) % (0.5) % (0.5) % Discrete Tax Adjustments (0.2) % — % — % (2.6) % — % — % — % 0.5 % Other 0.5 % (0.1) % 0.2 % — % 0.4 % (0.1) % 0.3 % — % Effective Income Tax Rate 7.9 % 18.1 % 22.6 % 8.5 % (0.2) % 14.0 % (25.4) % (2.7) %

Financing Activities (Tables)

Financing Activities (Tables)	6 Months Ended
Financing Activities (Tables)	Jun. 30, 2023
Long-term Debt	Type of Debt June 30, 2023 December 31, 2022 (in millions) Senior Unsecured Notes $ 33,491.5 $ 30,174.8 Pollution Control Bonds 1,770.9 1,770.2 Notes Payable 165.8 269.7 Securitization Bonds 432.1 487.8 Spent Nuclear Fuel Obligation (a) 292.3 285.6 Junior Subordinated Notes (b) 2,385.0 2,381.3 Other Long-term Debt 1,604.7 1,431.6 Total Long-term Debt Outstanding 40,142.3 36,801.0 Long-term Debt Due Within One Year 3,380.3 2,486.4 Long-term Debt $ 36,762.0 $ 34,314.6 (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 $341 million and $330 million as of June 30, 2023 and December 31, 2022, respectively, and are included in Spent Nuclear Fuel and Decommissioning Trusts on the balance sheets. (b) See “Equity Units” section below for additional information.
Long-term Debt Issuances	Principal Interest Company Type of Debt Amount (a) Rate Due Date Issuances: (in millions) (%) AEP Senior Unsecured Notes $ 850.0 5.63 2033 AEPTCo Senior Unsecured Notes 700.0 5.40 2053 AEP Texas Senior Unsecured Notes 450.0 5.40 2033 APCo Other Long-term Debt 200.0 Variable 2024 I&M Senior Unsecured Notes 500.0 5.63 2053 OPCo Senior Unsecured Notes 400.0 5.00 2033 PSO Senior Unsecured Notes 475.0 5.25 2033 SWEPCo Senior Unsecured Notes 350.0 5.30 2033 Non-Registrant: KPCo Pollution Control Bonds 65.0 4.70 2026 Transource Energy Other Long-term Debt 13.0 Variable 2025 Total Issuances $ 4,003.0 (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 Senior Unsecured Notes $ 125.0 3.09 2023 AEP Texas Securitization Bonds 31.5 2.85 2024 AEP Texas Securitization Bonds 11.7 2.06 2025 APCo Securitization Bonds 9.7 2.01 2023 APCo Securitization Bonds 3.3 3.77 2028 I&M Senior Unsecured Notes 250.0 3.20 2023 I&M Notes Payable 1.2 Variable 2023 I&M Notes Payable 2.4 Variable 2024 I&M Notes Payable 9.2 Variable 2025 I&M Notes Payable 7.9 0.93 2025 I&M Notes Payable 13.7 3.44 2026 I&M Notes Payable 13.6 5.93 2027 I&M Other Long-term Debt 1.2 6.00 2025 OPCo Other Long-term Debt 0.6 1.15 2028 PSO Other Long-term Debt 0.3 3.00 2027 SWEPCo Notes Payable 25.0 6.37 2024 SWEPCo Notes Payable 30.9 4.58 2032 SWEPCo Other Long-term Debt 38.2 4.68 2028 Non-Registrant: KPCo Pollution Control Bonds 65.0 2.35 2023 Transource Energy Senior Unsecured Notes 1.3 2.75 2050 Total Retirements and Principal Payments $ 641.7
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 June 30, 2023 Limit (in millions) AEP Texas $ 477.5 $ — $ 279.9 $ — $ (135.9) $ 500.0 AEPTCo 471.3 309.4 153.1 85.9 26.9 820.0 (a) APCo 388.6 19.8 295.0 18.9 (247.2) 500.0 I&M 475.3 100.3 174.0 43.0 40.5 500.0 OPCo 485.7 64.7 266.4 40.2 (72.3) 500.0 PSO 375.0 121.5 127.5 74.8 (68.1) 400.0 SWEPCo 401.6 (b) — 220.6 — (32.6) 400.0 (a) 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 June 30, 2023 (in millions) AEP Texas $ 6.9 $ 6.8 $ 6.9 SWEPCo 2.2 2.1 2.2
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 June 30, 2023 June 30, 2023 Borrowing Limit (in millions) $ 29.4 $ 158.1 $ 2.9 $ 70.2 $ 21.9 $ — $ 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	Six Months Ended June 30, 2023 2022 Maximum Interest Rate 5.69 % 2.11 % Minimum Interest Rate 4.66 % 0.10 %
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 Six Months Ended June 30, for Six Months Ended June 30, Company 2023 2022 2023 2022 AEP Texas 5.35 % 0.90 % — % 1.48 % AEPTCo 5.16 % 0.93 % 5.46 % 1.49 % APCo 5.36 % 1.08 % 5.35 % 0.95 % I&M 5.13 % 0.92 % 5.42 % 0.96 % OPCo 5.30 % 0.83 % 5.60 % 1.20 % PSO 5.47 % 1.17 % 5.11 % 0.65 % SWEPCo 5.22 % 1.25 % — % 0.55 %
Maximum Minimum Average Interest Rates for Funds Borrowed from Loaned to Nonutility Money Pool	Six Months Ended June 30, 2023 Six Months Ended June 30, 2022 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 5.69 % 4.66 % 5.35 % 2.11 % 0.46 % 0.98 % SWEPCo 5.69 % 4.66 % 5.35 % 2.11 % 0.46 % 0.98 %
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 Six Months for Funds for Funds for Funds for Funds for Funds for Funds Ended Borrowed Borrowed Loaned Loaned Borrowed Loaned June 30, from AEP from AEP to AEP to AEP from AEP to AEP 2023 5.69 % 4.53 % 5.69 % 4.53 % 5.27 % 5.35 % 2022 2.11 % 0.46 % 2.11 % 0.46 % 1.02 % 0.89 %
Short Term Debt	June 30, 2023 December 31, 2022 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 5.45 % $ 750.0 4.67 % AEP Commercial Paper 2,238.7 5.50 % 2,862.2 4.80 % AEP Term Loan 500.0 6.08 % — — % AEP Term Loan 150.0 5.94 % 150.0 5.17 % AEP Term Loan 125.0 5.94 % 125.0 5.17 % AEP Term Loan 100.0 5.94 % 100.0 5.23 % AEP Term Loan — — % 125.0 4.87 % SWEPCo Notes Payable 3.9 7.53 % — — % AEP Total Short-term Debt $ 3,867.6 $ 4,112.2 (a) Weighted-average rate as of June 30, 2023 and December 31, 2022, respectively. (b) Amount of securitized debt for receivables as accounted for under the “Transfers and Servicing” accounting guidance.
Comparative Accounts Receivable Information	Three Months Ended June 30, Six Months Ended June 30, 2023 2022 2023 2022 (dollars in millions) Effective Interest Rates on Securitization of Accounts Receivable 5.25 % 0.91 % 5.06 % 0.61 % Net Uncollectible Accounts Receivable Written-Off $ 7.3 $ 6.2 $ 14.1 $ 13.6
Customer Accounts Receivable Managed Portfolio	June 30, 2023 December 31, 2022 (in millions) Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts $ 1,184.9 $ 1,167.7 Short-term – Securitized Debt of Receivables 750.0 750.0 Delinquent Securitized Accounts Receivable 49.4 44.2 Bad Debt Reserves Related to Securitization 41.7 39.7 Unbilled Receivables Related to Securitization 392.4 360.9
Accounts Receivable and Accrued Unbilled Revenues	Company June 30, 2023 December 31, 2022 (in millions) APCo $ 181.9 $ 194.4 I&M 177.3 166.9 OPCo 477.4 478.6 PSO 177.8 155.5 SWEPCo 191.6 194.0
Fees Paid to AEP Credit for Customer Accounts Receivable Sold	Three Months Ended June 30, Six Months Ended June 30, Company 2023 2022 2023 2022 (in millions) APCo $ 4.3 $ 1.5 $ 9.2 $ 2.8 I&M 3.9 2.0 7.8 3.7 OPCo 7.6 7.5 14.9 14.9 PSO 3.5 1.3 6.7 2.2 SWEPCo 4.4 1.5 8.7 2.8
Proceeds on Sale of Receivables to AEP Credit	Three Months Ended June 30, Six Months Ended June 30, Company 2023 2022 2023 2022 (in millions) APCo $ 414.9 $ 339.0 $ 921.1 $ 754.5 I&M 497.2 502.4 1,022.6 1,015.8 OPCo 783.9 693.3 1,668.3 1,409.9 PSO 460.2 428.5 876.5 791.9 SWEPCo 460.5 437.2 898.1 831.7

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	6 Months Ended	12 Months Ended
Variable Interest Entities (Tables)	Jun. 30, 2023	Dec. 31, 2022
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Consolidated Assets And Liabilities Of Variable Interest Entities	American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities June 30, 2023 Registrant Subsidiaries SWEPCo I&M AEP Texas Transition Funding AEP Texas Restoration Funding APCo (in millions) ASSETS Current Assets $ 5.8 $ 72.5 $ 26.9 $ 25.4 $ 13.3 Net Property, Plant and Equipment — 129.3 — — — Other Noncurrent Assets 129.7 63.6 109.5 (a) 157.2 (b) 151.8 (c) Total Assets $ 135.5 $ 265.4 $ 136.4 $ 182.6 $ 165.1 LIABILITIES AND EQUITY Current Liabilities $ 19.8 $ 72.4 $ 74.5 $ 36.7 $ 29.6 Noncurrent Liabilities 115.6 193.0 57.5 144.7 133.6 Equity 0.1 — 4.4 1.2 1.9 Total Liabilities and Equity $ 135.5 $ 265.4 $ 136.4 $ 182.6 $ 165.1 (a) Includes an intercompany item eliminated in consolidation of $12 million. (b) Includes an intercompany item eliminated in consolidation of $7 million. (c) Includes an intercompany item eliminated in consolidation of $2 million . American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities June 30, 2023 Other Consolidated VIEs AEP Credit Protected Transource Energy (in millions) ASSETS Current Assets $ 1,186.0 $ 195.1 $ 29.3 Net Property, Plant and Equipment — — 496.6 Other Noncurrent Assets 9.4 — 5.3 Total Assets $ 1,195.4 $ 195.1 $ 531.2 LIABILITIES AND EQUITY Current Liabilities $ 1,132.8 $ 39.7 $ 21.1 Noncurrent Liabilities 0.9 81.9 232.0 Equity 61.7 73.5 278.1 Total Liabilities and Equity $ 1,195.4 $ 195.1 $ 531.2	American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities December 31, 2022 Registrant Subsidiaries SWEPCo I&M AEP Texas Transition Funding AEP Texas Restoration Funding APCo (in millions) ASSETS Current Assets $ 108.3 $ 90.2 $ 27.0 $ 21.1 $ 13.5 Net Property, Plant and Equipment 7.2 179.1 — — — Other Noncurrent Assets 130.0 94.0 140.9 (a) 168.8 (b) 164.6 (c) Total Assets $ 245.5 $ 363.3 $ 167.9 $ 189.9 $ 178.1 LIABILITIES AND EQUITY Current Liabilities $ 25.4 $ 90.0 $ 73.2 $ 31.3 $ 29.3 Noncurrent Liabilities 219.4 273.3 90.4 157.4 146.9 Equity 0.7 — 4.3 1.2 1.9 Total Liabilities and Equity $ 245.5 $ 363.3 $ 167.9 $ 189.9 $ 178.1 (a) Includes an intercompany item eliminated in consolidation of $16 million . (b) Includes an intercompany item eliminated in consolidation of $7 million . (c) Includes an intercompany item eliminated in consolidation of $2 million . American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities December 31, 2022 Other Consolidated VIEs AEP Credit Protected Transource Energy Apple Blossom and Black Oak Santa Rita East Dry Lake (in millions) ASSETS Current Assets $ 1,181.0 $ 194.5 $ 23.5 $ 8.3 $ 21.3 $ 4.0 Net Property, Plant and Equipment — — 482.3 216.5 421.6 142.6 Other Noncurrent Assets 9.0 0.3 2.7 13.6 0.1 0.3 Total Assets $ 1,190.0 $ 194.8 $ 508.5 $ 238.4 $ 443.0 $ 146.9 LIABILITIES AND EQUITY Current Liabilities $ 1,087.8 $ 46.4 $ 22.8 $ 4.5 $ 9.6 $ 1.0 Noncurrent Liabilities 0.9 79.1 218.6 5.4 7.3 0.7 Equity 101.3 69.3 267.1 228.5 426.1 145.2 Total Liabilities and Equity $ 1,190.0 $ 194.8 $ 508.5 $ 238.4 $ 443.0 $ 146.9

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	6 Months Ended
Revenue from Contracts with Customers (Tables)	Jun. 30, 2023
Disaggregated Revenues from Contracts with Customers	Three Months Ended June 30, 2023 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 $ 962.0 $ 574.1 $ — $ — $ — $ — $ 1,536.1 Commercial Revenues 642.7 358.3 — — — — 1,001.0 Industrial Revenues 698.9 152.1 — — — (0.1) 850.9 Other Retail Revenues 58.9 12.3 — — — — 71.2 Total Retail Revenues 2,362.5 1,096.8 — — — (0.1) 3,459.2 Wholesale and Competitive Retail Revenues: Generation Revenues 141.4 — — 19.6 — 0.1 161.1 Transmission Revenues (a) 113.5 184.1 455.8 — — (402.8) 350.6 Renewable Generation Revenues (b) — — — 33.1 — (3.1) 30.0 Retail, Trading and Marketing Revenues (b) — — — 407.7 1.2 (10.1) 398.8 Total Wholesale and Competitive Retail Revenues 254.9 184.1 455.8 460.4 1.2 (415.9) 940.5 Other Revenues from Contracts with Customers (c) 61.9 56.1 4.3 6.2 28.6 (39.9) 117.2 Total Revenues from Contracts with Customers 2,679.3 1,337.0 460.1 466.6 29.8 (455.9) 4,516.9 Other Revenues: Alternative Revenue Programs (b) (d) (4.9) (2.9) (1.5) — — (6.3) (15.6) Other Revenues (b) (e) 0.1 6.1 — (135.2) 2.2 (2.0) (128.8) Total Other Revenues (4.8) 3.2 (1.5) (135.2) 2.2 (8.3) (144.4) Total Revenues $ 2,674.5 $ 1,340.2 $ 458.6 $ 331.4 $ 32.0 $ (464.2) $ 4,372.5 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $360 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 $26 million. The remaining affiliated amounts were immaterial. (d) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. (e) Generation & Marketing includes economic hedge activity. Three Months Ended June 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 $ 979.3 $ 561.6 $ — $ — $ — $ — $ 1,540.9 Commercial Revenues 624.8 331.7 — — — — 956.5 Industrial Revenues 641.8 162.5 — — — — 804.3 Other Retail Revenues 52.9 12.8 — — — — 65.7 Total Retail Revenues 2,298.8 1,068.6 — — — — 3,367.4 Wholesale and Competitive Retail Revenues: Generation Revenues 188.3 — — 83.0 — 0.1 271.4 Transmission Revenues (a) 108.8 164.9 421.6 — — (332.0) 363.3 Renewable Generation Revenues (b) — — — 38.2 — (2.9) 35.3 Retail, Trading and Marketing Revenues (b) — — — 408.3 1.3 (2.3) 407.3 Total Wholesale and Competitive Retail Revenues 297.1 164.9 421.6 529.5 1.3 (337.1) 1,077.3 Other Revenues from Contracts with Customers (c) 49.2 65.9 0.2 1.6 20.9 (21.1) 116.7 Total Revenues from Contracts with Customers 2,645.1 1,299.4 421.8 531.1 22.2 (358.2) 4,561.4 Other Revenues: Alternative Revenue Programs (b) (d) 3.3 (4.6) (43.0) — — (13.1) (57.4) Other Revenues (b) (e) 0.1 6.8 — 128.5 2.3 (2.0) 135.7 Total Other Revenues 3.4 2.2 (43.0) 128.5 2.3 (15.1) 78.3 Total Revenues $ 2,648.5 $ 1,301.6 $ 378.8 $ 659.6 $ 24.5 $ (373.3) $ 4,639.7 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $334 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 Vertically Integrated Utilities was $5 million. The remaining affiliated amounts were immaterial. (d) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. (e) Generation & Marketing includes economic hedge activity. Three Months Ended June 30, 2023 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 144.9 $ — $ 324.8 $ 185.2 $ 429.3 $ 186.5 $ 185.1 Commercial Revenues 100.6 — 163.6 141.4 257.8 131.7 153.8 Industrial Revenues 35.2 — 192.5 155.9 116.8 107.8 110.6 Other Retail Revenues 8.7 — 25.2 1.2 3.6 28.3 2.6 Total Retail Revenues 289.4 — 706.1 483.7 807.5 454.3 452.1 Wholesale Revenues: Generation Revenues (a) — — 64.2 63.5 — 4.3 43.9 Transmission Revenues (b) 163.1 444.7 43.9 9.6 21.0 9.9 38.3 Total Wholesale Revenues 163.1 444.7 108.1 73.1 21.0 14.2 82.2 Other Revenues from Contracts with Customers (c) 10.7 4.1 11.8 45.0 45.5 7.2 7.0 Total Revenues from Contracts with Customers 463.2 448.8 826.0 601.8 874.0 475.7 541.3 Other Revenues: Alternative Revenue Programs (d) (e) (2.0) (3.9) 0.5 (2.6) (0.9) (1.0) (3.5) Other Revenues (e) — — — — 6.0 — — Total Other Revenues (2.0) (3.9) 0.5 (2.6) 5.1 (1.0) (3.5) Total Revenues $ 461.2 $ 444.9 $ 826.5 $ 599.2 $ 879.1 $ 474.7 $ 537.8 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $38 million primarily related to the PPA with KGPCo. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $357 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) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. (e) Amounts include affiliated and nonaffiliated revenues. Three Months Ended June 30, 2022 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 174.9 $ — $ 313.2 $ 195.2 $ 386.7 $ 185.2 $ 188.6 Commercial Revenues 110.6 — 152.6 138.6 221.1 121.2 146.0 Industrial Revenues 36.6 — 161.9 160.0 126.0 92.5 97.1 Other Retail Revenues 9.5 — 20.2 1.2 3.4 25.8 4.4 Total Retail Revenues 331.6 — 647.9 495.0 737.2 424.7 436.1 Wholesale Revenues: Generation Revenues (a) — — 63.5 94.2 — 0.3 57.4 Transmission Revenues (b) 143.8 406.1 40.8 8.7 21.1 9.1 39.3 Total Wholesale Revenues 143.8 406.1 104.3 102.9 21.1 9.4 96.7 Other Revenues from Contracts with Customers (c) 5.6 0.2 20.6 25.8 60.2 9.6 6.0 Total Revenues from Contracts with Customers 481.0 406.3 772.8 623.7 818.5 443.7 538.8 Other Revenues: Alternative Revenue Programs (d) (e) (2.2) (41.9) 0.8 7.3 (2.4) (0.8) (2.2) Other Revenues (e) — — — — 6.8 — — Total Other Revenues (2.2) (41.9) 0.8 7.3 4.4 (0.8) (2.2) Total Revenues $ 478.8 $ 364.4 $ 773.6 $ 631.0 $ 822.9 $ 442.9 $ 536.6 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $42 million primarily related to the PPA with KGPCo. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $330 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $19 million primarily related to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. (e) Amounts include affiliated and nonaffiliated revenues. Six Months Ended June 30, 2023 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 $ 2,132.4 $ 1,230.9 $ — $ — $ — $ — $ 3,363.3 Commercial Revenues 1,276.1 734.2 — — — — 2,010.3 Industrial Revenues (a) 1,369.2 365.0 — — — (0.3) 1,733.9 Other Retail Revenues 115.7 24.4 — — — — 140.1 Total Retail Revenues 4,893.4 2,354.5 — — — (0.3) 7,247.6 Wholesale and Competitive Retail Revenues: Generation Revenues 324.2 — — 52.0 — 0.1 376.3 Transmission Revenues (b) 228.2 348.3 905.9 — — (804.6) 677.8 Renewable Generation Revenues (a) — — — 54.4 — (3.2) 51.2 Retail, Trading and Marketing Revenues (c) — — — 821.4 0.9 (10.0) 812.3 Total Wholesale and Competitive Retail Revenues 552.4 348.3 905.9 927.8 0.9 (817.7) 1,917.6 Other Revenues from Contracts with Customers (d) 94.5 98.9 7.9 6.8 58.0 (83.6) 182.5 Total Revenues from Contracts with Customers 5,540.3 2,801.7 913.8 934.6 58.9 (901.6) 9,347.7 Other Revenues: Alternative Revenue Programs (a) (e) (8.0) (14.5) 0.3 — — (3.4) (25.6) Other Revenues (a) (f) — 17.2 — (276.2) 3.2 (2.9) (258.7) Total Other Revenues (8.0) 2.7 0.3 (276.2) 3.2 (6.3) (284.3) Total Revenues $ 5,532.3 $ 2,804.4 $ 914.1 $ 658.4 $ 62.1 $ (907.9) $ 9,063.4 (a) Amounts include affiliated and nonaffiliated revenues. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $712 million. The affiliated revenue for Vertically Integrated Utilities was $80 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $10 million. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $55 million. The remaining affiliated amounts were immaterial. (e) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. (f) Generation & Marketing includes economic hedge activity. Six Months Ended June 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 $ 2,130.1 $ 1,162.2 $ — $ — $ — $ — $ 3,292.3 Commercial Revenues 1,197.7 621.4 — — — — 1,819.1 Industrial Revenues 1,204.8 295.8 — — — (0.4) 1,500.2 Other Retail Revenues 100.3 24.4 — — — — 124.7 Total Retail Revenues 4,632.9 2,103.8 — — — (0.4) 6,736.3 Wholesale and Competitive Retail Revenues: Generation Revenues 375.5 — — 123.3 — 0.1 498.9 Transmission Revenues (a) 214.1 319.8 836.1 — — (693.8) 676.2 Renewable Generation Revenues (b) — — — 60.6 — (3.7) 56.9 Retail, Trading and Marketing Revenues (c) — — — 797.1 4.5 (11.3) 790.3 Total Wholesale and Competitive Retail Revenues 589.6 319.8 836.1 981.0 4.5 (708.7) 2,022.3 Other Revenues from Contracts with Customers (d) 110.8 119.7 — 10.2 34.8 (39.7) 235.8 Total Revenues from Contracts with Customers 5,333.3 2,543.3 836.1 991.2 39.3 (748.8) 8,994.4 Other Revenues: Alternative Revenue Programs (b) (e) 2.5 (8.0) (45.9) — — (11.8) (63.2) Other Revenues (b) (f) 0.1 13.1 — 287.7 5.1 (4.9) 301.1 Total Other Revenues 2.6 5.1 (45.9) 287.7 5.1 (16.7) 237.9 Total Revenues $ 5,335.9 $ 2,548.4 $ 790.2 $ 1,278.9 $ 44.4 $ (765.5) $ 9,232.3 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $661 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 $19 million. The remaining affiliated amounts were immaterial. (e) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. (f) Generation & Marketing includes economic hedge activity. Six Months Ended June 30, 2023 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 275.6 $ — $ 795.3 $ 424.8 $ 955.3 $ 357.4 $ 361.0 Commercial Revenues 197.9 — 334.9 280.3 536.3 240.8 297.3 Industrial Revenues (a) 74.5 — 378.3 308.5 290.4 206.1 214.8 Other Retail Revenues 17.0 — 51.4 2.5 7.4 52.5 5.2 Total Retail Revenues 565.0 — 1,559.9 1,016.1 1,789.4 856.8 878.3 Wholesale Revenues: Generation Revenues (b) — — 144.4 167.5 — 5.2 83.5 Transmission Revenues (c) 309.4 883.4 85.3 17.7 38.9 21.2 81.2 Total Wholesale Revenues 309.4 883.4 229.7 185.2 38.9 26.4 164.7 Other Revenues from Contracts with Customers (d) 20.4 7.8 24.8 66.4 78.7 9.5 14.9 Total Revenues from Contracts with Customers 894.8 891.2 1,814.4 1,267.7 1,907.0 892.7 1,057.9 Other Revenues: Alternative Revenue Program (a) (e) (4.1) (4.7) (0.2) (5.5) (10.4) (1.0) (4.2) Other Revenues (a) — — — — 17.1 — — Total Other Revenues (4.1) (4.7) (0.2) (5.5) 6.7 (1.0) (4.2) Total Revenues $ 890.7 $ 886.5 $ 1,814.2 $ 1,262.2 $ 1,913.7 $ 891.7 $ 1,053.7 (a) Amounts include affiliated and nonaffiliated revenues. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $85 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $706 million. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $35 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (e) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. Six Months Ended June 30, 2022 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 316.8 $ — $ 771.2 $ 427.0 $ 845.4 $ 351.1 $ 364.5 Commercial Revenues 205.5 — 306.5 265.2 415.8 218.7 276.5 Industrial Revenues 67.2 — 315.7 296.5 228.7 171.1 181.8 Other Retail Revenues 17.7 — 40.8 2.5 6.7 47.0 6.8 Total Retail Revenues 607.2 — 1,434.2 991.2 1,496.6 787.9 829.6 Wholesale Revenues: Generation Revenues (a) — — 119.7 184.6 — 9.8 118.6 Transmission Revenues (b) 276.9 806.4 81.9 17.5 42.9 18.7 74.5 Total Wholesale Revenues 276.9 806.4 201.6 202.1 42.9 28.5 193.1 Other Revenues from Contracts with Customers (c) 14.9 (0.1) 44.9 55.7 104.8 15.0 11.3 Total Revenues from Contracts with Customers 899.0 806.3 1,680.7 1,249.0 1,644.3 831.4 1,034.0 Other Revenues: Alternative Revenue Program (d) (e) (3.5) (41.5) 0.1 7.3 (4.5) (0.9) (2.6) Other Revenues (e) — — 0.1 (0.1) 13.1 — — Total Other Revenues (3.5) (41.5) 0.2 7.2 8.6 (0.9) (2.6) Total Revenues $ 895.5 $ 764.8 $ 1,680.9 $ 1,256.2 $ 1,652.9 $ 830.5 $ 1,031.4 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $78 million primarily relating to the PPA with KGPCo. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $653 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $29 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. (e) Amounts include affiliated and nonaffiliated revenues.
Fixed Performance Obligations	Company 2023 2024-2025 2026-2027 After 2027 Total (in millions) AEP $ 43.6 $ 161.4 $ 137.1 $ 60.9 $ 403.0 APCo 8.1 32.2 25.4 11.6 77.3 I&M 2.2 8.8 8.8 4.5 24.3
Affiliated Accounts Receivable Contracts with Customers	Company June 30, 2023 December 31, 2022 (in millions) AEP Texas $ — $ 0.1 AEPTCo 123.1 113.8 APCo 68.1 64.5 I&M 47.3 75.3 OPCo 68.6 49.9 PSO 30.6 18.8 SWEPCo 42.4 19.1

Significant Accounting Matter_3

Significant Accounting Matters (Details) - USD ($) $ / shares in Units, $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Dec. 31, 2022	Dec. 31, 2021
Amounts Attributable to AEP Common Shareholders
Earnings Attributable to Common Shareholders		$ 521,200	$ 524,500	$ 918,200	$ 1,239,200
Weighted Average Number of Basic AEP Common Shares Outstanding		514,879,144	513,623,431	514,529,837	509,857,710
Total Basic Earnings Per Share Attributable to AEP Common Shareholders		$ 1.01	$ 1.02	$ 1.78	$ 2.43
Weighted Average Dilutive Effect of:
Weighted Average Number of Diluted AEP Common Shares Outstanding		516,242,919	515,162,210	515,922,446	511,391,735
Total Diluted Earnings Per Share Attributable to AEP Common Shareholders		$ 1.01	$ 1.02	$ 1.78	$ 2.42
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		$ 304,900		$ 304,900		$ 509,400
Restricted Cash		45,800		45,800		47,100
Total Cash, Cash Equivalents and Restricted Cash		350,700	$ 621,200	350,700	$ 621,200	556,500	$ 451,400
Proceeds from Issuance of Debt	[1]			4,003,000
Securities Received as Collateral		73,000		73,000		481,000
Obligation to Return Securities Received as Collateral		35,000		35,000		2,000
AEP Texas Inc. [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		100		100		100
Restricted Cash		30,700		30,700		32,700
Total Cash, Cash Equivalents and Restricted Cash		30,800	29,800	30,800	29,800	32,800	30,500
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		6,800		6,800		7,500
Restricted Cash		15,100		15,100		14,400
Total Cash, Cash Equivalents and Restricted Cash		21,900	21,100	21,900	21,100	21,900	20,100
Indiana Michigan Power Co [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		3,800	2,800	3,800	2,800	4,200	1,300
Ohio Power Co [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		9,700		9,700		9,600
Total Cash, Cash Equivalents and Restricted Cash		9,700	6,900	9,700	6,900	9,600	3,000
Public Service Co Of Oklahoma [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		4,600	3,600	4,600	3,600	4,000	1,300
Southwestern Electric Power Co [Member]
Amounts Attributable to AEP Common Shareholders
Earnings Attributable to Common Shareholders		81,000	76,700	121,600	120,800
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		$ 4,600	$ 63,700	$ 4,600	$ 63,700	$ 88,400	$ 51,200
Restricted Stock Units and Performance Share Units [Member]
Weighted Average Dilutive Effect of:
Weighted Average Dilutive Effect of Shares		1,300,000	1,600,000	1,400,000	1,500,000
Dilutive Securities, Effect on Basic Earnings Per Share		$ 0	$ 0	$ 0	$ (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				6 Months Ended
Comprehensive Income (Details) - USD ($) $ in Millions		Jun. 30, 2023	Mar. 31, 2023	Jun. 30, 2022	Mar. 31, 2022	Jun. 30, 2023	Jun. 30, 2022
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		$ (68.1)	$ 83.7	$ 430.6	$ 184.8	$ 83.7	$ 184.8
Change in Fair Value Recognized in AOCI		12.9		259.3		(190.1)	544.3
Commodity
Generation & Marketing Revenues		4,372.5		4,639.7		9,063.4	9,232.3
Interest Rate
Interest Expense		460		327.6		875.7	641
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		23.9		(163.9)		67.5	(213.6)
Income Tax (Expense) Benefit		28.6		54		39	106.8
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		18.8		(129.5)		53.3	(168.7)
Reclassifications of KPCo Pension and OPEB Regulatory Assets, Net of Tax		0		0		16.7	0
Net Current Period Other Comprehensive Income (Loss)		31.7	(151.8)	120.8	245.8	(120.1)	366.6
Ending Balance in AOCI		(36.4)	(68.1)	551.4	430.6	(36.4)	551.4
Cash Flow Hedges [Member] \| Commodity [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		65.3	223.5	404	163.7	223.5	163.7
Change in Fair Value Recognized in AOCI		5.9		257.3		(189.4)	535.5
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		28.3		(161.7)		75.3	(209.7)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		22.3		(127.7)		59.4	(165.6)
Net Current Period Other Comprehensive Income (Loss)		28.2		129.6		(130)	369.9
Ending Balance in AOCI		93.5	65.3	533.6	404	93.5	533.6
Cash Flow Hedges [Member] \| Interest Rate [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		6.1	0.3	(13.6)	(21.3)	0.3	(21.3)
Change in Fair Value Recognized in AOCI		7		2		12.2	8.8
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(0.5)		1.1		0.2	2.2
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(0.4)		0.8		0.2	1.7
Net Current Period Other Comprehensive Income (Loss)		6.6		2.8		12.4	10.5
Ending Balance in AOCI		12.7	6.1	(10.8)	(13.6)	12.7	(10.8)
Pension and OPEB [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(139.5)	(140.1)	40.2	42.4	(140.1)	42.4
Change in Fair Value Recognized in AOCI		0		0		(12.9)	0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(3.9)		(3.3)		(8)	(6.1)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(3.1)		(2.6)		(6.3)	(4.8)
Net Current Period Other Comprehensive Income (Loss)		(3.1)		(11.6)		(2.5)	(13.8)
Ending Balance in AOCI		(142.6)	$ (139.5)	28.6	$ 40.2	(142.6)	28.6
Generation and Marketing [Member]
Commodity
Generation & Marketing Revenues		318.2		654.4		645.1	1,263.9
Reclassifications To Accumulated Other Comprehensive Income [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit				(2.4)			(2.4)
Reclassifications to AOCI, Current Period, before Tax, Attributable to Parent				(11.4)			(11.4)
Reclassifications of KPCo Pension and OPEB Regulatory Assets, Net of Tax				(9)			(9)
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			0
Reclassifications to AOCI, Current Period, before Tax, Attributable to Parent				0			0
Reclassifications of KPCo Pension and OPEB Regulatory Assets, Net of Tax				0			0
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			0
Reclassifications to AOCI, Current Period, before Tax, Attributable to Parent				0			0
Reclassifications of KPCo Pension and OPEB Regulatory Assets, Net of Tax				0			0
Reclassifications To Accumulated Other Comprehensive Income [Member] \| Pension and OPEB [Member] \| Pension Costs
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit				(2.4)			(2.4)
Reclassifications to AOCI, Current Period, before Tax, Attributable to Parent				(11.4)			(11.4)
Reclassifications of KPCo Pension and OPEB Regulatory Assets, Net of Tax				(9)			(9)
Reclassifications from Accumulated Other Comprehensive Income [Member]
Interest Rate
Interest Expense	[1]	(0.5)		1.1		0.2	2.2
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(5.3)		(5.4)		(10.6)	(10.3)
Amortization of Actuarial (Gains) Losses		1.4		2.1		2.6	4.2
Income Tax (Expense) Benefit		5.1		(34.4)		14.2	(44.9)
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Reclassification of KPCo Pension and OPEB Regulatory Assets from AOCI
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit						21.1
Income Tax (Expense) Benefit						4.4
Reclassification from AOCI, Net of Income Tax (Expense) Benefit						16.7
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Cash Flow Hedges [Member] \| Commodity [Member]
Interest Rate
Interest Expense	[1]	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		6		(34)		15.9	(44.1)
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Cash Flow Hedges [Member] \| Commodity [Member] \| Reclassification of KPCo Pension and OPEB Regulatory Assets from AOCI
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit						0
Income Tax (Expense) Benefit						0
Reclassification from AOCI, Net of Income Tax (Expense) Benefit						0
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Cash Flow Hedges [Member] \| Interest Rate [Member]
Interest Rate
Interest Expense	[1]	(0.5)		1.1		0.2	2.2
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	0.5
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Cash Flow Hedges [Member] \| Interest Rate [Member] \| Reclassification of KPCo Pension and OPEB Regulatory Assets from AOCI
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit						0
Income Tax (Expense) Benefit						0
Reclassification from AOCI, Net of Income Tax (Expense) Benefit						0
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Pension and OPEB [Member]
Interest Rate
Interest Expense	[1]	0		0		0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(5.3)		(5.4)		(10.6)	(10.3)
Amortization of Actuarial (Gains) Losses		1.4		2.1		2.6	4.2
Income Tax (Expense) Benefit		(0.8)		(0.7)		(1.7)	(1.3)
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Pension and OPEB [Member] \| Reclassification of KPCo Pension and OPEB Regulatory Assets from AOCI
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit						21.1
Income Tax (Expense) Benefit						4.4
Reclassification from AOCI, Net of Income Tax (Expense) Benefit						16.7
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Generation and Marketing [Member]
Commodity
Generation & Marketing Revenues	[1]			0.1
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Generation and Marketing [Member] \| Cash Flow Hedges [Member] \| Commodity [Member]
Commodity
Generation & Marketing Revenues	[1]			0.1
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Generation and Marketing [Member] \| Cash Flow Hedges [Member] \| Interest Rate [Member]
Commodity
Generation & Marketing Revenues	[1]			0
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Generation and Marketing [Member] \| Pension and OPEB [Member]
Commodity
Generation & Marketing Revenues	[1]			0
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Commodity
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	[1]	28.3		(161.8)		75.3	(209.7)
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member] \| Cash Flow Hedges [Member] \| Commodity [Member]
Commodity
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	[1]	28.3		(161.8)		75.3	(209.7)
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member] \| Cash Flow Hedges [Member] \| Interest Rate [Member]
Commodity
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	[1]	0		0		0	0
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member] \| Pension and OPEB [Member]
Commodity
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	[1]	$ 0		$ 0		$ 0	$ 0

[1]Amounts reclassified to the referenced line item on the statements of income.

Rate Matters Regulated Operatio

Rate Matters Regulated Operations (Details) - USD ($) $ in Millions		6 Months Ended
		Jun. 30, 2023		Dec. 31, 2022
Public Utilities, General Disclosures [Line Items]
Net Investment		$ 74,681.4		$ 73,339.1
Regulatory Assets, Noncurrent		4,672.8		4,762
Regulatory Assets, Current		1,256.4		1,310
AEP Texas Inc. [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		12,314.7		11,681.6
Regulatory Assets, Noncurrent		326.5		298.3
AEP Transmission Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		14,037.7		13,339.9
Regulatory Assets, Noncurrent		5.8		7.2
Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		12,674		12,379.2
Regulatory Assets, Noncurrent		891.7		1,058.6
Regulatory Assets, Current		586		473.1
Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		7,482.7		7,411.5
Regulatory Assets, Noncurrent		392.1		459.6
Regulatory Assets, Current		17.5		47.1
Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		9,002.9		8,609.3
Regulatory Assets, Noncurrent		406.9		327.3
Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		5,944.3		5,626.5
Regulatory Assets, Noncurrent		570		653.7
Regulatory Assets, Current		178.7		178.7
Public Service Co Of Oklahoma [Member] \| Northeastern Plant, Unit 3 \| Generating Units Probable of Abandonment [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		120.5
Accelerated Depreciation Regulatory Asset		154.9
Cost of Removal Regulatory Liability	[1]	$ 20.4
Expected Retirement Date	[2]	2026
Depreciation	[3]	$ 14.9
Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		8,472.9		8,262.2
Regulatory Assets, Noncurrent		1,147.2		1,042.4
Net Under-Recovered Fuel Costs		120
Regulatory Assets, Current		213.6		353
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		108
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		34
Recommended Disallowance from Staff or Intervenors		72
Southwestern Electric Power Co [Member] \| Dolet Hills Power Station and Related Fuel Operations \| Texas
Public Utilities, General Disclosures [Line Items]
Oxbow Mine Related Costs Recovery Request		48
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		177
Southwestern Electric Power Co [Member] \| Pirkey Power Plant and Related Fuel Operations \| Texas
Public Utilities, General Disclosures [Line Items]
Oxbow Mine Related Costs Recovery Request		33
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		384.3
Accelerated Depreciation Regulatory Asset		105.4
Cost of Removal Regulatory Liability	[4]	$ 58.2
Expected Retirement Date	[5],[6]	2028
Depreciation	[3]	$ 38.6
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		917		919.3
Regulatory Assets Pending Final Regulatory Approval [Member] \| AEP Texas Inc. [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		87.2		67
Regulatory Assets Pending Final Regulatory Approval [Member] \| Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		145.6		144.5
Regulatory Assets Pending Final Regulatory Approval [Member] \| Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		26.7		23.7
Regulatory Assets Pending Final Regulatory Approval [Member] \| Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		52.8		33.8
Regulatory Assets Pending Final Regulatory Approval [Member] \| Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		84.8		25.6
Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		438.5		547.3
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		21.4		19.3
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]	109.5		121.7
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		111.8		116.5
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		105.4		85.6
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		33.9		32
Regulatory Assets Currently Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Mobile Generation Lease Payments
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		29.4		17.6
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		29.4		17.6
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		7.2		7
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		12.1		9.7
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		1.9		2.5
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]	109.5		121.7
Regulatory Assets, Current		37		37
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		111.8		116.5
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		105.4		85.6
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		33.9		32
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	[9],[10]	395.4	[11]	407.2
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		49.3		55.6
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| 2020-2022 Virginia Triennial Review [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		35		37.9
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		34.9		26.7
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		13.6		13.4
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		72		72.6
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		5.5		1.1
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Appalachian Power Co [Member] \| 2020-2022 Virginia Triennial Review [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		35		37.9
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Indiana Michigan Power Co [Member] \| Storm Related Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		23.9		21.6
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		2.7		2
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	[12]	52.7		33.8
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] \| Ohio Power Co [Member] \| Storm-Related Costs Recovery Request [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		34
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		84.6	[13]	25.5
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		0.2		0.1
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Public Service Co Of Oklahoma [Member] \| Storm-Related Costs Recovery Request [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		52
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member] \| Storm Related Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		48	[14],[15]	151.5
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		0		11.8
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		15.9		$ 16
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member] \| Storm-Related Costs Recovery Request [Member] \| Louisiana Jurisdiction [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		28
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member] \| Storm-Related Costs Recovery Request [Member] \| Texas
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		$ 20

[1]Includes Northeastern Plant, Unit 4, which was retired in 2016. Removal of Northeastern Plant, Unit 4, will be performed with the removal of 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]Includes Welsh Plant, Unit 2, which was retired in 2016. Removal of Welsh Plant, Unit 2, will be performed with the removal of Welsh Plant, Units 1 and 3, after retirement.[5]Represents projected retirement date of coal assets, units are being evaluated for conversion to natural gas after 2028.[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 $37 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of June 30, 2023 and December 31, 2022, respectively. See the “February 2021 Severe Winter Weather Impacts in SPP” section below for additional information.[8]Includes $37 million and $37 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of June 30, 2023 and December 31, 2022, respectively. See the “February 2021 Severe Winter Weather Impacts in SPP” section below for additional information.[9]In April 2023, OPCo filed a request with the PUCO for recovery of $34 million in Ohio storm-related costs.[10]In April 2023, the LPSC issued an order approving the prudence and future recovery of the Louisiana storm-related regulatory assets. See “2021 Louisiana Storm Cost Filing” section below for additional information.[11]In June 2023, storms in the Oklahoma, Louisiana and Texas service territories caused power outages and extensive damage resulting in the deferral of $52 million, $28 million and $20 million, respectively. Recovery of these storm costs will be addressed in a future request.[12]In April 2023, OPCo filed a request with the PUCO for recovery of $34 million in storm costs.[13]In June 2023, storms caused power outages and extensive damage to the Oklahoma service territory, resulting in the deferral of $52 million. Recovery for these storm costs will be included in a future request.[14]In April 2023, the LPSC issued an order approving the prudence and future recovery of the Louisiana storm-related regulatory assets. See “2021 Louisiana Storm Cost Filing” section below for additional information.[15]In June 2023, additional storms in the Louisiana and Texas service territories caused power outages and extensive damage resulting in the deferral of $28 million and $20 million, respectively. Recovery of these storm costs will be addressed in a future request.

Rate Matters East Companies (De

Rate Matters East Companies (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2023	Dec. 31, 2022
Public Utilities, General Disclosures [Line Items]
Net Property, Plant and Equipment	$ 74,681.4	$ 73,339.1
AEP Transmission Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Property, Plant and Equipment	14,037.7	13,339.9
Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Property, Plant and Equipment	12,674	12,379.2
Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Property, Plant and Equipment	7,482.7	7,411.5
Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Property, Plant and Equipment	9,002.9	$ 8,609.3
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
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
2023 Alt One Annual Increase in ENEC	293
2023 Alt One Current Year ENEC Increase	89
2023 Alt One Under Recovery	200
2023 Alt Two Annual Increase in ENEC Rates	89
2023 Alt Two Asset Securitization	1,900
2023 Alt Two Under Recovery	553
2023 Alt Two Major Storm Expense Deferrals	88
2023 Alt Two WV Amos and Mountaineer Book Value and CCR and ELG Investments	$ 1,200
Opinion Coal Fired Plants Capacity Factor	69%
Opinion Recommended Disallowance Factor	52.90%
September 2022 Cumulative ENEC Under Recovery Balance	$ 430
Potential Cumulative ENEC Under Recovery Disallowance	285
Michigan Power Supply Cost Recovery Reconciliation \| Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Recommended Disallowance	18
Potential Disallowed Costs	14
OVEC ICPA Recommended Disallowance	$ 1
2020-2022 Virginia Triennial Review [Member] \| Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Return on Equity	10.60%
Intervenor Recommended Annual Increase	$ 69
Previously Incurred Costs Deferral Below Authorized ROE Band	35
Requested Annual Base Rate Increase	213
Requested Annual Base Rate Increase Vegetation Management Portion	47
Requested annual Base Rate Incresae Depreciation Expense Portion	$ 35
Intervenor Recommended Return on Equity	9.20%
Intervenor Recommended Base Rate Decrease Depreciation Expense	$ 36
Intervenor Recommended Base Rate Vegetation Management Removal	40
Intervenor Recommended Base Rate Storm Cost Removal	23
Intervenor Recommended Base Rate Boiler Maintenance Removal	$ 15
Ohio ESP Filings [Member] \| Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Proprosed ESP Return on Common Equity	10.65%
Fuel Adjustment Clause Purchased Power Limitation [Member] \| Kentucky Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Purchased Power Costs Not Recoverable Through FAC Recovery	$ 12
2023 Kentucky Base Rate and Securitization Case [Member] \| Kentucky Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Return on Equity	9.90%
Requested Annual Base Rate Increase	$ 94
Requested Purchased Power Costs Not Recoverable Through FAC Recovery	16
Requested Annual Base Rate Storm Level Restoration Expense	1
Requested Securitization Bonds Regulatory Assets Recovery	471
Requested Securitization Bonds Plant Recovery Retirement Costs	289
Requested Securitization Bonds Deferred Storm Costs	79
Requested Securitization Bonds Deferred Purchased Power Expenses	52
Requested Securitization Bonds Under-Recovered Purchased Power Rider Costs	$ 51

Rate Matters West Companies (De

Rate Matters West Companies (Details) $ in Millions	6 Months Ended
Rate Matters West Companies (Details) $ in Millions	Jun. 30, 2023 USD ($) MW	Dec. 31, 2022 USD ($)
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	$ 4,672.8	$ 4,762
Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	917	919.3
Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	570	653.7
Public Service Co Of Oklahoma [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	84.8	25.6
Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	1,147.2	1,042.4
Southwestern Electric Power Co [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	438.5	547.3
AEP Texas Inc. [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	326.5	298.3
AEP Texas Inc. [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	$ 87.2	67
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	$ 1,600
February 2021 Severe Storm Fuel Costs \| Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	293.7	329
February 2021 Severe Storm Fuel Costs \| Southwestern Electric Power Co [Member] \| Arkansas
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	$ 66.4	74.9
Remaining Recovery Period	6 years
February 2021 Severe Storm Fuel Costs \| Southwestern Electric Power Co [Member] \| Louisiana Jurisdiction [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	$ 109.5	121.7
February 2021 Severe Storm Fuel Costs \| Southwestern Electric Power Co [Member] \| Texas
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	$ 117.8	$ 132.4
Approved Carrying Charge	1.65%
Remaining Recovery Period	5 years
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	195
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
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
Requested Return on Equity	10%
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 Return on Equity	10.35%
Approved Return on Common Equity	9.50%
Requested Annual Increase	$ 134
Revised Requested Annual Increase	95
Approved Annual Revenue Increase	27
Authorized Annual Base Rate Increase	21
Approved Rider to Recover Dolet Hills and Pirkey Costs	14
Reduction in Fuel Costs	$ 8
2021 Louisiana Storm Cost Filing \| Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Interim WACC	3.125%
Approved Deferred Storm Costs	$ 150
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	$ 791
2022 Oklahoma Base Rate Case [Member] \| Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Requested Return on Equity	10.40%
Amount of Increase Related to Annual Depreciation Expense	$ 47
Requested Debt Capital Structure	45.40%
Requested Equity Capital Structure	54.60%
Requested Net Increase in Oklahoma Annual Revenues	$ 173
Amount of Increase Related to Annual Amortization Expense	$ 16
Wind Generation MWs \| MW	154
OCC Staff and Intervenor Recommended Plant Investments	$ 9
Contested Joint Agreement Base Rate Annual Revenue Increase	$ 50
Contested Joint Agreement Return on Equity	9.50%
Contested Joint Agreement Debt Capital Structure	45.40%
Contested Joint Agreement Equity Capital Structure	54.60%
Contested Joint Agreement Distribution Investments Recovery	$ 6
Contested Joint Agreement Interim Annual Base Rate Cumulative Revenue Increase	16
2022 Oklahoma Base Rate Case [Member] \| Public Service Co Of Oklahoma [Member] \| Minimum [Member]
Public Utilities, General Disclosures [Line Items]
OCC Staff and Intervenor Recommended Annual Revenue Change Range	$ 42
OCC Staff and Intervenor Recommended ROE Range	8.60%
2022 Oklahoma Base Rate Case [Member] \| Public Service Co Of Oklahoma [Member] \| Maximum [Member]
Public Utilities, General Disclosures [Line Items]
OCC Staff and Intervenor Recommended Annual Revenue Change Range	$ 49
OCC Staff and Intervenor Recommended ROE Range	9.50%

Rate Matters FERC (Details)

Rate Matters FERC (Details) - USD ($) $ in Millions	6 Months Ended
Rate Matters FERC (Details) - USD ($) $ in Millions	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2021
FERC PJM Transmission Formula Rate Challenge [Member]
Public Utilities, General Disclosures [Line Items]
Stand Alone Treatment of NOLCs Annual Revenue Increase	$ 60	$ 69	$ 78
FERC RTO Incentive Complaint [Member]
Public Utilities, General Disclosures [Line Items]
Estimated Pretax Income Reduction	20
Independence Energy Connection Project [Member]
Public Utilities, General Disclosures [Line Items]
AEP Share of Independence Energy Connection Capital Costs	$ 90
Ohio Power Co [Member] \| Ohio Transmission Company [Member] \| FERC RTO Incentive Complaint [Member]
Public Utilities, General Disclosures [Line Items]
Basis Point RTO Incentive	50%

Commitments, Guarantees and C_3

Commitments, Guarantees and Contingencies (Details)	6 Months Ended
Commitments, Guarantees and Contingencies (Details)	Jun. 30, 2023 USD ($)
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	$ 45,000,000
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Damages Representing Lost Mining Fees for Sabine	85,000,000
AEP Wind Holdings LLC [Member] \| Generation And Marketing [Member]
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Maximum Potential Amount of Future Payments Associated with Guarantee	78,000,000
Guarantor Obligations, Current Carrying Value	5,000,000
Guarantor Obligations, Current Carrying Value, Contingent Portion	1,000,000
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	5,600,000
Indiana Michigan Power Co [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	4,200,000
Ohio Power Co [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	7,000,000
Public Service Co Of Oklahoma [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	4,700,000
Southwestern Electric Power Co [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	5,400,000
Letters of Credit [Member]
Maximum Future Payments for Letters of Credit [Abstract]
Maximum Future Payments for Letters of Credit Issued Under the Uncommitted Facility	288,800,000
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Letters of Credit Limit	1,200,000,000
Uncommitted Facility	450,000,000
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

Acquisitions and Dispositions (

Acquisitions and Dispositions (Details)	3 Months Ended	6 Months Ended
Acquisitions and Dispositions (Details)	Jun. 30, 2022 USD ($)	Jun. 30, 2023 USD ($) GWh MW	Jun. 30, 2022 USD ($)	Dec. 31, 2022 USD ($)
Accounts Receivable and Accrued Unbilled Revenues		$ 990,800,000		$ 1,145,100,000
Net Property, Plant and Equipment		74,681,400,000		73,339,100,000
Assets Held for Sale		1,382,800,000		0
Accounts Payable, Current		2,433,900,000		2,670,800,000
Liabilities Held for Sale		64,800,000		0
Proceeds from Sale of Property, Plant, and Equipment		1,000,000	$ 208,500,000
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
Transmission Operations [Member] \| Proceeds for KY Operations
Enterprise Value		2,646,000,000
Generation And Marketing [Member] \| 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
Generation And Marketing [Member] \| BP Wind Energy
Impairment of Equity Method Investment	$ 186,000,000
Generation And Marketing [Member] \| Competitive Contracted Renewable Portfolio
gain (loss) on Disposition of Business net of Tax		(88,500,000)
Accounts Receivable and Accrued Unbilled Revenues		10,000,000
Net Property, Plant and Equipment		1,394,000,000
Disposal Group, Including Discontinued Operation, Other Assets		67,300,000
Disposal Group, Including Discontinued Operation, Assets		1,471,300,000
Assets Held for Sale		1,382,800,000
Accounts Payable, Current		4,600,000
Asset Retirement Obligation		31,000,000
Operating Lease, Liability		21,600,000
Disposal Group, Including Discontinued Operation, Other Liabilities, Current		7,600,000
Liabilities Held for Sale		64,800,000
Generation And Marketing [Member] \| Competitive Contracted Renewables
Enterprise Value		$ 1,500,000,000
Contracted Renewables GWs \| GWh		1.4
Competitive Contracted Renewables NBV		$ 1,200,000,000
Equity Method Investment, Ownership Percentage		50%
Equity Method Investments		$ 246,000,000
Proceeds from Sale of Productive Assets		1,200,000,000
Gain (Loss) on Disposition of Business		112,000,000
gain (loss) on Disposition of Business net of Tax		88,000,000
Other Noncontrolling Interests		183,000,000
EQ Method Investments		246,000,000
Deferred Tax Assets, Gross		23,500,000
Vertically Integrated Utilities [Member]
Enterprise Value		2,850,000,000
Pretax Reduction in Investment Basis		335,000,000
Vertically Integrated Utilities [Member] \| Proceeds for KY Operations
Enterprise Value		$ 2,646,000,000
Vertically Integrated Utilities [Member] \| Sundance [Member]
Wind Generation MWs \| MW		199
Vertically Integrated Utilities [Member] \| Maverick [Member]
Wind Generation MWs \| MW		287
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%
Payments to Acquire Property, Plant, and Equipment		$ 146,000,000
Accounts Receivable and Accrued Unbilled Revenues		80,500,000		70,100,000
Net Property, Plant and Equipment		5,944,300,000		5,626,500,000
Accounts Payable, Current		$ 284,200,000		202,900,000
Southwestern Electric Power Co [Member]
Percentage of an Asset Acquired		54.50%
Payments to Acquire Property, Plant, and Equipment		$ 0	$ (658,000,000)
Accounts Receivable and Accrued Unbilled Revenues		38,600,000		38,800,000
Net Property, Plant and Equipment		8,472,900,000		8,262,200,000
Accounts Payable, Current		260,200,000		213,100,000
AEP Transmission Co [Member]
Accounts Receivable and Accrued Unbilled Revenues		91,100,000		46,900,000
Net Property, Plant and Equipment		14,037,700,000		13,339,900,000
Accounts Payable, Current		$ 387,400,000		$ 427,800,000

Benefit Plans (Details)

Benefit Plans (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
Benefit Plans (Details) - USD ($) $ in Millions	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Pension Plans [Member]
Components of Net Periodic Benefit Cost
Service Cost	$ 23.6	$ 30.8	$ 47.2	$ 61.6
Interest Cost	54.8	37.1	109.6	74.1
Expected Return on Plan Assets	(84.8)	(63.3)	(169.6)	(126.7)
Amortization of Net Actuarial Loss	0.4	15.7	0.7	31.5
Net Periodic Benefit Cost (Credit)	(6)	20.3	(12.1)	40.5
Pension Plans [Member] \| AEP Texas Inc. [Member]
Components of Net Periodic Benefit Cost
Service Cost	2.1	2.8	4.1	5.6
Interest Cost	4.6	3	9.2	6
Expected Return on Plan Assets	(7)	(5.2)	(14)	(10.5)
Amortization of Net Actuarial Loss	0	1.3	0	2.6
Net Periodic Benefit Cost (Credit)	(0.3)	1.9	(0.7)	3.7
Pension Plans [Member] \| Appalachian Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	2.2	2.8	4.5	5.7
Interest Cost	6.6	4.4	13.2	8.8
Expected Return on Plan Assets	(11.1)	(8.1)	(22.3)	(16.2)
Amortization of Net Actuarial Loss	0	1.8	0	3.6
Net Periodic Benefit Cost (Credit)	(2.3)	0.9	(4.6)	1.9
Pension Plans [Member] \| Indiana Michigan Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	3	4.1	6	8.1
Interest Cost	6.2	4.2	12.4	8.4
Expected Return on Plan Assets	(11.1)	(8.1)	(22.1)	(16.1)
Amortization of Net Actuarial Loss	0	1.7	0	3.5
Net Periodic Benefit Cost (Credit)	(1.9)	1.9	(3.7)	3.9
Pension Plans [Member] \| Ohio Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	2.1	2.9	4.2	5.6
Interest Cost	5	3.2	9.9	6.6
Expected Return on Plan Assets	(8.5)	(6.2)	(17)	(12.4)
Amortization of Net Actuarial Loss	0	1.4	0	2.8
Net Periodic Benefit Cost (Credit)	(1.4)	1.3	(2.9)	2.6
Pension Plans [Member] \| Public Service Co Of Oklahoma [Member]
Components of Net Periodic Benefit Cost
Service Cost	1.4	1.8	2.8	3.7
Interest Cost	2.7	1.7	5.4	3.5
Expected Return on Plan Assets	(4.6)	(3.4)	(9.2)	(6.8)
Amortization of Net Actuarial Loss	0	0.8	0	1.5
Net Periodic Benefit Cost (Credit)	(0.5)	0.9	(1)	1.9
Pension Plans [Member] \| Southwestern Electric Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	1.9	2.7	3.8	5.3
Interest Cost	3.5	2.3	7	4.6
Expected Return on Plan Assets	(4.9)	(3.6)	(9.7)	(7.3)
Amortization of Net Actuarial Loss	0	0.9	0	1.9
Net Periodic Benefit Cost (Credit)	0.5	2.3	1.1	4.5
Other Postretirement Benefit Plans [Member]
Components of Net Periodic Benefit Cost
Service Cost	1.2	1.9	2.3	3.7
Interest Cost	11.5	7.3	23.1	14.6
Expected Return on Plan Assets	(27.4)	(27.5)	(54.8)	(55)
Amortization of Prior Service Cost (Credit)	(15.7)	(17.9)	(31.5)	(35.7)
Amortization of Net Actuarial Loss	3.7		7.4
Net Periodic Benefit Cost (Credit)	(26.7)	(36.2)	(53.5)	(72.4)
Other Postretirement Benefit Plans [Member] \| AEP Texas Inc. [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.1	0.1	0.2	0.2
Interest Cost	0.9	0.5	1.8	1.1
Expected Return on Plan Assets	(2.2)	(2.2)	(4.5)	(4.5)
Amortization of Prior Service Cost (Credit)	(1.4)	(1.5)	(2.7)	(3)
Amortization of Net Actuarial Loss	0.3		0.6
Net Periodic Benefit Cost (Credit)	(2.3)	(3.1)	(4.6)	(6.2)
Other Postretirement Benefit Plans [Member] \| Appalachian Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.2	0.2	0.3	0.4
Interest Cost	1.9	1.1	3.7	2.3
Expected Return on Plan Assets	(4)	(4)	(8)	(8.1)
Amortization of Prior Service Cost (Credit)	(2.3)	(2.6)	(4.6)	(5.2)
Amortization of Net Actuarial Loss	0.5		1.1
Net Periodic Benefit Cost (Credit)	(3.7)	(5.3)	(7.5)	(10.6)
Other Postretirement Benefit Plans [Member] \| Indiana Michigan Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.2	0.3	0.4	0.5
Interest Cost	1.4	0.9	2.7	1.7
Expected Return on Plan Assets	(3.4)	(3.5)	(6.8)	(6.9)
Amortization of Prior Service Cost (Credit)	(2.1)	(2.5)	(4.3)	(4.9)
Amortization of Net Actuarial Loss	0.4		0.9
Net Periodic Benefit Cost (Credit)	(3.5)	(4.8)	(7.1)	(9.6)
Other Postretirement Benefit Plans [Member] \| Ohio Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.1	0.1	0.2	0.3
Interest Cost	1.1	0.8	2.3	1.5
Expected Return on Plan Assets	(3)	(2.9)	(5.9)	(5.9)
Amortization of Prior Service Cost (Credit)	(1.5)	(1.8)	(3.1)	(3.6)
Amortization of Net Actuarial Loss	0.4		0.8
Net Periodic Benefit Cost (Credit)	(2.9)	(3.8)	(5.7)	(7.7)
Other Postretirement Benefit Plans [Member] \| Public Service Co Of Oklahoma [Member]
Components of Net Periodic Benefit Cost
Service Cost	0	0.1	0.1	0.2
Interest Cost	0.6	0.3	1.2	0.7
Expected Return on Plan Assets	(1.4)	(1.5)	(2.9)	(3)
Amortization of Prior Service Cost (Credit)	(1)	(1.1)	(2)	(2.2)
Amortization of Net Actuarial Loss	0.2		0.4
Net Periodic Benefit Cost (Credit)	(1.6)	(2.2)	(3.2)	(4.3)
Other Postretirement Benefit Plans [Member] \| Southwestern Electric Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.1	0.2	0.2	0.3
Interest Cost	0.7	0.4	1.4	0.9
Expected Return on Plan Assets	(1.8)	(1.8)	(3.6)	(3.7)
Amortization of Prior Service Cost (Credit)	(1.2)	(1.3)	(2.4)	(2.6)
Amortization of Net Actuarial Loss	0.3		0.5
Net Periodic Benefit Cost (Credit)	$ (1.9)	$ (2.5)	$ (3.9)	$ (5.1)

Business Segments (Details)

Business Segments (Details) - USD ($) $ in Millions		3 Months Ended						6 Months Ended
Business Segments (Details) - USD ($) $ in Millions		Jun. 30, 2023		Mar. 31, 2023	Jun. 30, 2022		Mar. 31, 2022	Jun. 30, 2023		Jun. 30, 2022		Dec. 31, 2022
Reportable Segment Information
Interest Expense		$ 460			$ 327.6			$ 875.7		$ 641
Revenue from Contracts with Customers		4,372.5			4,639.7			9,063.4		9,232.3
Revenues		4,372.5			4,639.7			9,063.4		9,232.3
Net Income (Loss)		516.1		$ 400.4	520.8		$ 718.1	916.5		1,238.9
Income Tax (Expense) Benefit		28.6			54			39		106.8
Balance Sheet Information
Total Property, Plant and Equipment		98,415.8						98,415.8				$ 97,021.4
Accumulated Depreciation and Amortization		23,734.4						23,734.4				23,682.3
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		74,681.4						74,681.4				73,339.1
Total Assets		96,002.1	[1]					96,002.1	[1]			93,403.3
Long-term Debt Due Within One Year		3,380.3						3,380.3				2,486.4
Long-term Debt		36,762						36,762				34,314.6
Total Long-term Debt Outstanding		40,142.3						40,142.3				36,801
Related Party
Reportable Segment Information
Revenue from Contracts with Customers		0			0			0		0
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reportable Segment Information
Interest Expense	[2]	(0.5)			1.1			0.2		2.2
Income Tax (Expense) Benefit		5.1			(34.4)			14.2		(44.9)
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
Interest Expense	[2]	(0.5)			1.1			0.2		2.2
Income Tax (Expense) Benefit		(0.1)			0.3			0		0.5
Vertically Integrated Utilities [Member]
Reportable Segment Information
Revenue from Contracts with Customers		2,629			2,595			5,445.3		5,241.8
Transmission and Distribution Utilities Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		1,330.8			1,296.8			2,786.1		2,539
Generation and Marketing Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		318.2			654.4			645.1		1,263.9
Generation and Marketing Revenues [Member] \| Reclassification out of Accumulated Other Comprehensive Income [Member]
Reportable Segment Information
Revenue from Contracts with Customers	[2]				0.1
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	[2]				0
Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		94.5			93.5			186.9		187.6
Revenues		(128.8)	[3]		135.7	[4],[5]		(258.7)	[6],[7]	301.1	[8],[9]
AEP Transmission Co [Member]
Reportable Segment Information
Interest Expense		50.7			39.3			95.9		77
Interest Income		2.6			0.2			4.1		0.3
Revenues from Related Parties, Net of Provisions for Refund		357.5			287.1			710.1		602.5
Revenues		444.9			364.4			886.5		764.8
Net Income (Loss)		175.7		$ 162.7	118.5		$ 155.4	338.4		273.9
Income Tax (Expense) Benefit		49.1			34.3			96.8		79.8
Balance Sheet Information
Total Property, Plant and Equipment		15,188.5						15,188.5				14,366.9
Accumulated Depreciation and Amortization		1,150.8						1,150.8				1,027
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		14,037.7						14,037.7				13,339.9
Total Assets		14,576.5						14,576.5				13,814.2
Long-term Debt Due Within One Year		60						60				60
Long-term Debt		5,413						5,413				4,722.8
Total Long-term Debt Outstanding		5,473						5,473				4,782.8
AEP Transmission Co [Member] \| Related Party
Reportable Segment Information
Revenue from Contracts with Customers		365.8			333.9			723.2		658.9
AEP Transmission Co [Member] \| Other Revenues [Member]
Reportable Segment Information
Revenues		0	[10]		0	[11]		0	[12]	0	[13]
AEP Transmission Co [Member] \| Transmission [Member]
Reportable Segment Information
Revenue from Contract with Customers, Net of Provisions for Refund, Including Assessed Tax		87.4			77.3			176.4		162.3
Revenue from Contracts with Customers		90.2			85.6			180.2		172.6
Reconciling Adjustments [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0			0			0		0
Revenues		(464.2)			(373.3)			(907.9)		(765.5)
Net Income (Loss)		0			0			0		0
Balance Sheet Information
Total Assets	[14]	(5,878)	[1]					(5,878)	[1]			(5,783)
Reconciling Adjustments [Member] \| Related Party
Reportable Segment Information
Revenue from Contracts with Customers		(464.2)			(373.3)			(907.9)		(765.5)
Reconciling Adjustments [Member] \| Other Revenues [Member]
Reportable Segment Information
Revenues		(2)	[3]		(2)	[4],[5]		(2.9)	[6],[7]	(4.9)	[8],[9]
Reconciling Adjustments [Member] \| AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0			0			0		0
Revenues		0			0			0		0
Net Income (Loss)		0			0			0		0
Balance Sheet Information
Total Assets	[15]	(5,591.9)						(5,591.9)				(4,878.8)
Reconciling Adjustments [Member] \| AEP Transmission Co [Member] \| Related Party
Reportable Segment Information
Revenue from Contracts with Customers		0			0			0		0
Vertically Integrated Utilities [Member]
Reportable Segment Information
Revenues		2,674.5			2,648.5			5,532.3		5,335.9
Net Income (Loss)		278.4			303.3			540.6		602.5
Balance Sheet Information
Total Assets		51,047.3	[1]					51,047.3	[1]			49,761.8
Vertically Integrated Utilities [Member] \| Related Party
Reportable Segment Information
Revenue from Contracts with Customers		45.5			53.5			87		94.1
Vertically Integrated Utilities [Member] \| Vertically Integrated Utilities [Member]
Reportable Segment Information
Revenue from Contracts with Customers		2,629			2,595			5,445.3		5,241.8
Vertically Integrated Utilities [Member] \| Other Revenues [Member]
Reportable Segment Information
Revenues		0.1	[3]		0.1	[4],[5]		0	[6],[7]	0.1	[8],[9]
Transmission And Distribution Utilities [Member]
Reportable Segment Information
Revenues		1,340.2			1,301.6			2,804.4		2,548.4
Net Income (Loss)		176.7			164.8			302.4		317.6
Balance Sheet Information
Total Assets		23,900	[1]					23,900	[1]			22,920.2
Transmission And Distribution Utilities [Member] \| Related Party
Reportable Segment Information
Revenue from Contracts with Customers		9.4			4.8			18.3		9.4
Transmission And Distribution Utilities [Member] \| Transmission and Distribution Utilities Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		1,330.8			1,296.8			2,786.1		2,539
Transmission And Distribution Utilities [Member] \| Other Revenues [Member]
Reportable Segment Information
Revenues		6.1	[3]		6.8	[4],[5]		17.2	[6],[7]	13.1	[8],[9]
AEP Transmission Holdco [Member]
Reportable Segment Information
Revenues		458.6			378.8			914.1		790.2
Net Income (Loss)		197.3			142.7			379.7		316.4
Balance Sheet Information
Total Assets		16,023.5	[1]					16,023.5	[1]			15,215.8
AEP Transmission Holdco [Member] \| Related Party
Reportable Segment Information
Revenue from Contracts with Customers		370.3			299.7			735.7		627.7
AEP Transmission Holdco [Member] \| Transmission [Member]
Reportable Segment Information
Revenue from Contracts with Customers		88.3			79.1			178.4		162.5
Generation And Marketing [Member]
Reportable Segment Information
Revenues		331.4			659.6			658.4		1,278.9
Net Income (Loss)		(38.6)			65.9			(195)		181.9
Balance Sheet Information
Total Assets		4,457.9	[1]					4,457.9	[1]			4,520.1
Generation And Marketing [Member] \| Related Party
Reportable Segment Information
Revenue from Contracts with Customers		13.2			5.2			13.3		15
Generation And Marketing [Member] \| Generation and Marketing Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		318.2			654.4			645.1		1,263.9
Generation And Marketing [Member] \| Other Revenues [Member]
Reportable Segment Information
Revenues		(135.2)	[3],[16]		128.5	[4],[5]		(276.2)	[6],[7]	287.7	[8],[9]
All Other [Member]
Reportable Segment Information
Revenues	[17]	32			24.5			62.1		44.4
Net Income (Loss)	[17]	(97.7)			(155.9)			(111.2)		(179.5)
Balance Sheet Information
Total Assets	[17],[18]	6,451.4	[1]					6,451.4	[1]			6,768.4
All Other [Member] \| Related Party
Reportable Segment Information
Revenue from Contracts with Customers	[17]	25.8			10.1			53.6		19.3
All Other [Member] \| Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers	[17]	6.2			14.4			8.5		25.1
Revenues		2.2	[3]		2.3	[4],[5]		3.2	[6],[7]	5.1	[8],[9]
State Transcos [Member] \| AEP Transmission Co [Member]
Reportable Segment Information
Revenues		444.9			364.4			886.5		764.8
Net Income (Loss)		174.2			118.4			335.8		273.8
Balance Sheet Information
Total Assets		14,626.3						14,626.3				13,875.6
State Transcos [Member] \| AEP Transmission Co [Member] \| Related Party
Reportable Segment Information
Revenue from Contracts with Customers		357.5			287.1			710.1		602.5
State Transcos [Member] \| AEP Transmission Co [Member] \| Transmission [Member]
Reportable Segment Information
Revenue from Contracts with Customers		87.4			77.3			176.4		162.3
AEPTCo Parent [Member] \| AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0			0			0		0
Revenues		0			0			0		0
Net Income (Loss)	[19]	1.5			0.1			2.6		0.1
Balance Sheet Information
Total Assets	[20]	5,542.1						5,542.1				$ 4,817.4
AEPTCo Parent [Member] \| AEP Transmission Co [Member] \| Related Party
Reportable Segment Information
Revenue from Contracts with Customers		$ 0			$ 0			$ 0		$ 0

[1]Amount includes Assets Held for Sale on the balance sheet. See “Planned Disposition of the Competitive Contracted Renewables Portfolio” section of Note 6 for additional information.[2]Amounts reclassified to the referenced line item on the statements of income.[3]Amounts include affiliated and nonaffiliated revenues.[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]Generation & Marketing includes economic hedge activity.[10]Amounts include affiliated and nonaffiliated revenues.[11]Amounts include affiliated and nonaffiliated revenues.[12]Amounts include affiliated and nonaffiliated revenues.[13]Amounts include affiliated and nonaffiliated revenues.[14]Reconciling Adjustments for Total Assets primarily include elimination of intercompany advances to affiliates and intercompany accounts receivable.[15]Primarily relates to the elimination of Notes Receivable from the State Transcos.[16]Generation & Marketing includes economic hedge activity.[17]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.[18]Includes elimination of AEP Parent’s investments in wholly-owned subsidiary companies.[19]Includes the elimination of AEPTCo Parent’s equity earnings in the State Transcos.[20]Primarily relates to Notes Receivable from the State Transcos.

Derivatives and Hedging (Detail

Derivatives and Hedging (Details) gal in Millions, MWh in Millions, MMBTU in Millions		3 Months Ended			6 Months Ended			12 Months Ended
		Jun. 30, 2023 USD ($) MMBTU MWh gal		Jun. 30, 2022 USD ($)	Jun. 30, 2023 USD ($) MMBTU MWh gal		Jun. 30, 2022 USD ($)	Dec. 31, 2022 USD ($) MWh MMBTU gal
Cash Collateral Netting
Cash Collateral Received Netted Against Risk Management Assets		$ 73,000,000			$ 73,000,000			$ 481,000,000
Cash Collateral Paid Netted Against Risk Management Liabilities		35,000,000			35,000,000			2,000,000
Fair Value of Derivative Instruments
Current Risk Management Assets		279,500,000			279,500,000			348,800,000
Long-term Risk Management Assets		266,800,000			266,800,000			284,100,000
Total Assets		546,300,000			546,300,000			632,900,000
Current Risk Management Liabilities		176,200,000			176,200,000			145,200,000
Long-term Risk Management Liabilities		275,300,000			275,300,000			345,200,000
Total Liabilities		451,500,000			451,500,000			490,400,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(34,300,000)		$ 257,900,000	(212,500,000)		$ 473,200,000
Carrying Amount of Hedged Asset (Liability)	[1],[2]	(855,100,000)			(855,100,000)			(855,500,000)
Cumulative Fair Value Hedging Adjustment in the Carrying Amount of the Hedged Asset (Liability)	[1],[2]	90,800,000			90,800,000			89,700,000
Gain (Loss) on Hedging Instruments
Gain (Loss) on Fair Value Hedging Instruments	[3]	(4,200,000)		(17,600,000)	2,700,000		(62,400,000)
Gain (Loss) on Fair Value Portion of Long Term Debt	[3]	4,200,000		17,600,000	(2,700,000)		62,400,000
Collateral Triggering Events [Abstract]
Fair Value Of Derivative Liabilities Subject To Cross Acceleration Provisions		125,000,000			125,000,000			127,000,000
Fair Value Of Derivative Liabilities Subject To Cross Default Provisions		178,000,000			178,000,000			217,000,000
Derivatives and Hedging (Textuals) [Abstract]
Hedged Liability, Discontinued Fair Value Hedge, Cumulative Increase (Decrease)		(34,000,000)			(34,000,000)			(38,000,000)
Credit Downgrade Trigger Exposure		0			0			2,000,000
AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(200,000)		1,300,000	(600,000)		2,600,000
Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		39,200,000			39,200,000			69,100,000
Current Risk Management Liabilities		1,100,000			1,100,000			3,600,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		24,600,000		23,000,000	(8,100,000)		23,100,000
Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		21,400,000			21,400,000			15,200,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		19,100,000		2,200,000	14,500,000		2,400,000
Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Liabilities		6,300,000			6,300,000			1,800,000
Long-term Risk Management Liabilities		47,700,000			47,700,000			37,900,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(12,800,000)		23,300,000	(25,100,000)		47,400,000
Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		44,800,000			44,800,000			25,300,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		40,100,000		39,600,000	56,900,000		56,100,000
Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		28,000,000			28,000,000			16,400,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		32,700,000		37,500,000	43,100,000		56,500,000
Risk Management Contracts [Member]
Fair Value of Derivative Instruments
Total Assets	[4]	425,700,000	[5]		425,700,000	[5]		315,400,000	[6]
Total Liabilities	[4]	325,200,000	[5]		325,200,000	[5]		339,800,000	[6]
Risk Management Contracts [Member] \| AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Total Liabilities	[4]	0			0
Risk Management Contracts [Member] \| Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[4],[7]	39,400,000			39,400,000			69,100,000
Total Liabilities	[4],[7]	1,100,000			1,100,000			3,500,000
Risk Management Contracts [Member] \| Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[4],[7]	30,500,000			30,500,000			15,400,000
Total Liabilities	[4],[7]	1,400,000			1,400,000			0
Risk Management Contracts [Member] \| Ohio Power Co [Member]
Fair Value of Derivative Instruments
Total Liabilities	[7]	54,000,000			54,000,000			39,700,000
Risk Management Contracts [Member] \| Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Total Assets	[4],[7]	44,800,000			44,800,000			25,300,000
Total Liabilities	[4],[7]	3,400,000			3,400,000			1,600,000
Risk Management Contracts [Member] \| Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[4],[7]	28,000,000			28,000,000			16,400,000
Total Liabilities	[4],[7]	1,800,000			1,800,000			1,400,000
Commodity [Member]
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		93,500,000			93,500,000			223,500,000
Portion Expected to be Reclassified to Net Income During the Next Twelve Months					$ 24,100,000			119,900,000
Derivatives and Hedging (Textuals) [Abstract]
Maximum Term for Exposure to Variability of Future Cash Flows					93 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	[8]	721,600,000			721,600,000			965,400,000
Long-term Risk Management Assets	[8]	466,400,000			466,400,000			565,600,000
Total Assets	[8]	1,188,000,000			1,188,000,000			1,531,000,000
Current Risk Management Liabilities	[8]	631,500,000			631,500,000			663,800,000
Long-term Risk Management Liabilities	[8]	418,500,000			418,500,000			412,000,000
Total Liabilities	[8]	1,050,000,000			1,050,000,000			1,075,800,000
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	138,000,000			138,000,000			455,200,000
Commodity [Member] \| Risk Management Contracts [Member] \| AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]	0			0			0
Long-term Risk Management Assets	[8]	0			0			0
Total Assets	[8]	0			0			0
Current Risk Management Liabilities	[8]	400,000			400,000			0
Long-term Risk Management Liabilities	[8]	100,000			100,000			0
Total Liabilities	[8]	500,000			500,000			0
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	(500,000)			(500,000)			0
Commodity [Member] \| Risk Management Contracts [Member] \| Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]	42,500,000			42,500,000			69,300,000
Long-term Risk Management Assets	[8]	600,000			600,000			700,000
Total Assets	[8]	43,100,000			43,100,000			70,000,000
Current Risk Management Liabilities	[8]	5,100,000			5,100,000			4,100,000
Long-term Risk Management Liabilities	[8]	400,000			400,000			700,000
Total Liabilities	[8]	5,500,000			5,500,000			4,800,000
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	37,600,000			37,600,000			65,200,000
Commodity [Member] \| Risk Management Contracts [Member] \| Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]	22,300,000			22,300,000			16,000,000
Long-term Risk Management Assets	[8]	11,800,000			11,800,000			500,000
Total Assets	[8]	34,100,000			34,100,000			16,500,000
Current Risk Management Liabilities	[8]	2,800,000			2,800,000			900,000
Long-term Risk Management Liabilities	[8]	2,700,000			2,700,000			300,000
Total Liabilities	[8]	5,500,000			5,500,000			1,200,000
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	28,600,000			28,600,000			15,300,000
Commodity [Member] \| Risk Management Contracts [Member] \| Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]	0			0			0
Long-term Risk Management Assets	[8]	0			0			0
Total Assets	[8]	0			0			0
Current Risk Management Liabilities	[8]	6,600,000			6,600,000			2,100,000
Long-term Risk Management Liabilities	[8]	47,800,000			47,800,000			37,900,000
Total Liabilities	[8]	54,400,000			54,400,000			40,000,000
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	(54,400,000)			(54,400,000)			(40,000,000)
Commodity [Member] \| Risk Management Contracts [Member] \| Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]	47,400,000			47,400,000			24,100,000
Long-term Risk Management Assets	[8]	200,000			200,000			0
Total Assets	[8]	47,600,000			47,600,000			24,100,000
Current Risk Management Liabilities	[8]	5,400,000			5,400,000			2,100,000
Long-term Risk Management Liabilities	[8]	1,000,000			1,000,000			0
Total Liabilities	[8]	6,400,000			6,400,000			2,100,000
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	41,200,000			41,200,000			22,000,000
Commodity [Member] \| Risk Management Contracts [Member] \| Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]	28,500,000			28,500,000			16,800,000
Long-term Risk Management Assets	[8]	0			0			0
Total Assets	[8]	28,500,000			28,500,000			16,800,000
Current Risk Management Liabilities	[8]	2,400,000			2,400,000			2,000,000
Long-term Risk Management Liabilities	[8]	200,000			200,000			0
Total Liabilities	[8]	2,600,000			2,600,000			2,000,000
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	25,900,000			25,900,000			14,800,000
Commodity [Member] \| Hedging Contracts [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]	43,400,000			43,400,000			212,200,000
Long-term Risk Management Assets	[8]	95,100,000			95,100,000			148,900,000
Total Assets	[8]	138,500,000			138,500,000			361,100,000
Current Risk Management Liabilities	[8]	12,800,000			12,800,000			60,400,000
Long-term Risk Management Liabilities	[8]	6,700,000			6,700,000			17,400,000
Total Liabilities	[8]	19,500,000			19,500,000			77,800,000
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	119,000,000			119,000,000			283,300,000
Interest Rate [Member]
Commodity:
Derivative, Notional Amount		950,000,000			950,000,000			1,650,000,000
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		12,700,000			12,700,000			300,000
Portion Expected to be Reclassified to Net Income During the Next Twelve Months					$ 4,300,000			300,000
Derivatives and Hedging (Textuals) [Abstract]
Maximum Term for Exposure to Variability of Future Cash Flows					90 months
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		2,900,000			2,900,000			(300,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months					300,000			(200,000)
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		6,300,000			6,300,000			6,700,000
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		(5,700,000)			(5,700,000)			(5,100,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months					(400,000)			(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			200,000,000
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		(200,000)			(200,000)			1,300,000
Portion Expected to be Reclassified to Net Income During the Next Twelve Months					0			100,000
Interest Rate [Member] \| Southwestern Electric Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0			0
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		1,400,000			1,400,000			1,100,000
Portion Expected to be Reclassified to Net Income During the Next Twelve Months					300,000			200,000
Interest Rate [Member] \| Hedging Contracts [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]	0			0			1,800,000
Long-term Risk Management Assets	[8]	0			0			14,300,000
Total Assets	[8]	0			0			16,100,000
Current Risk Management Liabilities	[8]	42,600,000			42,600,000			41,400,000
Long-term Risk Management Liabilities	[8]	82,100,000			82,100,000			91,100,000
Total Liabilities	[8]	124,700,000			124,700,000			132,500,000
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	(124,700,000)			(124,700,000)			(116,400,000)
Interest Rate [Member] \| Hedging Contracts [Member] \| Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]							1,600,000
Long-term Risk Management Assets	[8]							0
Total Assets	[8]							1,600,000
Current Risk Management Liabilities	[8]							0
Long-term Risk Management Liabilities	[8]							0
Total Liabilities	[8]							0
Total MTM Derivative Contract Net Assets (Liabilities)	[8]							1,600,000
Gross Amounts of Risk Management Assets/Liabilities Recognized [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		765,000,000			765,000,000			1,179,400,000
Long-term Risk Management Assets		561,500,000			561,500,000			728,800,000
Total Assets		1,326,500,000			1,326,500,000			1,908,200,000
Current Risk Management Liabilities		686,900,000			686,900,000			765,600,000
Long-term Risk Management Liabilities		507,300,000			507,300,000			520,500,000
Total Liabilities		1,194,200,000			1,194,200,000			1,286,100,000
Total MTM Derivative Contract Net Assets (Liabilities)		132,300,000			132,300,000			622,100,000
Gross Amounts of Risk Management Assets/Liabilities Recognized [Member] \| Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets								25,700,000
Long-term Risk Management Assets								0
Total Assets								25,700,000
Current Risk Management Liabilities								2,100,000
Long-term Risk Management Liabilities								0
Total Liabilities								2,100,000
Total MTM Derivative Contract Net Assets (Liabilities)								23,600,000
Gross Amounts Offset in the Statement of Financial Position [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	(485,500,000)			(485,500,000)			(830,600,000)
Long-term Risk Management Assets	[9]	(294,700,000)			(294,700,000)			(444,700,000)
Total Assets	[9]	(780,200,000)			(780,200,000)			(1,275,300,000)
Current Risk Management Liabilities	[9]	(510,700,000)			(510,700,000)			(620,400,000)
Long-term Risk Management Liabilities	[9]	(232,000,000)			(232,000,000)			(175,300,000)
Total Liabilities	[9]	(742,700,000)			(742,700,000)			(795,700,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	(37,500,000)			(37,500,000)			(479,600,000)
Gross Amounts Offset in the Statement of Financial Position [Member] \| AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	0			0			0
Long-term Risk Management Assets	[9]	0			0			0
Total Assets	[9]	0			0			0
Current Risk Management Liabilities	[9]	(400,000)			(400,000)			0
Long-term Risk Management Liabilities	[9]	(100,000)			(100,000)			0
Total Liabilities	[9]	(500,000)			(500,000)			0
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	500,000			500,000			0
Gross Amounts Offset in the Statement of Financial Position [Member] \| Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	(3,300,000)			(3,300,000)			(200,000)
Long-term Risk Management Assets	[9]	(400,000)			(400,000)			(700,000)
Total Assets	[9]	(3,700,000)			(3,700,000)			(900,000)
Current Risk Management Liabilities	[9]	(4,000,000)			(4,000,000)			(500,000)
Long-term Risk Management Liabilities	[9]	(400,000)			(400,000)			(600,000)
Total Liabilities	[9]	(4,400,000)			(4,400,000)			(1,100,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	700,000			700,000			200,000
Gross Amounts Offset in the Statement of Financial Position [Member] \| Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	(900,000)			(900,000)			(800,000)
Long-term Risk Management Assets	[9]	(2,700,000)			(2,700,000)			(300,000)
Total Assets	[9]	(3,600,000)			(3,600,000)			(1,100,000)
Current Risk Management Liabilities	[9]	(1,400,000)			(1,400,000)			(900,000)
Long-term Risk Management Liabilities	[9]	(2,700,000)			(2,700,000)			(300,000)
Total Liabilities	[9]	(4,100,000)			(4,100,000)			(1,200,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	500,000			500,000			100,000
Gross Amounts Offset in the Statement of Financial Position [Member] \| Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	0			0			0
Long-term Risk Management Assets	[9]	0			0			0
Total Assets	[9]	0			0			0
Current Risk Management Liabilities	[9]	(300,000)			(300,000)			(300,000)
Long-term Risk Management Liabilities	[9]	(100,000)			(100,000)			0
Total Liabilities	[9]	(400,000)			(400,000)			(300,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	400,000			400,000			300,000
Gross Amounts Offset in the Statement of Financial Position [Member] \| Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	(2,600,000)			(2,600,000)			(400,000)
Long-term Risk Management Assets	[9]	(200,000)			(200,000)			0
Total Assets	[9]	(2,800,000)			(2,800,000)			(400,000)
Current Risk Management Liabilities	[9]	(2,800,000)			(2,800,000)			(500,000)
Long-term Risk Management Liabilities	[9]	(200,000)			(200,000)			0
Total Liabilities	[9]	(3,000,000)			(3,000,000)			(500,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	200,000			200,000			100,000
Gross Amounts Offset in the Statement of Financial Position [Member] \| Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	(500,000)			(500,000)			(400,000)
Long-term Risk Management Assets	[9]	0			0			0
Total Assets	[9]	(500,000)			(500,000)			(400,000)
Current Risk Management Liabilities	[9]	(800,000)			(800,000)			(600,000)
Long-term Risk Management Liabilities	[9]	0			0			0
Total Liabilities	[9]	(800,000)			(800,000)			(600,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	300,000			300,000			200,000
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[10]	279,500,000			279,500,000			348,800,000
Long-term Risk Management Assets	[10]	266,800,000			266,800,000			284,100,000
Total Assets	[10]	546,300,000			546,300,000			632,900,000
Current Risk Management Liabilities	[10]	176,200,000			176,200,000			145,200,000
Long-term Risk Management Liabilities	[10]	275,300,000			275,300,000			345,200,000
Total Liabilities	[10]	451,500,000			451,500,000			490,400,000
Total MTM Derivative Contract Net Assets (Liabilities)	[10]	94,800,000			94,800,000			142,500,000
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	[10]	0			0			0
Long-term Risk Management Assets	[10]	0			0			0
Total Assets	[10]	0			0			0
Current Risk Management Liabilities	[10]	0			0			0
Long-term Risk Management Liabilities	[10]	0			0			0
Total Liabilities	[10]	0			0			0
Total MTM Derivative Contract Net Assets (Liabilities)	[10]	0			0			0
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member] \| Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[10]	39,200,000			39,200,000			69,100,000
Long-term Risk Management Assets	[10]	200,000			200,000			0
Total Assets	[10]	39,400,000			39,400,000			69,100,000
Current Risk Management Liabilities	[10]	1,100,000			1,100,000			3,600,000
Long-term Risk Management Liabilities	[10]	0			0			100,000
Total Liabilities	[10]	1,100,000			1,100,000			3,700,000
Total MTM Derivative Contract Net Assets (Liabilities)	[10]	38,300,000			38,300,000			65,400,000
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	[10]	21,400,000			21,400,000			15,200,000
Long-term Risk Management Assets	[10]	9,100,000			9,100,000			200,000
Total Assets	[10]	30,500,000			30,500,000			15,400,000
Current Risk Management Liabilities	[10]	1,400,000			1,400,000			0
Long-term Risk Management Liabilities	[10]	0			0			0
Total Liabilities	[10]	1,400,000			1,400,000			0
Total MTM Derivative Contract Net Assets (Liabilities)	[10]	29,100,000			29,100,000			15,400,000
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	[10]	0			0			0
Long-term Risk Management Assets	[10]	0			0			0
Total Assets	[10]	0			0			0
Current Risk Management Liabilities	[10]	6,300,000			6,300,000			1,800,000
Long-term Risk Management Liabilities	[10]	47,700,000			47,700,000			37,900,000
Total Liabilities	[10]	54,000,000			54,000,000			39,700,000
Total MTM Derivative Contract Net Assets (Liabilities)	[10]	(54,000,000)			(54,000,000)			(39,700,000)
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	[10]	44,800,000			44,800,000			25,300,000
Long-term Risk Management Assets	[10]	0			0			0
Total Assets	[10]	44,800,000			44,800,000			25,300,000
Current Risk Management Liabilities	[10]	2,600,000			2,600,000			1,600,000
Long-term Risk Management Liabilities	[10]	800,000			800,000			0
Total Liabilities	[10]	3,400,000			3,400,000			1,600,000
Total MTM Derivative Contract Net Assets (Liabilities)	[10]	41,400,000			41,400,000			23,700,000
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	[10]	28,000,000			28,000,000			16,400,000
Long-term Risk Management Assets	[10]	0			0			0
Total Assets	[10]	28,000,000			28,000,000			16,400,000
Current Risk Management Liabilities	[10]	1,600,000			1,600,000			1,400,000
Long-term Risk Management Liabilities	[10]	200,000			200,000			0
Total Liabilities	[10]	1,800,000			1,800,000			1,400,000
Total MTM Derivative Contract Net Assets (Liabilities)	[10]	$ 26,200,000			$ 26,200,000			$ 15,000,000
Power [Member]
Commodity:
Derivative, Energy Notional Amount \| MWh		269.9			269.9			226.8
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		29.1			29.1			17.9
Power [Member] \| Indiana Michigan Power Co [Member]
Commodity:
Derivative, Energy Notional Amount \| MWh		9.2			9.2			4.2
Power [Member] \| Ohio Power Co [Member]
Commodity:
Derivative, Energy Notional Amount \| MWh		2.3			2.3			2.5
Power [Member] \| Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Energy Notional Amount \| MWh		8.7			8.7			2.9
Power [Member] \| Southwestern Electric Power Co [Member]
Commodity:
Derivative, Energy Notional Amount \| MWh		6.9			6.9			2.2
Natural Gas [Member]
Commodity:
Derivative, Energy Notional Amount \| MMBTU		136.8			136.8			77.1
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		5.2			5.2			1.9
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		28.3			28.3			1.9
Natural Gas [Member] \| Southwestern Electric Power Co [Member]
Commodity:
Derivative, Energy Notional Amount \| MMBTU		7.3			7.3			2.1
Heating Oil and Gasoline [Member]
Commodity:
Derivative, Volume Notional Amount \| gal		6.7			6.7			6.9
Heating Oil and Gasoline [Member] \| AEP Texas Inc. [Member]
Commodity:
Derivative, Volume Notional Amount \| gal		1.8			1.8			1.9
Heating Oil and Gasoline [Member] \| Appalachian Power Co [Member]
Commodity:
Derivative, Volume Notional Amount \| gal		1			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		1.4			1.4			1.4
Heating Oil and Gasoline [Member] \| Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Volume Notional Amount \| gal		0.9			0.9			0.9
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		$ 91,400,000			$ 91,400,000			$ 99,900,000
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
Vertically Integrated Utilities Revenues [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		17,000,000		100,000	11,700,000		100,000
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		(141,800,000)		121,000,000	(289,200,000)		273,300,000
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
Electric Generation, Transmission and Distribution Revenues [Member] \| AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0			0		0
Electric Generation, Transmission and Distribution Revenues [Member] \| Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0			0		100,000
Electric Generation, Transmission and Distribution Revenues [Member] \| Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		17,000,000			11,700,000		(100,000)
Electric Generation, Transmission and Distribution Revenues [Member] \| Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0			0		0
Electric Generation, Transmission and Distribution Revenues [Member] \| Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0			0		0
Electric Generation, Transmission and Distribution Revenues [Member] \| Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0			0		0
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		1,300,000		900,000	2,000,000		2,400,000
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [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, Fuel and Other Consumables Used for Electric Generation [Member] \| Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		1,300,000		700,000	1,900,000		2,100,000
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [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		0
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [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, Fuel and Other Consumables Used for Electric Generation [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		100,000	0		100,000
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [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		(100,000)		1,700,000	(100,000)		2,300,000
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		0		500,000	0		700,000
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		0		200,000	0		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		0		200,000	0		300,000
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		0		300,000	0		400,000
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		0		200,000	0		300,000
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		0		300,000	0		400,000
Maintenance Expense [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(300,000)		2,400,000	(200,000)		3,200,000
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		(100,000)		700,000	(100,000)		900,000
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		0		400,000	0		500,000
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		0		200,000	0		300,000
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		0		400,000	0		500,000
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		0		300,000	0		400,000
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		0		400,000	0		500,000
Regulatory Assets [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	(12,400,000)		21,400,000	(37,200,000)		45,000,000
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	[11]	(100,000)		100,000	(500,000)		100,000
Regulatory Assets [Member] \| Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	5,900,000		100,000	(1,200,000)		0
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	[11]	(1,600,000)		300,000	(2,100,000)		(1,300,000)
Regulatory Assets [Member] \| Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	(12,800,000)		21,000,000	(25,100,000)		44,900,000
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	[11]	(2,300,000)		0	(3,500,000)		3,600,000
Regulatory Assets [Member] \| Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	(900,000)		(100,000)	(2,400,000)		(2,200,000)
Regulatory Liabilities [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	102,000,000		110,400,000	100,500,000		146,900,000
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	[11]	0		0	0		900,000
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	[11]	17,400,000		21,600,000	(8,800,000)		20,200,000
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	[11]	3,600,000		1,500,000	4,800,000		3,200,000
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	[11]	0		1,600,000	0		1,600,000
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	[11]	42,400,000		39,000,000	60,400,000		51,700,000
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	[11]	$ 33,600,000		$ 36,900,000	$ 45,500,000		$ 57,800,000

[1]Amounts include $(34) million and $(38) million as of June 30, 2023 and December 31, 2022, respectively, for the fair value hedge adjustment of hedged debt obligations for which hedge accounting has been discontinued.[2]Amounts included on the Balance Sheet within Noncurrent Liabilities line item Long-term Debt.[3]Gain (Loss) is included in Interest Expense on the statements of income.[4]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.’’[5]The June 30, 2023 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $(6) million in 2023 and $(8) million in periods 2024-2026; Level 2 matures $(27) million in 2023, $59 million in periods 2024-2026, $12 million in periods 2027-2028 and $2 million in periods 2029-2033; Level 3 matures $63 million in 2023, $56 million in periods 2024-2026, $1 million in periods 2027-2028 and $(14) million in periods 2029-2033. Risk management commodity contracts are substantially comprised of power contracts.[6]The December 31, 2022 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $(7) million in 2023; Level 2 matures $182 million in 2023, $134 million in periods 2024-2026, $10 million in periods 2027-2028 and $1 million in periods 2029-2033; Level 3 matures $128 million in 2023, $6 million in periods 2024-2026, $6 million in periods 2027-2028 and $(5) million in periods 2029-2033. Risk management commodity contracts are substantially comprised of power contracts.[7]Substantially comprised of power contracts for the Registrant Subsidiaries.[8]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.”[9]Amounts include counterparty netting of risk management and hedging contracts and associated cash collateral in accordance with the accounting guidance for “Derivatives and Hedging.”[10]All derivative contracts subject to a master netting arrangement or similar agreement are offset in the statement of financial position.[11]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		6 Months Ended		12 Months Ended
		Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Dec. 31, 2022
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		$ 40,142,300,000		$ 40,142,300,000		$ 36,801,000,000
Long Term Debt, Fair Value	[1]	36,351,300,000		36,351,300,000		32,915,900,000
Other Temporary Investments
Cost		232,800,000		232,800,000		223,600,000
Gross Unrealized Gains		24,400,000		24,400,000		19,400,000
Gross Unrealized Losses		(8,900,000)		(8,900,000)		(8,300,000)
Other Short-term Investments		248,300,000		248,300,000		234,700,000
Debt and Equity Securities Within Other Temporary Investments
Proceeds from Investment Sales		0	$ 11,100,000	0	$ 15,000,000
Purchases of Investments		1,300,000	800,000	2,300,000	1,600,000
Gross Realized Gains on Investment Sales		0	3,300,000	0	3,600,000
Gross Realized Losses on Investment Sales		0	400,000	0	500,000
Nuclear Trust Fund Investments
Fair Value		3,648,800,000		3,648,800,000		3,341,200,000
Securities Activity Within Decommissioning and SNF Trusts
Payments to Acquire Investments				1,235,600,000	1,254,800,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		3,648,800,000		3,648,800,000		3,341,200,000
Spent Nuclear Fuel and Decommissioning Trusts [Member]
Securities Activity Within Decommissioning and SNF Trusts
Payments to Acquire Investments		697,000,000	745,500,000	1,233,300,000	1,253,200,000
Realized Investment Gains (Losses)		6,400,000	10,900,000	54,800,000	16,700,000
Gain (Loss) on Investments		3,700,000	17,900,000	12,300,000	25,100,000
Contractual Maturities, Fair Value of Debt Securities
Within 1 year		325,000,000		325,000,000
After 1 year through 5 years		496,900,000		496,900,000
After 5 years through 10 years		219,200,000		219,200,000
After 10 years		222,900,000		222,900,000
Fair Value Measurements (Textuals)
Adjusted Cost of Debt Securities		1,300,000,000		1,300,000,000		1,200,000,000
Adjusted Cost of Domestic Equity Securities		640,000,000		640,000,000		654,000,000
Other than Temporary Impairment Losses, Investments				(27,300,000)		(28,500,000)
Proceeds from Sale of Other Investments		688,700,000	736,400,000	1,206,300,000	1,229,900,000
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Loss, before Tax		(25,000,000)		(25,000,000)		(29,000,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		1,736,400,000		1,736,400,000		1,496,300,000
Cash [Member]
Other Temporary Investments
Cost	[2]	45,800,000		45,800,000		47,100,000
Gross Unrealized Gains	[2]	0		0		0
Gross Unrealized Losses	[2]	0		0		0
Other Short-term Investments	[2]	45,800,000		45,800,000		47,100,000
Fixed Income Funds [Member]
Nuclear Trust Fund Investments
Fair Value		1,264,000,000		1,264,000,000		1,188,700,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,264,000,000		1,264,000,000		1,188,700,000
Fixed Income Funds [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				(27,300,000)		(28,500,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Loss, before Tax		(20,400,000)		(20,400,000)		(22,600,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		10,700,000		10,700,000		12,600,000
Mutual Funds Fixed Income [Member]
Other Temporary Investments
Cost	[3]	155,700,000		155,700,000		152,400,000
Gross Unrealized Gains	[3]	0		0		0
Gross Unrealized Losses	[3]	(8,900,000)		(8,900,000)		(8,300,000)
Other Short-term Investments	[3]	146,800,000		146,800,000		144,100,000
Domestic [Member]
Nuclear Trust Fund Investments
Fair Value	[4]	2,360,600,000		2,360,600,000		2,131,300,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[4]	2,360,600,000		2,360,600,000		2,131,300,000
Domestic [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				0		0
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Loss, before Tax		(4,600,000)		(4,600,000)		(6,400,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		1,725,700,000		1,725,700,000		1,483,700,000
Mutual Funds Equity [Member]
Other Temporary Investments
Cost		15,400,000		15,400,000		15,100,000
Gross Unrealized Gains		24,400,000		24,400,000		19,400,000
Gross Unrealized Losses		0		0		0
Other Short-term Investments	[4]	39,800,000		39,800,000		34,500,000
Cash and Cash Equivalents [Member]
Nuclear Trust Fund Investments
Fair Value	[5]	24,200,000		24,200,000		21,200,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[5]	24,200,000		24,200,000		21,200,000
Cash and Cash Equivalents [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				0		0
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Loss, before Tax		0		0		0
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		0		0		0
US Government Agencies Debt Securities [Member]
Nuclear Trust Fund Investments
Fair Value		1,191,900,000		1,191,900,000		1,123,800,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,191,900,000		1,191,900,000		1,123,800,000
US Government Agencies Debt Securities [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				(25,600,000)		(18,800,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Loss, before Tax		(13,800,000)		(13,800,000)		(14,900,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		9,900,000		9,900,000		11,800,000
Corporate Debt [Member]
Nuclear Trust Fund Investments
Fair Value		68,800,000		68,800,000		61,600,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		68,800,000		68,800,000		61,600,000
Corporate Debt [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				(1,700,000)		(9,600,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Loss, before Tax		(6,600,000)		(6,600,000)		(7,700,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		800,000		800,000		700,000
State and Local Jurisdiction [Member]
Nuclear Trust Fund Investments
Fair Value		3,300,000		3,300,000		3,300,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		3,300,000		3,300,000		3,300,000
State and Local Jurisdiction [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				0		(100,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Loss, before Tax		0		0		0
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		0		0		100,000
Other Cash Deposits [Member]
Other Temporary Investments
Cost		15,900,000		15,900,000		9,000,000
Gross Unrealized Gains		0		0		0
Gross Unrealized Losses		0		0		0
Other Short-term Investments		15,900,000		15,900,000		9,000,000
AEP Texas Inc. [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		5,937,500,000		5,937,500,000		5,657,800,000
Long Term Debt, Fair Value		5,295,500,000		5,295,500,000		5,045,800,000
AEP Transmission Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		5,473,000,000		5,473,000,000		4,782,800,000
Long Term Debt, Fair Value		4,719,200,000		4,719,200,000		3,940,500,000
Appalachian Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		5,599,700,000		5,599,700,000		5,410,500,000
Long Term Debt, Fair Value		5,298,400,000		5,298,400,000		5,079,200,000
Indiana Michigan Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		3,464,100,000		3,464,100,000		3,260,800,000
Long Term Debt, Fair Value		3,174,200,000		3,174,200,000		2,929,000,000
Nuclear Trust Fund Investments
Fair Value		3,648,800,000		3,648,800,000		3,341,200,000
Securities Activity Within Decommissioning and SNF Trusts
Payments to Acquire Investments				1,233,300,000	1,253,200,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		3,648,800,000		3,648,800,000		3,341,200,000
Indiana Michigan Power Co [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Securities Activity Within Decommissioning and SNF Trusts
Payments to Acquire Investments		697,000,000	745,500,000	1,233,300,000	1,253,200,000
Realized Investment Gains (Losses)		6,400,000	10,900,000	54,800,000	16,700,000
Gain (Loss) on Investments		3,700,000	17,900,000	12,300,000	25,100,000
Contractual Maturities, Fair Value of Debt Securities
Within 1 year		325,000,000		325,000,000
After 1 year through 5 years		496,900,000		496,900,000
After 5 years through 10 years		219,200,000		219,200,000
After 10 years		222,900,000		222,900,000
Fair Value Measurements (Textuals)
Adjusted Cost of Debt Securities		1,300,000,000		1,300,000,000		1,200,000,000
Adjusted Cost of Domestic Equity Securities		640,000,000		640,000,000		654,000,000
Other than Temporary Impairment Losses, Investments				(27,300,000)		(28,500,000)
Proceeds from Sale of Other Investments		688,700,000	$ 736,400,000	1,206,300,000	$ 1,229,900,000
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Loss, before Tax		(25,000,000)		(25,000,000)		(29,000,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		1,736,400,000		1,736,400,000		1,496,300,000
Indiana Michigan Power Co [Member] \| Fixed Income Funds [Member]
Nuclear Trust Fund Investments
Fair Value		1,264,000,000		1,264,000,000		1,188,700,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,264,000,000		1,264,000,000		1,188,700,000
Indiana Michigan Power Co [Member] \| Fixed Income Funds [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				(27,300,000)		(28,500,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Loss, before Tax		(20,400,000)		(20,400,000)		(22,600,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		10,700,000		10,700,000		12,600,000
Indiana Michigan Power Co [Member] \| Domestic [Member]
Nuclear Trust Fund Investments
Fair Value	[4]	2,360,600,000		2,360,600,000		2,131,300,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[4]	2,360,600,000		2,360,600,000		2,131,300,000
Indiana Michigan Power Co [Member] \| Domestic [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				0		0
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Loss, before Tax		(4,600,000)		(4,600,000)		(6,400,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		1,725,700,000		1,725,700,000		1,483,700,000
Indiana Michigan Power Co [Member] \| Cash and Cash Equivalents [Member]
Nuclear Trust Fund Investments
Fair Value	[5]	24,200,000		24,200,000		21,200,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[5]	24,200,000		24,200,000		21,200,000
Indiana Michigan Power Co [Member] \| Cash and Cash Equivalents [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				0		0
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Loss, before Tax		0		0		0
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		0		0		0
Indiana Michigan Power Co [Member] \| US Government Agencies Debt Securities [Member]
Nuclear Trust Fund Investments
Fair Value		1,191,900,000		1,191,900,000		1,123,800,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,191,900,000		1,191,900,000		1,123,800,000
Indiana Michigan Power Co [Member] \| US Government Agencies Debt Securities [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				(25,600,000)		(18,800,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Loss, before Tax		(13,800,000)		(13,800,000)		(14,900,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		9,900,000		9,900,000		11,800,000
Indiana Michigan Power Co [Member] \| Corporate Debt [Member]
Nuclear Trust Fund Investments
Fair Value		68,800,000		68,800,000		61,600,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		68,800,000		68,800,000		61,600,000
Indiana Michigan Power Co [Member] \| Corporate Debt [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				(1,700,000)		(9,600,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Loss, before Tax		(6,600,000)		(6,600,000)		(7,700,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		800,000		800,000		700,000
Indiana Michigan Power Co [Member] \| State and Local Jurisdiction [Member]
Nuclear Trust Fund Investments
Fair Value		3,300,000		3,300,000		3,300,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		3,300,000		3,300,000		3,300,000
Indiana Michigan Power Co [Member] \| State and Local Jurisdiction [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				0		(100,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Loss, before Tax		0		0		0
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		0		0		100,000
Ohio Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		3,365,600,000		3,365,600,000		2,970,300,000
Long Term Debt, Fair Value		2,878,800,000		2,878,800,000		2,516,600,000
Public Service Co Of Oklahoma [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		2,383,900,000		2,383,900,000		1,912,800,000
Long Term Debt, Fair Value		2,106,100,000		2,106,100,000		1,635,800,000
Southwestern Electric Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		3,645,600,000		3,645,600,000		3,391,600,000
Long Term Debt, Fair Value		3,135,300,000		3,135,300,000		2,870,900,000
Equity Units [Member]
Book Values and Fair Values of Long - term Debt
Long Term Debt, Fair Value		$ 844,000,000		$ 844,000,000		$ 877,000,000

[1]The fair value amounts include debt related to AEP’s Equity Units and had a fair value of $844 million and $877 million as of June 30, 2023 and December 31, 2022, respectively. See “Equity Units” section of Note 12 for additional information.[2]Primarily represents amounts held for the repayment of debt.[3]Primarily short and intermediate maturities which may be sold and do not contain maturity dates.[4]Amounts represent publicly traded equity securities and equity-based mutual funds.[5]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 ($)		3 Months Ended			6 Months Ended
Fair Value Assets and Liabilities (Details) - USD ($)		Jun. 30, 2023		Jun. 30, 2022	Jun. 30, 2023		Jun. 30, 2022	Dec. 31, 2022
Other [Member]
Risk Management Assets		$ (774,100,000)			$ (774,100,000)			$ (1,264,300,000)
Risk Management Liabilities		(736,600,000)			(736,600,000)			(784,700,000)
Assets, Fair Value Disclosure
Other Short-term Investments		15,900,000			15,900,000			9,000,000
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		10,900,000			10,900,000			9,900,000
Total Assets		(747,300,000)			(747,300,000)			(1,245,400,000)
Risk Management Assets
Risk Management Assets		(774,100,000)			(774,100,000)			(1,264,300,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities		(736,600,000)			(736,600,000)			(784,700,000)
Risk Management Assets		546,300,000			546,300,000			632,900,000
Risk Management Liabilities		451,500,000			451,500,000			490,400,000
Other Short-term Investments		248,300,000			248,300,000			234,700,000
Spent Nuclear Fuel and Decommissioning Trusts		3,648,800,000			3,648,800,000			3,341,200,000
Total Assets		4,443,400,000			4,443,400,000			4,208,800,000
Risk Management Assets		546,300,000			546,300,000			632,900,000
Risk Management Liabilities		451,500,000			451,500,000			490,400,000
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		45,100,000		$ 82,800,000	160,400,000		$ 103,100,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	(86,800,000)		38,600,000	(97,500,000)		68,100,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	(15,800,000)		(16,800,000)	(3,000,000)		(35,700,000)
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	4,700,000		5,700,000	(15,000,000)		22,500,000
Settlements		62,300,000		(69,300,000)	(23,000,000)		(149,000,000)
Transfers into Level 3	[4],[5]			2,400,000	(6,100,000)		4,400,000
Transfers out of Level 3	[5]	(3,100,000)		5,800,000	(1,300,000)		9,600,000
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	119,700,000		234,700,000	111,600,000		260,900,000
Ending Balance		126,100,000		283,900,000	126,100,000		283,900,000
Fair Value Measurements 1 (Textuals)
Assets Held for Sale		1,382,800,000			1,382,800,000			0
Liabilities Held for Sale		64,800,000			64,800,000			0
Total Long-term Debt Outstanding		40,142,300,000			40,142,300,000			36,801,000,000
Level 1 [Member]
Risk Management Assets		12,500,000			12,500,000			15,000,000
Risk Management Liabilities		26,500,000			26,500,000			21,800,000
Assets, Fair Value Disclosure
Other Short-term Investments		232,400,000			232,400,000			225,700,000
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		2,373,900,000			2,373,900,000			2,142,600,000
Total Assets		2,618,800,000			2,618,800,000			2,383,300,000
Risk Management Assets
Risk Management Assets		12,500,000			12,500,000			15,000,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		26,500,000			26,500,000			21,800,000
Level 2 [Member]
Risk Management Assets		1,012,000,000			1,012,000,000			1,541,100,000
Risk Management Liabilities		991,800,000			991,800,000			1,072,600,000
Assets, Fair Value Disclosure
Other Short-term Investments		0			0			0
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,264,000,000			1,264,000,000			1,188,700,000
Total Assets		2,276,000,000			2,276,000,000			2,729,800,000
Risk Management Assets
Risk Management Assets		1,012,000,000			1,012,000,000			1,541,100,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		991,800,000			991,800,000			1,072,600,000
Level 3 [Member]
Risk Management Assets		295,900,000			295,900,000			341,100,000
Risk Management Liabilities		169,800,000			169,800,000			180,700,000
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		295,900,000			295,900,000			341,100,000
Risk Management Assets
Risk Management Assets		295,900,000			295,900,000			341,100,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		169,800,000			169,800,000			180,700,000
2023 [Member] \| Level 1 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		(6,000,000)			(6,000,000)			(7,000,000)
2023 [Member] \| Level 2 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		(27,000,000)			(27,000,000)			182,000,000
2023 [Member] \| Level 3 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		63,000,000			63,000,000			128,000,000
2024 - 2026 [Member] \| Level 1 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		(8,000,000)			(8,000,000)
2024 - 2026 [Member] \| Level 2 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		59,000,000			59,000,000			134,000,000
2024 - 2026 [Member] \| Level 3 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		56,000,000			56,000,000			6,000,000
2027 - 2028 [Member] \| Level 2 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		12,000,000			12,000,000			10,000,000
2027 - 2028 [Member] \| Level 3 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		1,000,000			1,000,000			6,000,000
2029 - 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		2,000,000			2,000,000			1,000,000
2029 - 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		(14,000,000)			(14,000,000)			(5,000,000)
Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets	[7]	(756,900,000)	[8]		(756,900,000)	[8]		(1,211,500,000)	[9]
Risk Management Liabilities	[7]	(719,400,000)	[8]		(719,400,000)	[8]		(731,900,000)	[9]
Risk Management Assets
Risk Management Assets	[7]	(756,900,000)	[8]		(756,900,000)	[8]		(1,211,500,000)	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	(719,400,000)	[8]		(719,400,000)	[8]		(731,900,000)	[9]
Risk Management Commodity Contracts [Member]
Risk Management Assets	[7]	425,700,000	[8]		425,700,000	[8]		315,400,000	[9]
Risk Management Liabilities	[7]	325,200,000	[8]		325,200,000	[8]		339,800,000	[9]
Risk Management Assets
Risk Management Assets	[7]	425,700,000	[8]		425,700,000	[8]		315,400,000	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	325,200,000	[8]		325,200,000	[8]		339,800,000	[9]
Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets	[7]	12,500,000	[8]		12,500,000	[8]		15,000,000	[9]
Risk Management Liabilities	[7]	26,500,000	[8]		26,500,000	[8]		21,800,000	[9]
Risk Management Assets
Risk Management Assets	[7]	12,500,000	[8]		12,500,000	[8]		15,000,000	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	26,500,000	[8]		26,500,000	[8]		21,800,000	[9]
Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets	[7]	893,600,000	[8]		893,600,000	[8]		1,197,500,000	[9]
Risk Management Liabilities	[7]	848,300,000	[8]		848,300,000	[8]		870,900,000	[9]
Risk Management Assets
Risk Management Assets	[7]	893,600,000	[8]		893,600,000	[8]		1,197,500,000	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	848,300,000	[8]		848,300,000	[8]		870,900,000	[9]
Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets	[7]	276,500,000	[8]		276,500,000	[8]		314,400,000	[9]
Risk Management Liabilities	[7]	169,800,000	[8]		169,800,000	[8]		179,000,000	[9]
Risk Management Assets
Risk Management Assets	[7]	276,500,000	[8]		276,500,000	[8]		314,400,000	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	169,800,000	[8]		169,800,000	[8]		179,000,000	[9]
Energy Contracts [Member] \| Level 3 [Member]
Risk Management Assets		158,400,000			158,400,000			204,000,000
Risk Management Liabilities		158,100,000			158,100,000			167,400,000
Risk Management Assets
Risk Management Assets		158,400,000			158,400,000			204,000,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		158,100,000			158,100,000			167,400,000
Energy Contracts [Member] \| Weighted Average [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	44.95			44.95			49.14
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	44.95			44.95			49.14
Energy Contracts [Member] \| Low [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	1.89			1.89			2.91
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	1.89			1.89			2.91
Energy Contracts [Member] \| High [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	90.40			90.40			187.34
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	90.40			90.40			187.34
Natural Gas Contracts [Member] \| Level 3 [Member]
Risk Management Assets		200,000			200,000
Risk Management Liabilities		200,000			200,000
Risk Management Assets
Risk Management Assets		200,000			200,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		200,000			200,000
Natural Gas Contracts [Member] \| Weighted Average [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[11],[12]	3.21			3.21
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[11],[12]	3.21			3.21
Natural Gas Contracts [Member] \| Low [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[12]	2.14			2.14
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[12]	2.14			2.14
Natural Gas Contracts [Member] \| High [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[12]	4.21			4.21
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[12]	4.21			4.21
FTRs [Member] \| Level 3 [Member]
Risk Management Assets		137,300,000			137,300,000			137,100,000
Risk Management Liabilities		11,500,000			11,500,000			13,300,000
Risk Management Assets
Risk Management Assets		137,300,000			137,300,000			137,100,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		11,500,000			11,500,000			13,300,000
FTRs [Member] \| Weighted Average [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	(0.20)			(0.20)			1.18
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	(0.20)			(0.20)			1.18
FTRs [Member] \| Low [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	(17.92)			(17.92)			(36.45)
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	(17.92)			(17.92)			(36.45)
FTRs [Member] \| High [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	11.35			11.35			20.72
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	11.35			11.35			20.72
Commodity Hedges [Member] \| Other [Member]
Risk Management Assets	[7]	(17,200,000)			(17,200,000)			(52,800,000)
Risk Management Liabilities	[7]	(17,200,000)			(17,200,000)			(52,800,000)
Risk Management Assets
Risk Management Assets	[7]	(17,200,000)			(17,200,000)			(52,800,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	(17,200,000)			(17,200,000)			(52,800,000)
Commodity Hedges [Member]
Risk Management Assets	[7]	120,600,000			120,600,000			306,500,000
Risk Management Liabilities	[7]	1,600,000			1,600,000			23,200,000
Risk Management Assets
Risk Management Assets	[7]	120,600,000			120,600,000			306,500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	1,600,000			1,600,000			23,200,000
Commodity Hedges [Member] \| Level 1 [Member]
Risk Management Assets	[7]	0			0			0
Risk Management Liabilities	[7]	0			0			0
Risk Management Assets
Risk Management Assets	[7]	0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	0			0			0
Commodity Hedges [Member] \| Level 2 [Member]
Risk Management Assets	[7]	118,400,000			118,400,000			332,600,000
Risk Management Liabilities	[7]	18,800,000			18,800,000			74,300,000
Risk Management Assets
Risk Management Assets	[7]	118,400,000			118,400,000			332,600,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	18,800,000			18,800,000			74,300,000
Commodity Hedges [Member] \| Level 3 [Member]
Risk Management Assets	[7]	19,400,000			19,400,000			26,700,000
Risk Management Liabilities	[7]	0			0			1,700,000
Risk Management Assets
Risk Management Assets	[7]	19,400,000			19,400,000			26,700,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	0			0			1,700,000
Interest Rate [Member] \| Other [Member]
Risk Management Assets								0
Risk Management Assets
Risk Management Assets								0
Interest Rate [Member]
Risk Management Assets								11,000,000
Risk Management Assets
Risk Management Assets								11,000,000
Interest Rate [Member] \| Level 1 [Member]
Risk Management Assets								0
Risk Management Assets
Risk Management Assets								0
Interest Rate [Member] \| Level 2 [Member]
Risk Management Assets								11,000,000
Risk Management Assets
Risk Management Assets								11,000,000
Interest Rate [Member] \| Level 3 [Member]
Risk Management Assets								0
Risk Management Assets
Risk Management Assets								0
Fair Value Hedges [Member] \| Other [Member]
Risk Management Liabilities		0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0			0
Fair Value Hedges [Member]
Risk Management Liabilities		124,700,000			124,700,000			127,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		124,700,000			124,700,000			127,400,000
Fair Value Hedges [Member] \| Level 1 [Member]
Risk Management Liabilities		0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0			0
Fair Value Hedges [Member] \| Level 2 [Member]
Risk Management Liabilities		124,700,000			124,700,000			127,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		124,700,000			124,700,000			127,400,000
Fair Value Hedges [Member] \| Level 3 [Member]
Risk Management Liabilities		0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0			0
AEP Texas Inc. [Member] \| Other [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0			0
AEP Texas Inc. [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		30,700,000			30,700,000			32,700,000
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		5,937,500,000			5,937,500,000			5,657,800,000
AEP Texas Inc. [Member] \| Level 1 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		30,700,000			30,700,000			32,700,000
AEP Texas Inc. [Member] \| Level 2 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0			0
AEP Texas Inc. [Member] \| Level 3 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0			0
AEP Texas Inc. [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Liabilities	[7]	(500,000)			(500,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	(500,000)			(500,000)
AEP Texas Inc. [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Liabilities	[7]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	0			0
AEP Texas Inc. [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Liabilities	[7]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	0			0
AEP Texas Inc. [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Liabilities	[7]	500,000			500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	500,000			500,000
AEP Texas Inc. [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Liabilities	[7]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	0			0
AEP Transmission Co [Member]
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		5,473,000,000			5,473,000,000			4,782,800,000
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		(3,300,000)			(3,300,000)			(1,000,000)
Appalachian Power Co [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		15,100,000			15,100,000			14,400,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		54,500,000			54,500,000			83,500,000
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		5,700,000		6,600,000	69,100,000		41,700,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	(11,900,000)		5,700,000	(47,900,000)		3,000,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	0		0	0		0
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	0		0	0		0
Settlements		6,200,000		(12,400,000)	(21,100,000)		(44,700,000)
Transfers into Level 3	[4],[5]			0	0		0
Transfers out of Level 3	[5]	0		0	0		0
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	39,400,000		79,700,000	39,300,000		79,600,000
Ending Balance		39,400,000		79,600,000	39,400,000		79,600,000
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		5,599,700,000			5,599,700,000			5,410,500,000
Appalachian Power Co [Member] \| Level 1 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		15,100,000			15,100,000			14,400,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		15,100,000			15,100,000			14,400,000
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		1,600,000			1,600,000			700,000
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		41,100,000			41,100,000			69,400,000
Appalachian Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets	[7],[13]	(3,300,000)			(3,300,000)			(1,000,000)
Risk Management Liabilities	[7],[13]	(4,000,000)			(4,000,000)			(1,400,000)
Risk Management Assets
Risk Management Assets	[7],[13]	(3,300,000)			(3,300,000)			(1,000,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[13]	(4,000,000)			(4,000,000)			(1,400,000)
Appalachian Power Co [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Assets	[7],[13]	39,400,000			39,400,000			69,100,000
Risk Management Liabilities	[7],[13]	1,100,000			1,100,000			3,500,000
Risk Management Assets
Risk Management Assets	[7],[13]	39,400,000			39,400,000			69,100,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[13]	1,100,000			1,100,000			3,500,000
Appalachian Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets	[7],[13]	0			0			0
Risk Management Liabilities	[7],[13]	0			0			0
Risk Management Assets
Risk Management Assets	[7],[13]	0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[13]	0			0			0
Appalachian Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets	[7],[13]	1,600,000			1,600,000			700,000
Risk Management Liabilities	[7],[13]	3,400,000			3,400,000			4,600,000
Risk Management Assets
Risk Management Assets	[7],[13]	1,600,000			1,600,000			700,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[13]	3,400,000			3,400,000			4,600,000
Appalachian Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets	[7],[13]	41,100,000			41,100,000			69,400,000
Risk Management Liabilities	[7],[13]	1,700,000			1,700,000			300,000
Risk Management Assets
Risk Management Assets	[7],[13]	41,100,000			41,100,000			69,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[13]	1,700,000			1,700,000			300,000
Appalachian Power Co [Member] \| Natural Gas Contracts [Member] \| Level 3 [Member]
Risk Management Assets		200,000			200,000
Risk Management Liabilities		0			0
Risk Management Assets
Risk Management Assets		200,000			200,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0
Appalachian Power Co [Member] \| Natural Gas Contracts [Member] \| Weighted Average [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[11],[12]	3.35			3.35
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[11],[12]	3.35			3.35
Appalachian Power Co [Member] \| Natural Gas Contracts [Member] \| Low [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[12]	2.91			2.91
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[12]	2.91			2.91
Appalachian Power Co [Member] \| Natural Gas Contracts [Member] \| High [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[12]	4.19			4.19
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[12]	4.19			4.19
Appalachian Power Co [Member] \| FTRs [Member] \| Level 3 [Member]
Risk Management Assets		40,900,000			40,900,000			69,400,000
Risk Management Liabilities		1,700,000			1,700,000			300,000
Risk Management Assets
Risk Management Assets		40,900,000			40,900,000			69,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		1,700,000			1,700,000			300,000
Appalachian Power Co [Member] \| FTRs [Member] \| Weighted Average [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	1.37			1.37			3.89
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	1.37			1.37			3.89
Appalachian Power Co [Member] \| FTRs [Member] \| Low [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	(3.60)			(3.60)			(2.82)
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	(3.60)			(3.60)			(2.82)
Appalachian Power Co [Member] \| FTRs [Member] \| High [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	9.53			9.53			18.88
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	9.53			9.53			18.88
Indiana Michigan Power Co [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		10,900,000			10,900,000			9,900,000
Total Assets		7,600,000			7,600,000			8,700,000
Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		3,648,800,000			3,648,800,000			3,341,200,000
Total Assets		3,679,300,000			3,679,300,000			3,356,600,000
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		1,100,000		1,000,000	4,600,000		(700,000)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	(3,200,000)		(300,000)	(2,300,000)		3,700,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	0		0	0		0
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	0		0	0		0
Settlements		2,000,000		(700,000)	(2,200,000)		(3,000,000)
Transfers into Level 3	[4],[5]			0	0		0
Transfers out of Level 3	[5]	0		0	0		0
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	6,900,000		9,800,000	6,700,000		9,800,000
Ending Balance		6,800,000		9,800,000	6,800,000		9,800,000
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		3,464,100,000			3,464,100,000			3,260,800,000
Indiana Michigan Power Co [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		2,373,900,000			2,373,900,000			2,142,600,000
Total Assets		2,373,900,000			2,373,900,000			2,142,600,000
Indiana Michigan Power Co [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,264,000,000			1,264,000,000			1,188,700,000
Total Assets		1,289,600,000			1,289,600,000			1,200,000,000
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		8,200,000			8,200,000			5,300,000
Indiana Michigan Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets	[7],[13]	(3,300,000)			(3,300,000)			(1,200,000)
Risk Management Liabilities	[7],[13]	(3,800,000)			(3,800,000)			(1,300,000)
Risk Management Assets
Risk Management Assets	[7],[13]	(3,300,000)			(3,300,000)			(1,200,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[13]	(3,800,000)			(3,800,000)			(1,300,000)
Indiana Michigan Power Co [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Assets	[7],[13]	30,500,000			30,500,000			15,400,000
Risk Management Liabilities	[7],[13]	1,400,000			1,400,000			0
Risk Management Assets
Risk Management Assets	[7],[13]	30,500,000			30,500,000			15,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[13]	1,400,000			1,400,000			0
Indiana Michigan Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets	[7],[13]	0			0			0
Risk Management Liabilities	[7],[13]	0			0			0
Risk Management Assets
Risk Management Assets	[7],[13]	0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[13]	0			0			0
Indiana Michigan Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets	[7],[13]	25,600,000			25,600,000			11,300,000
Risk Management Liabilities	[7],[13]	3,800,000			3,800,000			600,000
Risk Management Assets
Risk Management Assets	[7],[13]	25,600,000			25,600,000			11,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[13]	3,800,000			3,800,000			600,000
Indiana Michigan Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets	[7],[13]	8,200,000			8,200,000			5,300,000
Risk Management Liabilities	[7],[13]	1,400,000			1,400,000			700,000
Risk Management Assets
Risk Management Assets	[7],[13]	8,200,000			8,200,000			5,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[13]	1,400,000			1,400,000			700,000
Indiana Michigan Power Co [Member] \| FTRs [Member] \| Level 3 [Member]
Risk Management Assets		8,200,000			8,200,000			5,300,000
Risk Management Liabilities		1,400,000			1,400,000			700,000
Risk Management Assets
Risk Management Assets		8,200,000			8,200,000			5,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		1,400,000			1,400,000			700,000
Indiana Michigan Power Co [Member] \| FTRs [Member] \| Weighted Average [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	1.07			1.07			1.23
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	1.07			1.07			1.23
Indiana Michigan Power Co [Member] \| FTRs [Member] \| Low [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	(6.02)			(6.02)			0.16
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	(6.02)			(6.02)			0.16
Indiana Michigan Power Co [Member] \| FTRs [Member] \| High [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	9.11			9.11			18.79
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	9.11			9.11			18.79
Ohio Power Co [Member]
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		(46,900,000)		(68,500,000)	(40,000,000)		(92,500,000)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	(1,400,000)		900,000	(1,700,000)		2,400,000
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		1,300,000		0	2,400,000		1,400,000
Transfers into Level 3	[4],[5]			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)		19,200,000	(14,700,000)		40,300,000
Ending Balance		(54,000,000)		(48,400,000)	(54,000,000)		(48,400,000)
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		3,365,600,000			3,365,600,000			2,970,300,000
Ohio Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Liabilities	[7],[13]	(400,000)			(400,000)			(300,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[13]	(400,000)			(400,000)			(300,000)
Ohio Power Co [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Liabilities	[13]	54,000,000			54,000,000			39,700,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[13]	54,000,000			54,000,000			39,700,000
Ohio Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Liabilities	[13]	0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[13]	0			0			0
Ohio Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Liabilities	[13]	400,000			400,000			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[13]	400,000			400,000			0
Ohio Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Liabilities	[13]	54,000,000			54,000,000			40,000,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[13]	54,000,000			54,000,000			40,000,000
Ohio Power Co [Member] \| Energy Contracts [Member] \| Level 3 [Member]
Risk Management Assets		0			0			0
Risk Management Liabilities		54,000,000			54,000,000			40,000,000
Risk Management Assets
Risk Management Assets		0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		54,000,000			54,000,000			40,000,000
Ohio Power Co [Member] \| Energy Contracts [Member] \| Weighted Average [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	41.40			41.40			48.76
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	41.40			41.40			48.76
Ohio Power Co [Member] \| Energy Contracts [Member] \| Low [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	16.97			16.97			2.91
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	16.97			16.97			2.91
Ohio Power Co [Member] \| Energy Contracts [Member] \| High [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	71.80			71.80			187.34
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	71.80			71.80			187.34
Public Service Co Of Oklahoma [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets								(300,000)
Public Service Co Of Oklahoma [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets								25,300,000
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		9,300,000		6,500,000	23,700,000		12,100,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	(42,100,000)		11,900,000	(25,500,000)		24,200,000
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		32,800,000		(18,400,000)	1,800,000		(36,300,000)
Transfers into Level 3	[4],[5]			0	0		0
Transfers out of Level 3	[5]	0		0	0		0
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	43,100,000		64,500,000	43,100,000		64,500,000
Ending Balance		43,100,000		64,500,000	43,100,000		64,500,000
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		2,383,900,000			2,383,900,000			1,912,800,000
Public Service Co Of Oklahoma [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets								0
Public Service Co Of Oklahoma [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets								1,600,000
Public Service Co Of Oklahoma [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets								24,000,000
Public Service Co Of Oklahoma [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets	[7],[13]	(2,800,000)			(2,800,000)			1,300,000
Risk Management Liabilities	[7],[13]	(3,000,000)			(3,000,000)			(400,000)
Risk Management Assets
Risk Management Assets	[7],[13]	(2,800,000)			(2,800,000)			1,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[13]	(3,000,000)			(3,000,000)			(400,000)
Public Service Co Of Oklahoma [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Assets	[7],[13]	44,800,000			44,800,000			25,300,000
Risk Management Liabilities	[7],[13]	3,400,000			3,400,000			1,600,000
Risk Management Assets
Risk Management Assets	[7],[13]	44,800,000			44,800,000			25,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[13]	3,400,000			3,400,000			1,600,000
Public Service Co Of Oklahoma [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets	[7],[13]	0			0			0
Risk Management Liabilities	[7],[13]	0			0			0
Risk Management Assets
Risk Management Assets	[7],[13]	0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[13]	0			0			0
Public Service Co Of Oklahoma [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets	[7],[13]	2,900,000			2,900,000			0
Risk Management Liabilities	[7],[13]	4,800,000			4,800,000			1,700,000
Risk Management Assets
Risk Management Assets	[7],[13]	2,900,000			2,900,000			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[13]	4,800,000			4,800,000			1,700,000
Public Service Co Of Oklahoma [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets	[7],[13]	44,700,000			44,700,000			24,000,000
Risk Management Liabilities	[7],[13]	1,600,000			1,600,000			300,000
Risk Management Assets
Risk Management Assets	[7],[13]	44,700,000			44,700,000			24,000,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[13]	1,600,000			1,600,000			300,000
Public Service Co Of Oklahoma [Member] \| FTRs [Member] \| Level 3 [Member]
Risk Management Assets		44,700,000			44,700,000			24,000,000
Risk Management Liabilities		1,600,000			1,600,000			300,000
Risk Management Assets
Risk Management Assets		44,700,000			44,700,000			24,000,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		1,600,000			1,600,000			300,000
Public Service Co Of Oklahoma [Member] \| FTRs [Member] \| Weighted Average [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[11]	(4.44)			(4.44)			(7.55)	[10]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[11]	(4.44)			(4.44)			(7.55)	[10]
Public Service Co Of Oklahoma [Member] \| FTRs [Member] \| Low [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit		(17.92)			(17.92)			(36.45)	[10]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit		(17.92)			(17.92)			(36.45)	[10]
Public Service Co Of Oklahoma [Member] \| FTRs [Member] \| High [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit		0.87			0.87			3.40	[10]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit		0.87			0.87			3.40	[10]
Public Service Co Of Oklahoma [Member] \| Interest Rate [Member] \| Other [Member]
Risk Management Assets								(1,600,000)
Risk Management Assets
Risk Management Assets								(1,600,000)
Public Service Co Of Oklahoma [Member] \| Interest Rate [Member]
Risk Management Assets								0
Risk Management Assets
Risk Management Assets								0
Public Service Co Of Oklahoma [Member] \| Interest Rate [Member] \| Level 1 [Member]
Risk Management Assets								0
Risk Management Assets
Risk Management Assets								0
Public Service Co Of Oklahoma [Member] \| Interest Rate [Member] \| Level 2 [Member]
Risk Management Assets								1,600,000
Risk Management Assets
Risk Management Assets								1,600,000
Public Service Co Of Oklahoma [Member] \| Interest Rate [Member] \| Level 3 [Member]
Risk Management Assets								0
Risk Management Assets
Risk Management Assets								0
Southwestern Electric Power Co [Member]
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		5,800,000		15,700,000	14,200,000		10,900,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	(32,800,000)		19,900,000	(20,300,000)		32,500,000
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		27,000,000		(27,900,000)	6,100,000		(41,000,000)
Transfers into Level 3	[4],[5]			0	0		0
Transfers out of Level 3	[5]	0		0	0		0
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	26,000,000		37,700,000	26,000,000		43,000,000
Ending Balance		26,000,000		$ 45,400,000	26,000,000		$ 45,400,000
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		3,645,600,000			3,645,600,000			3,391,600,000
Southwestern Electric Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets	[7],[13]	(500,000)			(500,000)			(400,000)
Risk Management Liabilities	[7],[13]	(800,000)			(800,000)			(600,000)
Risk Management Assets
Risk Management Assets	[7],[13]	(500,000)			(500,000)			(400,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[13]	(800,000)			(800,000)			(600,000)
Southwestern Electric Power Co [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Assets	[7],[13]	28,000,000			28,000,000			16,400,000
Risk Management Liabilities	[7],[13]	1,800,000			1,800,000			1,400,000
Risk Management Assets
Risk Management Assets	[7],[13]	28,000,000			28,000,000			16,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[13]	1,800,000			1,800,000			1,400,000
Southwestern Electric Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets	[7],[13]	0			0			0
Risk Management Liabilities	[7],[13]	0			0			0
Risk Management Assets
Risk Management Assets	[7],[13]	0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[13]	0			0			0
Southwestern Electric Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets	[7],[13]	400,000			400,000			2,200,000
Risk Management Liabilities	[7],[13]	500,000			500,000			1,600,000
Risk Management Assets
Risk Management Assets	[7],[13]	400,000			400,000			2,200,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[13]	500,000			500,000			1,600,000
Southwestern Electric Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets	[7],[13]	28,100,000			28,100,000			14,600,000
Risk Management Liabilities	[7],[13]	2,100,000			2,100,000			400,000
Risk Management Assets
Risk Management Assets	[7],[13]	28,100,000			28,100,000			14,600,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[13]	2,100,000			2,100,000			400,000
Southwestern Electric Power Co [Member] \| Natural Gas Contracts [Member] \| Level 3 [Member]
Risk Management Assets		0			0
Risk Management Liabilities		200,000			200,000
Risk Management Assets
Risk Management Assets		0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		200,000			200,000
Southwestern Electric Power Co [Member] \| Natural Gas Contracts [Member] \| Weighted Average [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[11],[12]	3.35			3.35
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[11],[12]	3.35			3.35
Southwestern Electric Power Co [Member] \| Natural Gas Contracts [Member] \| Low [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[12]	2.91			2.91
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[12]	2.91			2.91
Southwestern Electric Power Co [Member] \| Natural Gas Contracts [Member] \| High [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[12]	4.19			4.19
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[12]	4.19			4.19
Southwestern Electric Power Co [Member] \| FTRs [Member] \| Level 3 [Member]
Risk Management Assets		28,100,000			28,100,000			14,600,000
Risk Management Liabilities		1,900,000			1,900,000			400,000
Risk Management Assets
Risk Management Assets		28,100,000			28,100,000			14,600,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		1,900,000			1,900,000			400,000
Southwestern Electric Power Co [Member] \| FTRs [Member] \| Weighted Average [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	(4.44)			(4.44)			(7.55)
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	(4.44)			(4.44)			(7.55)
Southwestern Electric Power Co [Member] \| FTRs [Member] \| Low [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	(17.92)			(17.92)			(36.45)
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	(17.92)			(17.92)			(36.45)
Southwestern Electric Power Co [Member] \| FTRs [Member] \| High [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	0.87			0.87			3.40
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	0.87			0.87			3.40
Cash [Member] \| Other [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0			0
Cash [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		45,800,000			45,800,000			47,100,000
Other Short-term Investments	[14]	45,800,000			45,800,000			47,100,000
Cash [Member] \| Level 1 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		45,800,000			45,800,000			47,100,000
Cash [Member] \| Level 2 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0			0
Cash [Member] \| Level 3 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0			0
Other Cash Deposits [Member] \| Other [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[15]	15,900,000			15,900,000			9,000,000
Other Cash Deposits [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		15,900,000			15,900,000			9,000,000
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	[16]	146,800,000			146,800,000			144,100,000
Mutual Funds Fixed Income [Member] \| Level 1 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		146,800,000			146,800,000			144,100,000
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	[17]	0			0			0
Mutual Funds Equity [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[17]	39,800,000			39,800,000			34,500,000
Mutual Funds Equity [Member] \| Level 1 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[17]	39,800,000			39,800,000			34,500,000
Mutual Funds Equity [Member] \| Level 2 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[17]	0			0			0
Mutual Funds Equity [Member] \| Level 3 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[17]	0			0			0
Cash and Cash Equivalents [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[18]	10,900,000			10,900,000			9,900,000
Cash and Cash Equivalents [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[18]	24,200,000			24,200,000			21,200,000
Cash and Cash Equivalents [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[18]	13,300,000			13,300,000			11,300,000
Cash and Cash Equivalents [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[18]	0			0			0
Cash and Cash Equivalents [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[18]	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	[18]	10,900,000			10,900,000			9,900,000
Cash and Cash Equivalents [Member] \| Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[18]	24,200,000			24,200,000			21,200,000
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	[18]	13,300,000			13,300,000			11,300,000
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	[18]	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	[18]	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		1,191,900,000			1,191,900,000			1,123,800,000
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		1,191,900,000			1,191,900,000			1,123,800,000
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		1,191,900,000			1,191,900,000			1,123,800,000
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		1,191,900,000			1,191,900,000			1,123,800,000
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		68,800,000			68,800,000			61,600,000
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		68,800,000			68,800,000			61,600,000
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		68,800,000			68,800,000			61,600,000
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		68,800,000			68,800,000			61,600,000
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		3,300,000			3,300,000			3,300,000
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		3,300,000			3,300,000			3,300,000
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		3,300,000			3,300,000			3,300,000
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		3,300,000			3,300,000			3,300,000
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		1,264,000,000			1,264,000,000			1,188,700,000
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		1,264,000,000			1,264,000,000			1,188,700,000
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		1,264,000,000			1,264,000,000			1,188,700,000
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		1,264,000,000			1,264,000,000			1,188,700,000
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	[17]	0			0			0
Domestic [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[17]	2,360,600,000			2,360,600,000			2,131,300,000
Domestic [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[17]	2,360,600,000			2,360,600,000			2,131,300,000
Domestic [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[17]	0			0			0
Domestic [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[17]	0			0			0
Domestic [Member] \| Indiana Michigan Power Co [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[17]	0			0			0
Domestic [Member] \| Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[17]	2,360,600,000			2,360,600,000			2,131,300,000
Domestic [Member] \| Indiana Michigan Power Co [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[17]	2,360,600,000			2,360,600,000			2,131,300,000
Domestic [Member] \| Indiana Michigan Power Co [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[17]	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	[17]	$ 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]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.’’[8]The June 30, 2023 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $(6) million in 2023 and $(8) million in periods 2024-2026; Level 2 matures $(27) million in 2023, $59 million in periods 2024-2026, $12 million in periods 2027-2028 and $2 million in periods 2029-2033; Level 3 matures $63 million in 2023, $56 million in periods 2024-2026, $1 million in periods 2027-2028 and $(14) million in periods 2029-2033. Risk management commodity contracts are substantially comprised of power contracts.[9]The December 31, 2022 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $(7) million in 2023; Level 2 matures $182 million in 2023, $134 million in periods 2024-2026, $10 million in periods 2027-2028 and $1 million in periods 2029-2033; Level 3 matures $128 million in 2023, $6 million in periods 2024-2026, $6 million in periods 2027-2028 and $(5) million in periods 2029-2033. Risk management commodity contracts are substantially comprised of power contracts.[10]Represents market prices in dollars per MWh.[11]The weighted average is the product of the forward market price of the underlying commodity and volume weighted by term.[12]Represents market prices in dollars per MMBtu.[13]Substantially comprised of power contracts for the Registrant Subsidiaries.[14]Primarily represents amounts held for the repayment of debt.[15]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.[16]Primarily short and intermediate maturities which may be sold and do not contain maturity dates.[17]Amounts represent publicly traded equity securities and equity-based mutual funds.[18]Amounts in “Other’’ column primarily represent accrued interest receivables from financial institutions. Level 1 amounts primarily represent investments in money market funds.

Income Taxes (Details)

Income Taxes (Details)	3 Months Ended		6 Months Ended
Income Taxes (Details)	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21%	21%	21%	21%
State Income Tax, net of Federal Benefit	2.10%	1.30%	2%	1.40%
Tax Reform Excess ADIT Reversal	(6.20%)	(7.10%)	(6.20%)	(6.80%)
Production and Investment Tax Credits	(9.90%)	(6.10%)	(9.80%)	(7.10%)
Flow Through	(1.00%)	(0.10%)	(0.50%)	0.10%
AFUDC Equity	(1.20%)	(1.10%)	(1.30%)	(1.00%)
Discrete Tax Adjustments		0.30%	(1.40%)	(0.20%)
Other	0.40%	1.10%	0.30%	0.50%
Effective Income Tax Rate	5.20%	9.30%	4.10%	7.90%
Income Taxes (Textuals) [Abstract]
corporate alternative minimum tax			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	0.60%	0.70%	0.50%	0.50%
Tax Reform Excess ADIT Reversal	(1.30%)	(2.10%)	(1.40%)	(2.00%)
Production and Investment Tax Credits	(0.20%)	(0.60%)	(0.20%)	(0.40%)
Flow Through	0.10%	0.20%	0.20%	0.20%
AFUDC Equity	(0.90%)	(1.40%)	(1.10%)	(1.10%)
Discrete Tax Adjustments		0%	0%	0%
Other	0.30%	0.10%	0.20%	(0.10%)
Effective Income Tax Rate	19.60%	17.90%	19.20%	18.10%
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%	2.90%	2.60%	2.70%
Tax Reform Excess ADIT Reversal	0.10%	0.30%	0.20%	0.30%
Production and Investment Tax Credits	0%	0%	0%	0%
Flow Through	0.20%	0.40%	0.20%	0.30%
AFUDC Equity	(2.10%)	(2.30%)	(1.80%)	(1.90%)
Discrete Tax Adjustments		0%	0%	0%
Other	0%	0.10%	0%	0.20%
Effective Income Tax Rate	21.80%	22.40%	22.20%	22.60%
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	3.20%	(1.00%)	2.60%	1.50%
Tax Reform Excess ADIT Reversal	(4.50%)	(20.40%)	(4.50%)	(11.00%)
Production and Investment Tax Credits	(0.10%)	0%	(0.10%)	0%
Flow Through	(5.10%)	(1.40%)	(0.80%)	0.60%
AFUDC Equity	(1.50%)	(1.50%)	(0.90%)	(1.00%)
Discrete Tax Adjustments		(6.00%)	2.40%	(2.60%)
Other	(0.40%)	(0.20%)	(0.10%)	0%
Effective Income Tax Rate	12.60%	(9.50%)	19.60%	8.50%
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	0.70%	(1.30%)	2.40%	0.40%
Tax Reform Excess ADIT Reversal	(6.10%)	(17.20%)	(7.20%)	(17.20%)
Production and Investment Tax Credits	0.10%	(3.40%)	(0.60%)	(2.30%)
Flow Through	(4.40%)	(1.20%)	(2.90%)	(1.60%)
AFUDC Equity	(0.10%)	(1.30%)	(0.30%)	(0.90%)
Discrete Tax Adjustments		0%	1%	0%
Other	0.10%	1.30%	0.10%	0.40%
Effective Income Tax Rate	11.30%	(2.10%)	13.50%	(0.20%)
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	0.80%	1%	0.90%	0.90%
Tax Reform Excess ADIT Reversal	(8.50%)	(7.80%)	(7.60%)	(7.80%)
Production and Investment Tax Credits	0%	0%	0%	0%
Flow Through	1.20%	0.20%	0.80%	0.60%
AFUDC Equity	(0.70%)	(0.70%)	(0.80%)	(0.60%)
Discrete Tax Adjustments		0%	0%	0%
Other	0.10%	0.10%	0.10%	(0.10%)
Effective Income Tax Rate	13.90%	13.80%	14.40%	14%
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	2%	3.90%	2%	3.50%
Tax Reform Excess ADIT Reversal	(17.20%)	(19.20%)	(17.10%)	(18.60%)
Production and Investment Tax Credits	(55.10%)	(32.20%)	(55.20%)	(31.40%)
Flow Through	0.30%	0.30%	0.30%	0.30%
AFUDC Equity	(1.40%)	(0.40%)	(1.40%)	(0.50%)
Discrete Tax Adjustments		0%	0%	0%
Other	0%	0.50%	0.10%	0.30%
Effective Income Tax Rate	(50.40%)	(26.10%)	(50.30%)	(25.40%)
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	(1.60%)	2.50%	(1.20%)	2.40%
Tax Reform Excess ADIT Reversal	(4.20%)	(5.20%)	(4.00%)	(5.10%)
Production and Investment Tax Credits	(29.20%)	(19.80%)	(28.20%)	(20.80%)
Flow Through	(0.80%)	0%	(0.30%)	(0.20%)
AFUDC Equity	0%	(0.50%)	(0.30%)	(0.50%)
Discrete Tax Adjustments		0.80%	0%	0.50%
Other	0.70%	(0.10%)	0.10%	0%
Effective Income Tax Rate	(14.10%)	(1.30%)	(12.90%)	(2.70%)

Financing Activities (Details)

Financing Activities (Details) - USD ($)			1 Months Ended	3 Months Ended						6 Months Ended
Financing Activities (Details) - USD ($)		Mar. 15, 2023	Jul. 27, 2023	Jun. 30, 2023		Mar. 31, 2023	Jun. 30, 2022		Mar. 31, 2022	Jun. 30, 2023		Jun. 30, 2022		Dec. 31, 2022
Long-term Debt
Senior Unsecured Notes				$ 33,491,500,000						$ 33,491,500,000				$ 30,174,800,000
Pollution Control Bonds				1,770,900,000						1,770,900,000				1,770,200,000
Notes Payable				165,800,000						165,800,000				269,700,000
Securitization Bonds				432,100,000						432,100,000				487,800,000
Spent Nuclear Fuel Obligation	[1]			292,300,000						292,300,000				285,600,000
Junior Subordinated Notes	[2]			2,385,000,000						2,385,000,000				2,381,300,000
Other Long-term Debt				1,604,700,000						1,604,700,000				1,431,600,000
Total Long-term Debt Outstanding				40,142,300,000						40,142,300,000				36,801,000,000
Long-term Debt Due Within One Year				3,380,300,000						3,380,300,000				2,486,400,000
Long-term Debt				36,762,000,000						36,762,000,000				34,314,600,000
Liabilities Held for Sale				64,800,000						64,800,000				0
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]									4,003,000,000
Repayments of Long-term Debt										641,700,000		$ 582,400,000
Short-term Debt:
Securitized Debt for Receivables	[4]			750,000,000						750,000,000				750,000,000
Commercial Paper				2,238,700,000						2,238,700,000				2,862,200,000
Total Short-term Debt				$ 3,867,600,000						$ 3,867,600,000				$ 4,112,200,000
Securitized Debt for Receivables	[4],[5]			5.45%						5.45%				4.67%
Comparative Accounts Receivable Information
Effective Interest Rates on Securitization of Accounts Receivable				5.25%			0.91%			5.06%		0.61%
Net Uncollectible Accounts Receivable Written Off				$ 7,300,000			$ 6,200,000			$ 14,100,000		$ 13,600,000
Customer Accounts Receivable Managed Portfolio
Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts				1,184,900,000						1,184,900,000				$ 1,167,700,000
Total Principal Outstanding				750,000,000						750,000,000				750,000,000
Delinquent Securitized Accounts Receivable				49,400,000						49,400,000				44,200,000
Bad Debt Reserves Related to Securitization, Sale of Accounts Receivable				41,700,000						41,700,000				39,700,000
Unbilled Receivables Related to Securitization, Sale of Accounts Receivable				392,400,000						392,400,000				360,900,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				4,372,500,000			4,639,700,000			9,063,400,000		9,232,300,000
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										$ 77,600,000		812,700,000
Trust Fund Assets One Time Fee Obligation for Nuclear Fuel Disposition														330,000,000
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,				(3,300,000)		$ 12,500,000	(18,800,000)		$ 16,700,000
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				1,382,800,000						1,382,800,000				$ 0
Issuance of Long-term Debt										3,958,800,000		2,639,100,000
Related Party
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0		0
Reconciling Adjustments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0		0
Reconciling Adjustments [Member] \| Related Party
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				(464,200,000)			(373,300,000)			(907,900,000)		(765,500,000)
Vertically Integrated Utilities [Member] \| Related Party
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				45,500,000			53,500,000			87,000,000		94,100,000
Transmission And Distribution Utilities [Member] \| Related Party
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				9,400,000			4,800,000			18,300,000		9,400,000
Generation And Marketing [Member] \| Related Party
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				13,200,000			5,200,000			13,300,000		15,000,000
Other Segments [Member] \| Related Party
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold	[6]			25,800,000			10,100,000			53,600,000		19,300,000
Wholesale Transmission [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				350,600,000	[7]		363,300,000	[8]		677,800,000	[9]	676,200,000	[10]
Wholesale Transmission [Member] \| Reconciling Adjustments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				(402,800,000)	[7]		(332,000,000)	[8]		(804,600,000)	[9]	(693,800,000)	[10]
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				455,800,000	[7]		421,600,000	[8]		905,900,000	[9]	836,100,000	[10]
Wholesale Transmission [Member] \| AEP Transmission Holdco [Member] \| Related Party
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				360,000,000			334,000,000			712,000,000		661,000,000
Wholesale Transmission [Member] \| Vertically Integrated Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				113,500,000	[7]		108,800,000	[8]		228,200,000	[9]	214,100,000	[10]
Wholesale Transmission [Member] \| Vertically Integrated Utilities [Member] \| Related Party
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold										80,000,000
Wholesale Transmission [Member] \| Transmission And Distribution Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				184,100,000	[7]		164,900,000	[8]		348,300,000	[9]	319,800,000	[10]
Wholesale Transmission [Member] \| Generation And Marketing [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0	[7]		0	[8]		0	[9]	0	[10]
Wholesale Transmission [Member] \| Other Segments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0	[7]		0	[8]		0	[9]	0	[10]
Other Revenues [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				117,200,000	[11]		116,700,000	[12]		182,500,000	[13]	235,800,000	[14]
Other Revenues [Member] \| Reconciling Adjustments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				(39,900,000)	[11]		(21,100,000)	[12]		(83,600,000)	[13]	(39,700,000)	[14]
Other Revenues [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				4,300,000	[11]		200,000	[12]		7,900,000	[13]	0	[14]
Other Revenues [Member] \| Corporate and Other \| Related Party
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				26,000,000
Other Revenues [Member] \| Vertically Integrated Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				61,900,000	[11]		49,200,000	[12]		94,500,000	[13]	110,800,000	[14]
Other Revenues [Member] \| Transmission And Distribution Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				56,100,000	[11]		65,900,000	[12]		98,900,000	[13]	119,700,000	[14]
Other Revenues [Member] \| Generation And Marketing [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				6,200,000	[11]		1,600,000	[12]		6,800,000	[13]	10,200,000	[14]
Other Revenues [Member] \| Other Segments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				28,600,000	[11]		20,900,000	[12]		58,000,000	[13]	34,800,000	[14]
Wholesale Generation [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				161,100,000			271,400,000			376,300,000		498,900,000
Wholesale Generation [Member] \| Reconciling Adjustments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				100,000			100,000			100,000		100,000
Wholesale Generation [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				0			0			0		0
Wholesale Generation [Member] \| Vertically Integrated Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				141,400,000			188,300,000			324,200,000		375,500,000
Wholesale Generation [Member] \| Transmission And Distribution Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0		0
Wholesale Generation [Member] \| Generation And Marketing [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				19,600,000			83,000,000			52,000,000		123,300,000
Wholesale Generation [Member] \| Other Segments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0		0
Residential [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				1,536,100,000			1,540,900,000			3,363,300,000		3,292,300,000
Residential [Member] \| Reconciling Adjustments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0		0
Residential [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				0			0			0		0
Residential [Member] \| Vertically Integrated Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				962,000,000			979,300,000			2,132,400,000		2,130,100,000
Residential [Member] \| Transmission And Distribution Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				574,100,000			561,600,000			1,230,900,000		1,162,200,000
Residential [Member] \| Generation And Marketing [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0		0
Residential [Member] \| Other Segments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0		0
Commercial [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				1,001,000,000			956,500,000			2,010,300,000		1,819,100,000
Commercial [Member] \| Reconciling Adjustments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0		0
Commercial [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				0			0			0		0
Commercial [Member] \| Vertically Integrated Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				642,700,000			624,800,000			1,276,100,000		1,197,700,000
Commercial [Member] \| Transmission And Distribution Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				358,300,000			331,700,000			734,200,000		621,400,000
Commercial [Member] \| Generation And Marketing [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0		0
Commercial [Member] \| Other Segments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0		0
Industrial [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				850,900,000			804,300,000			1,733,900,000	[15]	1,500,200,000
Industrial [Member] \| Reconciling Adjustments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				(100,000)			0			(300,000)	[15]	(400,000)
Industrial [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				0			0			0	[15]	0
Industrial [Member] \| Vertically Integrated Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				698,900,000			641,800,000			1,369,200,000	[15]	1,204,800,000
Industrial [Member] \| Transmission And Distribution Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				152,100,000			162,500,000			365,000,000	[15]	295,800,000
Industrial [Member] \| Generation And Marketing [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0	[15]	0
Industrial [Member] \| Other Segments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0	[15]	0
Other Retail [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				71,200,000			65,700,000			140,100,000		124,700,000
Other Retail [Member] \| Reconciling Adjustments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0		0
Other Retail [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				0			0			0		0
Other Retail [Member] \| Vertically Integrated Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				58,900,000			52,900,000			115,700,000		100,300,000
Other Retail [Member] \| Transmission And Distribution Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				12,300,000			12,800,000			24,400,000		24,400,000
Other Retail [Member] \| Generation And Marketing [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0		0
Other Retail [Member] \| Other Segments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0		0
Retail [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				3,459,200,000			3,367,400,000			7,247,600,000		6,736,300,000
Retail [Member] \| Reconciling Adjustments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				(100,000)			0			(300,000)		(400,000)
Retail [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				0			0			0		0
Retail [Member] \| Vertically Integrated Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				2,362,500,000			2,298,800,000			4,893,400,000		4,632,900,000
Retail [Member] \| Transmission And Distribution Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				1,096,800,000			1,068,600,000			2,354,500,000		2,103,800,000
Retail [Member] \| Generation And Marketing [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0		0
Retail [Member] \| Other Segments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0		0
Renewable Generation [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				30,000,000	[16]		35,300,000	[17]		51,200,000	[15]	56,900,000	[18]
Renewable Generation [Member] \| Reconciling Adjustments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				(3,100,000)	[16]		(2,900,000)	[17]		(3,200,000)	[15]	(3,700,000)	[18]
Renewable Generation [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				0	[16]		0	[17]		0	[15]	0	[18]
Renewable Generation [Member] \| Vertically Integrated Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0	[16]		0	[17]		0	[15]	0	[18]
Renewable Generation [Member] \| Transmission And Distribution Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0	[16]		0	[17]		0	[15]	0	[18]
Renewable Generation [Member] \| Generation And Marketing [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				33,100,000	[16]		38,200,000	[17]		54,400,000	[15]	60,600,000	[18]
Renewable Generation [Member] \| Other Segments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0	[16]		0	[17]		0	[15]	0	[18]
Retail, Trading and Marketing Revenues [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				398,800,000	[16]		407,300,000	[17]		812,300,000	[19]	790,300,000	[20]
Retail, Trading and Marketing Revenues [Member] \| Reconciling Adjustments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				(10,100,000)	[16]		(2,300,000)	[17]		(10,000,000)	[19]	(11,300,000)	[20]
Retail, Trading and Marketing Revenues [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				0	[16]		0	[17]		0	[19]	0	[20]
Retail, Trading and Marketing Revenues [Member] \| Vertically Integrated Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0	[16]		0	[17]		0	[19]	0	[20]
Retail, Trading and Marketing Revenues [Member] \| Vertically Integrated Utilities [Member] \| Related Party
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold							5,000,000
Retail, Trading and Marketing Revenues [Member] \| Transmission And Distribution Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0	[16]		0	[17]		0	[19]	0	[20]
Retail, Trading and Marketing Revenues [Member] \| Generation And Marketing [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				407,700,000	[16]		408,300,000	[17]		821,400,000	[19]	797,100,000	[20]
Retail, Trading and Marketing Revenues [Member] \| Other Segments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				1,200,000	[16]		1,300,000	[17]		900,000	[19]	4,500,000	[20]
Wholesale and Competitive [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				940,500,000			1,077,300,000			1,917,600,000		2,022,300,000
Wholesale and Competitive [Member] \| Reconciling Adjustments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				(415,900,000)			(337,100,000)			(817,700,000)		(708,700,000)
Wholesale and Competitive [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				455,800,000			421,600,000			905,900,000		836,100,000
Wholesale and Competitive [Member] \| Vertically Integrated Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				254,900,000			297,100,000			552,400,000		589,600,000
Wholesale and Competitive [Member] \| Transmission And Distribution Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				184,100,000			164,900,000			348,300,000		319,800,000
Wholesale and Competitive [Member] \| Generation And Marketing [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				460,400,000			529,500,000			927,800,000		981,000,000
Wholesale and Competitive [Member] \| Other Segments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				1,200,000			1,300,000			900,000		4,500,000
Affiliated and Nonaffiliated [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				4,516,900,000			4,561,400,000			9,347,700,000		8,994,400,000
Affiliated and Nonaffiliated [Member] \| Reconciling Adjustments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				(455,900,000)			(358,200,000)			(901,600,000)		(748,800,000)
Affiliated and Nonaffiliated [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				460,100,000			421,800,000			913,800,000		836,100,000
Affiliated and Nonaffiliated [Member] \| Vertically Integrated Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				2,679,300,000			2,645,100,000			5,540,300,000		5,333,300,000
Affiliated and Nonaffiliated [Member] \| Transmission And Distribution Utilities [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				1,337,000,000			1,299,400,000			2,801,700,000		2,543,300,000
Affiliated and Nonaffiliated [Member] \| Generation And Marketing [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				466,600,000			531,100,000			934,600,000		991,200,000
Affiliated and Nonaffiliated [Member] \| Other Segments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				29,800,000			22,200,000			58,900,000		39,300,000
Other Revenues [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				94,500,000			93,500,000			186,900,000		187,600,000
Other Revenues [Member] \| Corporate and Other \| Related Party
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold										55,000,000		19,000,000
Other Revenues [Member] \| Other Segments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold	[6]			6,200,000			14,400,000			8,500,000		25,100,000
Retail, Trading and Marketing \| Generation And Marketing [Member] \| Related Party
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold										$ 10,000,000		11,000,000
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
Maximum Shares Issued Under Equity Units Conversion										10,205,100
Corporate unit ownership share of an equity unit				5%						5%
Junior Subordinated Debt [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Interest Rate (Percentage)				5.699%						5.699%
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%
Senior Unsecured Notes [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]									$ 850,000,000
Due Date										2033
Interest Rate (Percentage)				5.63%						5.63%
Commercial Paper [Member]
Short-term Debt:
Weighted Average Interest Rate	[5]			5.50%						5.50%				4.80%
Term Loan [Member]
Short-term Debt:
Weighted Average Interest Rate	[5]			5.94%						5.94%				5.17%
Term Loan				$ 125,000,000						$ 125,000,000				$ 125,000,000
Term Loan 2 [Member]
Short-term Debt:
Weighted Average Interest Rate	[5]			5.94%						5.94%				5.17%
Term Loan				$ 150,000,000						$ 150,000,000				$ 150,000,000
Term Loan 3
Short-term Debt:
Weighted Average Interest Rate	[5]			6.08%						6.08%				0%
Term Loan				$ 500,000,000						$ 500,000,000				$ 0
Term Loan 4
Short-term Debt:
Weighted Average Interest Rate	[5]			5.94%						5.94%				5.23%
Term Loan				$ 100,000,000						$ 100,000,000				$ 100,000,000
Term Loan 5
Short-term Debt:
Weighted Average Interest Rate	[5]			0%						0%				4.87%
Term Loan				$ 0						$ 0				$ 125,000,000
AEP Texas Inc. [Member]
Long-term Debt
Total Long-term Debt Outstanding				5,937,500,000						5,937,500,000				5,657,800,000
Long-term Debt Due Within One Year				154,700,000						154,700,000				278,500,000
Long-term Debt				5,782,800,000						5,782,800,000				5,379,300,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt										$ 168,200,000		242,000,000
Financing Activities (Textuals)
Maximum Percentage Debt to Capitalization										67.50%
Issuance of Long-term Debt										$ 445,900,000		1,188,600,000
AEP Texas Inc. [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool				135,900,000						135,900,000				96,500,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				1,300,000			800,000			2,500,000		1,700,000
Financing Activities (Textuals)
Net Loans To Money Pool				6,900,000						6,900,000				6,900,000
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				163,100,000	[21]		143,800,000	[22]		309,400,000	[23]	276,900,000	[24]
AEP Texas Inc. [Member] \| Other Revenues [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				10,700,000	[25]		5,600,000	[26]		20,400,000	[27]	14,900,000	[28]
AEP Texas Inc. [Member] \| Wholesale Generation [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0	[29]		0	[30]		0	[31]	0	[32]
AEP Texas Inc. [Member] \| Residential [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				144,900,000			174,900,000			275,600,000		316,800,000
AEP Texas Inc. [Member] \| Commercial [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				100,600,000			110,600,000			197,900,000		205,500,000
AEP Texas Inc. [Member] \| Industrial [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				35,200,000			36,600,000			74,500,000	[33]	67,200,000
AEP Texas Inc. [Member] \| Other Retail [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				8,700,000			9,500,000			17,000,000		17,700,000
AEP Texas Inc. [Member] \| Retail [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				289,400,000			331,600,000			565,000,000		607,200,000
AEP Texas Inc. [Member] \| Wholesale and Competitive [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				163,100,000			143,800,000			309,400,000		276,900,000
AEP Texas Inc. [Member] \| Affiliated and Nonaffiliated [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				463,200,000			481,000,000			894,800,000		899,000,000
AEP Texas Inc. [Member] \| Other Revenues [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				500,000			1,100,000			$ 1,100,000		$ 2,200,000
AEP Texas Inc. [Member] \| Utility [Member]
Maximum Interest Rate										5.69%		2.11%
Minimum Interest Rate										4.66%		0.10%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool										$ 477,500,000
Maximum Loans to Money Pool										0
Average Borrowings from Money Pool										279,900,000
Average Loans to Money Pool										0
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										5.35%		0.90%
Average Interest Rate For Funds Loaned										0%		1.48%
AEP Texas Inc. [Member] \| Utility [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool				(135,900,000)						$ (135,900,000)
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
Maximum and Minimum Interest Rates
Maximum Interest Rate For Funds Loaned										5.69%		2.11%
Minimum Interest Rate for Funds Loaned										4.66%		0.46%
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Loaned										5.35%		0.98%
AEP Texas Inc. [Member] \| Nonutility [Member] \| Related Party
Financing Activities (Textuals)
Net Loans To Money Pool				$ 6,900,000						$ 6,900,000
AEP Texas Inc. [Member] \| Securitization Bonds [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt										$ 31,500,000
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										$ 11,700,000
Due Date										2025
Interest Rate (Percentage)				2.06%						2.06%
AEP Texas Inc. [Member] \| Senior Unsecured Notes Three
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]									$ 450,000,000
Due Date										2033
Interest Rate (Percentage)				5.40%						5.40%
AEP Texas Inc. [Member] \| Senior Unsecured Notes Eight
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt										$ 125,000,000
Due Date										2023
Interest Rate (Percentage)				3.09%						3.09%
AEP Transmission Co [Member]
Long-term Debt
Total Long-term Debt Outstanding				$ 5,473,000,000						$ 5,473,000,000				4,782,800,000
Long-term Debt Due Within One Year				60,000,000						60,000,000				60,000,000
Long-term Debt				5,413,000,000						5,413,000,000				4,722,800,000
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				0.60%						0.60%
Maximum Percentage Debt to Capitalization										67.50%
Issuance of Long-term Debt										$ 689,100,000		$ 540,900,000
AEP Transmission Co [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool				$ 74,400,000						74,400,000				229,300,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				365,800,000			333,900,000			723,200,000		658,900,000
Financing Activities (Textuals)
Net Loans To Money Pool				79,400,000						79,400,000				4,400,000
AEP Transmission Co [Member] \| Reconciling Adjustments [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0		0
AEP Transmission Co [Member] \| Reconciling Adjustments [Member] \| Related Party
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0		0
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				444,700,000	[21]		406,100,000	[22]		883,400,000	[23]	806,400,000	[24]
AEP Transmission Co [Member] \| Wholesale Transmission [Member] \| Related Party
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				357,000,000			330,000,000			706,000,000		653,000,000
AEP Transmission Co [Member] \| Other Revenues [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				4,100,000	[25]		200,000	[26]		7,800,000	[27]	(100,000)	[28]
AEP Transmission Co [Member] \| Wholesale Generation [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0	[29]		0	[30]		0	[31]	0	[32]
AEP Transmission Co [Member] \| Residential [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0		0
AEP Transmission Co [Member] \| Commercial [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0		0
AEP Transmission Co [Member] \| Industrial [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0	[33]	0
AEP Transmission Co [Member] \| Other Retail [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0		0
AEP Transmission Co [Member] \| Retail [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0			0			0		0
AEP Transmission Co [Member] \| Wholesale and Competitive [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				444,700,000			406,100,000			883,400,000		806,400,000
AEP Transmission Co [Member] \| Affiliated and Nonaffiliated [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				448,800,000			406,300,000			$ 891,200,000		$ 806,300,000
AEP Transmission Co [Member] \| Utility [Member]
Maximum Interest Rate										5.69%		2.11%
Minimum Interest Rate										4.66%		0.10%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool										$ 471,300,000
Maximum Loans to Money Pool										309,400,000
Average Borrowings from Money Pool										153,100,000
Average Loans to Money Pool										85,900,000
Authorized Short Term Borrowing Limit	[34]									$ 820,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed										5.16%		0.93%
Average Interest Rate For Funds Loaned										5.46%		1.49%
AEP Transmission Co [Member] \| Utility [Member] \| Related Party
Financing Activities (Textuals)
Net Loans To Money Pool				26,900,000						$ 26,900,000
AEP Transmission Co [Member] \| Direct Borrowing [Member]
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool										29,400,000
Maximum Loans to Money Pool										158,100,000
Average Borrowings from Money Pool										2,900,000
Average Loans to Money Pool										70,200,000
Borrowings from Parent				21,900,000						21,900,000
Loans to Parent				$ 0						0
Authorized Short Term Borrowing Limit	[35]									$ 50,000,000
Maximum and Minimum Interest Rates
Maximum Interest Rate for Funds Borrowed										5.69%		2.11%
Minimum Interest Rate For Funds Borrowed										4.53%		0.46%
Maximum Interest Rate For Funds Loaned										5.69%		2.11%
Minimum Interest Rate for Funds Loaned										4.53%		0.46%
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed										5.27%		1.02%
Average Interest Rate For Funds Loaned										5.35%		0.89%
AEP Transmission Co [Member] \| Senior Unsecured Notes Two [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]									$ 700,000,000
Due Date										2053
Interest Rate (Percentage)				5.40%						5.40%
Appalachian Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding				$ 5,599,700,000						$ 5,599,700,000				5,410,500,000
Long-term Debt Due Within One Year				538,300,000						538,300,000				251,800,000
Long-term Debt				5,061,400,000						5,061,400,000				5,158,700,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt										13,000,000		$ 117,100,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues				181,900,000						181,900,000				194,400,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit				414,900,000			339,000,000			$ 921,100,000		754,500,000
Financing Activities (Textuals)
Maximum Percentage Debt to Capitalization										67.50%
Issuance of Long-term Debt										$ 200,000,000		103,300,000
Appalachian Power Co [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool				266,100,000						266,100,000				182,200,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				61,100,000			63,100,000			130,700,000		120,000,000
Financing Activities (Textuals)
Net Loans To Money Pool				18,900,000						18,900,000				19,800,000
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				43,900,000	[21]		40,800,000	[22]		85,300,000	[23]	81,900,000	[24]
Appalachian Power Co [Member] \| Other Revenues [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				11,800,000	[25]		20,600,000	[26]		24,800,000	[27]	44,900,000	[28]
Appalachian Power Co [Member] \| Wholesale Generation [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				64,200,000	[29]		63,500,000	[30]		144,400,000	[31]	119,700,000	[32]
Appalachian Power Co [Member] \| Wholesale Generation [Member] \| Related Party
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				38,000,000			42,000,000			85,000,000		78,000,000
Appalachian Power Co [Member] \| Residential [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				324,800,000			313,200,000			795,300,000		771,200,000
Appalachian Power Co [Member] \| Commercial [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				163,600,000			152,600,000			334,900,000		306,500,000
Appalachian Power Co [Member] \| Industrial [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				192,500,000			161,900,000			378,300,000	[33]	315,700,000
Appalachian Power Co [Member] \| Other Retail [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				25,200,000			20,200,000			51,400,000		40,800,000
Appalachian Power Co [Member] \| Retail [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				706,100,000			647,900,000			1,559,900,000		1,434,200,000
Appalachian Power Co [Member] \| Wholesale and Competitive [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				108,100,000			104,300,000			229,700,000		201,600,000
Appalachian Power Co [Member] \| Affiliated and Nonaffiliated [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				826,000,000			772,800,000			1,814,400,000		1,680,700,000
Appalachian Power Co [Member] \| Other Revenues [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				2,900,000			5,600,000			6,500,000		8,900,000
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				4,300,000			1,500,000			$ 9,200,000		$ 2,800,000
Appalachian Power Co [Member] \| Utility [Member]
Maximum Interest Rate										5.69%		2.11%
Minimum Interest Rate										4.66%		0.10%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool										$ 388,600,000
Maximum Loans to Money Pool										19,800,000
Average Borrowings from Money Pool										295,000,000
Average Loans to Money Pool										18,900,000
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										5.36%		1.08%
Average Interest Rate For Funds Loaned										5.35%		0.95%
Appalachian Power Co [Member] \| Utility [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool				$ (247,200,000)						$ (247,200,000)
Appalachian Power Co [Member] \| Other Long Term Debt [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]									$ 200,000,000
Due Date										2024
Interest Rate (Variable)										Variable
Appalachian Power Co [Member] \| Securitization Bonds Three
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt										$ 9,700,000
Due Date										2023
Interest Rate (Percentage)				2.01%						2.01%
Appalachian Power Co [Member] \| Securitization Bonds Four
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt										$ 3,300,000
Due Date										2028
Interest Rate (Percentage)				3.77%						3.77%
Indiana Michigan Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding				$ 3,464,100,000						$ 3,464,100,000				3,260,800,000
Long-term Debt Due Within One Year				74,300,000						74,300,000				341,800,000
Long-term Debt				3,389,800,000						3,389,800,000				2,919,000,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt										299,200,000		$ 40,700,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues				177,300,000						177,300,000				166,900,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit				497,200,000			502,400,000			1,022,600,000		1,015,800,000
Financing Activities (Textuals)
Trust Fund Assets One Time Fee Obligation for Nuclear Fuel Disposition				341,000,000						$ 341,000,000				330,000,000
Maximum Percentage Debt to Capitalization										67.50%
Issuance of Long-term Debt										$ 494,900,000		72,800,000
Indiana Michigan Power Co [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool				0						0				249,900,000
Financing Activities (Textuals)
Net Loans To Money Pool				40,500,000						40,500,000				23,000,000
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				9,600,000	[21]		8,700,000	[22]		17,700,000	[23]	17,500,000	[24]
Indiana Michigan Power Co [Member] \| Other Revenues [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				45,000,000	[25]		25,800,000	[26]		66,400,000	[27]	55,700,000	[28]
Indiana Michigan Power Co [Member] \| Other Revenues [Member] \| Related Party
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				17,000,000
Indiana Michigan Power Co [Member] \| Wholesale Generation [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				63,500,000	[29]		94,200,000	[30]		167,500,000	[31]	184,600,000	[32]
Indiana Michigan Power Co [Member] \| Residential [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				185,200,000			195,200,000			424,800,000		427,000,000
Indiana Michigan Power Co [Member] \| Commercial [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				141,400,000			138,600,000			280,300,000		265,200,000
Indiana Michigan Power Co [Member] \| Industrial [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				155,900,000			160,000,000			308,500,000	[33]	296,500,000
Indiana Michigan Power Co [Member] \| Other Retail [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				1,200,000			1,200,000			2,500,000		2,500,000
Indiana Michigan Power Co [Member] \| Retail [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				483,700,000			495,000,000			1,016,100,000		991,200,000
Indiana Michigan Power Co [Member] \| Wholesale and Competitive [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				73,100,000			102,900,000			185,200,000		202,100,000
Indiana Michigan Power Co [Member] \| Affiliated and Nonaffiliated [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				601,800,000			623,700,000			1,267,700,000		1,249,000,000
Indiana Michigan Power Co [Member] \| Other Revenues [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				2,400,000			2,800,000			5,500,000		5,600,000
Indiana Michigan Power Co [Member] \| Other Revenues [Member] \| Related Party
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold							19,000,000			35,000,000		29,000,000
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				3,900,000			2,000,000			$ 7,800,000		$ 3,700,000
Indiana Michigan Power Co [Member] \| Utility [Member]
Maximum Interest Rate										5.69%		2.11%
Minimum Interest Rate										4.66%		0.10%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool										$ 475,300,000
Maximum Loans to Money Pool										100,300,000
Average Borrowings from Money Pool										174,000,000
Average Loans to Money Pool										43,000,000
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										5.13%		0.92%
Average Interest Rate For Funds Loaned										5.42%		0.96%
Indiana Michigan Power Co [Member] \| Utility [Member] \| Related Party
Financing Activities (Textuals)
Net Loans To Money Pool				$ 40,500,000						$ 40,500,000
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										$ 7,900,000
Due Date										2025
Interest Rate (Percentage)				0.93%						0.93%
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										$ 13,700,000
Due Date										2026
Interest Rate (Percentage)				3.44%						3.44%
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										$ 13,600,000
Due Date										2027
Interest Rate (Percentage)				5.93%						5.93%
Indiana Michigan Power Co [Member] \| OtherLongTermDebtThree
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt										$ 1,200,000
Due Date										2025
Interest Rate (Percentage)				6%						6%
Indiana Michigan Power Co [Member] \| Notes Payable, Other Payable Nine \| Subsequent Event [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 8,000,000
Indiana Michigan Power Co [Member] \| Notes Payable, Other Payable
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt										$ 1,200,000
Due Date										2023
Interest Rate (Variable)										Variable
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										$ 2,400,000
Due Date										2024
Interest Rate (Variable)										Variable
Indiana Michigan Power Co [Member] \| Senior Unsecured Notes Four
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]									$ 500,000,000
Due Date										2053
Interest Rate (Percentage)				5.63%						5.63%
Indiana Michigan 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										$ 9,200,000
Due Date										2025
Interest Rate (Variable)										Variable
Indiana Michigan Power Co [Member] \| Senior Unsecured Notes Nine
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt										$ 250,000,000
Due Date										2023
Interest Rate (Percentage)				3.20%						3.20%
Ohio Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding				$ 3,365,600,000						$ 3,365,600,000				2,970,300,000
Long-term Debt Due Within One Year				0						0				100,000
Long-term Debt				3,365,600,000						3,365,600,000				2,970,200,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt										600,000		$ 100,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues				477,400,000						477,400,000				478,600,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit				783,900,000			693,300,000			1,668,300,000		1,409,900,000
Financing Activities (Textuals)
Issuance of Long-term Debt										395,100,000		0
Ohio Power Co [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool				72,300,000						72,300,000				172,900,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				8,200,000			3,900,000			15,800,000		7,600,000
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				21,000,000	[21]		21,100,000	[22]		38,900,000	[23]	42,900,000	[24]
Ohio Power Co [Member] \| Other Revenues [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				45,500,000	[25]		60,200,000	[26]		78,700,000	[27]	104,800,000	[28]
Ohio Power Co [Member] \| Wholesale Generation [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				0	[29]		0	[30]		0	[31]	0	[32]
Ohio Power Co [Member] \| Residential [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				429,300,000			386,700,000			955,300,000		845,400,000
Ohio Power Co [Member] \| Commercial [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				257,800,000			221,100,000			536,300,000		415,800,000
Ohio Power Co [Member] \| Industrial [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				116,800,000			126,000,000			290,400,000	[33]	228,700,000
Ohio Power Co [Member] \| Other Retail [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				3,600,000			3,400,000			7,400,000		6,700,000
Ohio Power Co [Member] \| Retail [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				807,500,000			737,200,000			1,789,400,000		1,496,600,000
Ohio Power Co [Member] \| Wholesale and Competitive [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				21,000,000			21,100,000			38,900,000		42,900,000
Ohio Power Co [Member] \| Affiliated and Nonaffiliated [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				874,000,000			818,500,000			1,907,000,000		1,644,300,000
Ohio Power Co [Member] \| Other Revenues [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				2,100,000			1,800,000			7,300,000		3,900,000
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				7,600,000			7,500,000			$ 14,900,000		$ 14,900,000
Ohio Power Co [Member] \| Utility [Member]
Maximum Interest Rate										5.69%		2.11%
Minimum Interest Rate										4.66%		0.10%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool										$ 485,700,000
Maximum Loans to Money Pool										64,700,000
Average Borrowings from Money Pool										266,400,000
Average Loans to Money Pool										40,200,000
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										5.30%		0.83%
Average Interest Rate For Funds Loaned										5.60%		1.20%
Ohio Power Co [Member] \| Utility [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool				$ (72,300,000)						$ (72,300,000)
Ohio Power Co [Member] \| OtherLongTermDebtFour
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt										$ 600,000
Due Date										2028
Interest Rate (Percentage)				1.15%						1.15%
Ohio Power Co [Member] \| Senior Unsecured Notes Five
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]									$ 400,000,000
Due Date										2033
Interest Rate (Percentage)				5%						5%
Public Service Co Of Oklahoma [Member]
Long-term Debt
Total Long-term Debt Outstanding				$ 2,383,900,000						$ 2,383,900,000				1,912,800,000
Long-term Debt Due Within One Year				600,000						600,000				500,000
Long-term Debt				2,383,300,000						2,383,300,000				1,912,300,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt										300,000		$ 300,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues				177,800,000						177,800,000				155,500,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit				460,200,000			428,500,000			$ 876,500,000		791,900,000
Financing Activities (Textuals)
Maximum Percentage Debt to Capitalization										67.50%
Issuance of Long-term Debt										$ 469,800,000		500,000,000
Public Service Co Of Oklahoma [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool				68,100,000						68,100,000				364,200,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				100,000			800,000			800,000		1,400,000
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				9,900,000	[21]		9,100,000	[22]		21,200,000	[23]	18,700,000	[24]
Public Service Co Of Oklahoma [Member] \| Other Revenues [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				7,200,000	[25]		9,600,000	[26]		9,500,000	[27]	15,000,000	[28]
Public Service Co Of Oklahoma [Member] \| Wholesale Generation [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				4,300,000	[29]		300,000	[30]		5,200,000	[31]	9,800,000	[32]
Public Service Co Of Oklahoma [Member] \| Residential [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				186,500,000			185,200,000			357,400,000		351,100,000
Public Service Co Of Oklahoma [Member] \| Commercial [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				131,700,000			121,200,000			240,800,000		218,700,000
Public Service Co Of Oklahoma [Member] \| Industrial [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				107,800,000			92,500,000			206,100,000	[33]	171,100,000
Public Service Co Of Oklahoma [Member] \| Other Retail [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				28,300,000			25,800,000			52,500,000		47,000,000
Public Service Co Of Oklahoma [Member] \| Retail [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				454,300,000			424,700,000			856,800,000		787,900,000
Public Service Co Of Oklahoma [Member] \| Wholesale and Competitive [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				14,200,000			9,400,000			26,400,000		28,500,000
Public Service Co Of Oklahoma [Member] \| Affiliated and Nonaffiliated [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				475,700,000			443,700,000			892,700,000		831,400,000
Public Service Co Of Oklahoma [Member] \| Other Revenues [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				2,200,000			2,100,000			3,700,000		2,700,000
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				3,500,000			1,300,000			$ 6,700,000		$ 2,200,000
Public Service Co Of Oklahoma [Member] \| Utility [Member]
Maximum Interest Rate										5.69%		2.11%
Minimum Interest Rate										4.66%		0.10%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool										$ 375,000,000
Maximum Loans to Money Pool										121,500,000
Average Borrowings from Money Pool										127,500,000
Average Loans to Money Pool										74,800,000
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										5.47%		1.17%
Average Interest Rate For Funds Loaned										5.11%		0.65%
Public Service Co Of Oklahoma [Member] \| Utility [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool				$ (68,100,000)						$ (68,100,000)
Public Service Co Of Oklahoma [Member] \| Other Long Term Debt Five
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt										$ 300,000
Due Date										2027
Interest Rate (Percentage)				3%						3%
Public Service Co Of Oklahoma [Member] \| Senior Unsecured Notes Six
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]									$ 475,000,000
Due Date										2033
Interest Rate (Percentage)				5.25%						5.25%
Southwestern Electric Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding				$ 3,645,600,000						$ 3,645,600,000				3,391,600,000
Long-term Debt Due Within One Year				0						0				6,200,000
Long-term Debt				3,645,600,000						3,645,600,000				3,385,400,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt										94,100,000		$ 3,100,000
Short-term Debt:
Notes Payable				3,900,000						3,900,000				0
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues				191,600,000						191,600,000				194,000,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit				460,500,000			437,200,000			$ 898,100,000		831,700,000
Financing Activities (Textuals)
Maximum Percentage Debt to Capitalization										67.50%
Issuance of Long-term Debt										$ 346,800,000		0
Southwestern Electric Power Co [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool				32,600,000						32,600,000				310,700,000
Financing Activities (Textuals)
Net Loans To Money Pool				2,200,000						2,200,000				$ 2,100,000
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				38,300,000	[21]		39,300,000	[22]		81,200,000	[23]	74,500,000	[24]
Southwestern Electric Power Co [Member] \| Other Revenues [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				7,000,000	[25]		6,000,000	[26]		14,900,000	[27]	11,300,000	[28]
Southwestern Electric Power Co [Member] \| Wholesale Generation [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				43,900,000	[29]		57,400,000	[30]		83,500,000	[31]	118,600,000	[32]
Southwestern Electric Power Co [Member] \| Residential [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				185,100,000			188,600,000			361,000,000		364,500,000
Southwestern Electric Power Co [Member] \| Commercial [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				153,800,000			146,000,000			297,300,000		276,500,000
Southwestern Electric Power Co [Member] \| Industrial [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				110,600,000			97,100,000			214,800,000	[33]	181,800,000
Southwestern Electric Power Co [Member] \| Other Retail [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				2,600,000			4,400,000			5,200,000		6,800,000
Southwestern Electric Power Co [Member] \| Retail [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				452,100,000			436,100,000			878,300,000		829,600,000
Southwestern Electric Power Co [Member] \| Wholesale and Competitive [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				82,200,000			96,700,000			164,700,000		193,100,000
Southwestern Electric Power Co [Member] \| Affiliated and Nonaffiliated [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				541,300,000			538,800,000			1,057,900,000		1,034,000,000
Southwestern Electric Power Co [Member] \| Other Revenues [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				800,000			400,000			1,300,000		1,000,000
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				4,400,000			1,500,000			$ 8,700,000		$ 2,800,000
Southwestern Electric Power Co [Member] \| Utility [Member]
Maximum Interest Rate										5.69%		2.11%
Minimum Interest Rate										4.66%		0.10%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool	[36]									$ 401,600,000
Maximum Loans to Money Pool										0
Average Borrowings from Money Pool										220,600,000
Average Loans to Money Pool										0
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										5.22%		1.25%
Average Interest Rate For Funds Loaned										0%		0.55%
Financing Activities (Textuals)
Amount Exceeding Maximum Borrowings from Money Pool		$ 1,600,000
Southwestern Electric Power Co [Member] \| Utility [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool				(32,600,000)						$ (32,600,000)
Southwestern Electric Power Co [Member] \| Nonutility [Member]
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Loans to Money Pool										2,200,000
Average Loans to Money Pool										$ 2,100,000
Maximum and Minimum Interest Rates
Maximum Interest Rate For Funds Loaned										5.69%		2.11%
Minimum Interest Rate for Funds Loaned										4.66%		0.46%
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Loaned										5.35%		0.98%
Southwestern Electric Power Co [Member] \| Nonutility [Member] \| Related Party
Financing Activities (Textuals)
Net Loans To Money Pool				$ 2,200,000						$ 2,200,000
Southwestern Electric 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										$ 25,000,000
Due Date										2024
Interest Rate (Percentage)				6.37%						6.37%
Southwestern Electric 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										$ 30,900,000
Due Date										2032
Interest Rate (Percentage)				4.58%						4.58%
Southwestern Electric Power Co [Member] \| Other Long Term Debt Six
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt										$ 38,200,000
Due Date										2028
Interest Rate (Percentage)				4.68%						4.68%
Southwestern Electric Power Co [Member] \| Senior Unsecured Notes Seven
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]									$ 350,000,000
Due Date										2033
Interest Rate (Percentage)				5.30%						5.30%
Southwestern Electric Power Co [Member] \| Loans Payable [Member]
Short-term Debt:
Weighted Average Interest Rate	[5]			7.53%						7.53%				0%
Transource Energy [Member] \| Other Long Term Debt Two [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]									$ 13,000,000
Due Date										2025
Interest Rate (Variable)										Variable
Transource Energy [Member] \| Senior Unsecured Notes Ten
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt										$ 1,300,000
Due Date										2050
Interest Rate (Percentage)				2.75%						2.75%
Kentucky Power Co [Member] \| Pollution Control Bond [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]									$ 65,000,000
Due Date										2026
Interest Rate (Percentage)				4.70%						4.70%
Kentucky Power Co [Member] \| Pollution Control Bond Two [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt										$ 65,000,000
Due Date										2023
Interest Rate (Percentage)				2.35%						2.35%
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,				$ (3,300,000)		$ 12,700,000	$ (17,200,000)		$ 15,200,000
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 $341 million and $330 million as of June 30, 2023 and December 31, 2022, 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]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.[4]Amount of securitized debt for receivables as accounted for under the “Transfers and Servicing” accounting guidance.[5]Weighted-average rate as of June 30, 2023 and December 31, 2022, respectively.[6]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.[7]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $360 million. The remaining affiliated amounts were immaterial.[8]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $334 million. The remaining affiliated amounts were immaterial.[9]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $712 million. The affiliated revenue for Vertically Integrated Utilities was $80 million. The remaining affiliated amounts were immaterial.[10]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $661 million. The remaining affiliated amounts were immaterial.[11]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $26 million. The remaining affiliated amounts were immaterial.[12]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Vertically Integrated Utilities was $5 million. The remaining affiliated amounts were immaterial.[13]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $55 million. The remaining affiliated amounts were immaterial.[14]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $19 million. The remaining affiliated amounts were immaterial.[15]Amounts include affiliated and nonaffiliated revenues.[16]Amounts include affiliated and nonaffiliated revenues.[17]Amounts include affiliated and nonaffiliated revenues[18]Amounts include affiliated and nonaffiliated revenues.[19]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $10 million. The remaining affiliated amounts were immaterial.[20]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $11 million. The remaining affiliated amounts were immaterial.[21]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $357 million. The remaining affiliated amounts were immaterial.[22]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $330 million. The remaining affiliated amounts were immaterial.[23]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $706 million. The remaining affiliated amounts were immaterial.[24]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $653 million. The remaining affiliated amounts were immaterial.[25]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.[26]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $19 million primarily related to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial.[27]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $35 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial.[28]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $29 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial.[29]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $38 million primarily related to the PPA with KGPCo.[30]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $42 million primarily related to the PPA with KGPCo.[31]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $85 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial.[32]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $78 million primarily relating to the PPA with KGPCo.[33]Amounts include affiliated and nonaffiliated revenues.[34](a) Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions.[35](a) Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions.[36]SWEPCo’s maximum borrowings from the Utility Money Pool exceeded the authorized short-term borrowing limit by $1.6 million on March 15, 2023. On March 16, 2023, SWEPCo’s borrowings from the Utility Money Pool were reduced below the $400 million authorized limit and borrowings have continued to remain below the authorized limit.

Variable Interest Entities (Det

Variable Interest Entities (Details) - USD ($) $ in Millions	Jun. 30, 2023		Mar. 31, 2023	Dec. 31, 2022		Jun. 30, 2022	Mar. 31, 2022	Dec. 31, 2021
ASSETS
Current Assets	$ 8,041.3			$ 6,775.5
Net Property, Plant and Equipment	74,681.4			73,339.1
Other Noncurrent Assets	13,279.4			13,288.7
Total Assets	96,002.1	[1]		93,403.3
LIABILITIES AND EQUITY
Current Liabilities	13,267.1			13,266.3
Noncurrent Liabilities	58,546.7			55,968.7
Equity	24,123.6		$ 23,967.8	24,122.4		$ 24,297	$ 24,038.1	$ 22,680.2
Total Liabilities and Equity	96,002.1			93,403.3
Southwestern Electric Power Co [Member]
ASSETS
Current Assets	612.1			812.2
Net Property, Plant and Equipment	8,472.9			8,262.2
Other Noncurrent Assets	1,461.1			1,304.4
Total Assets	10,546.1			10,378.8
LIABILITIES AND EQUITY
Current Liabilities	784.7			947.7
Noncurrent Liabilities	5,965.9			5,756.3
Equity	3,795.5		3,765.2	3,674.8		3,611.1	3,543.8	3,149.8
Total Liabilities and Equity	10,546.1			10,378.8
Indiana Michigan Power Co [Member]
ASSETS
Current Assets	584.1			571.8
Net Property, Plant and Equipment	7,482.7			7,411.5
Other Noncurrent Assets	4,373.4			4,135.6
Total Assets	12,440.2			12,118.9
LIABILITIES AND EQUITY
Current Liabilities	678.2			1,197.1
Noncurrent Liabilities	8,641.3			7,913.5
Equity	3,120.7		3,077.3	3,008.3		2,893.3	2,849.5	2,784.7
Total Liabilities and Equity	12,440.2			12,118.9
AEP Texas Inc. [Member]
ASSETS
Current Assets	487.2			446.9
Net Property, Plant and Equipment	12,314.7			11,681.6
Other Noncurrent Assets	812.5			763.7
Total Assets	13,614.4			12,892.2
LIABILITIES AND EQUITY
Current Liabilities	923.7			1,043.8
Noncurrent Liabilities	8,356.1			7,944.1
Equity	4,334.6		4,051.3	3,904.3		3,755.6	3,664.1	3,594.2
Total Liabilities and Equity	13,614.4			12,892.2
Appalachian Power Co [Member]
ASSETS
Current Assets	1,392.6			1,259.6
Net Property, Plant and Equipment	12,674			12,379.2
Other Noncurrent Assets	1,391.4			1,583.4
Total Assets	15,458			15,222.2
LIABILITIES AND EQUITY
Current Liabilities	1,604			1,390.2
Noncurrent Liabilities	8,720.9			8,856.6
Equity	5,133.1		$ 5,086.9	4,975.4		$ 4,821.1	$ 4,748	$ 4,647.9
Total Liabilities and Equity	15,458			15,222.2
Sabine Mining Co [Member] \| Variable Interest Entities [Member] \| Southwestern Electric Power Co [Member]
ASSETS
Current Assets	5.8			108.3
Net Property, Plant and Equipment	0			7.2
Other Noncurrent Assets	129.7			130
Total Assets	135.5			245.5
LIABILITIES AND EQUITY
Current Liabilities	19.8			25.4
Noncurrent Liabilities	115.6			219.4
Equity	0.1			0.7
Total Liabilities and Equity	135.5			245.5
DCC Fuel [Member] \| Variable Interest Entities [Member] \| Indiana Michigan Power Co [Member]
ASSETS
Current Assets	72.5			90.2
Net Property, Plant and Equipment	129.3			179.1
Other Noncurrent Assets	63.6			94
Total Assets	265.4			363.3
LIABILITIES AND EQUITY
Current Liabilities	72.4			90
Noncurrent Liabilities	193			273.3
Equity	0			0
Total Liabilities and Equity	265.4			363.3
AEP Texas Central Transition Funding Co [Member] \| AEP Texas Inc. [Member] \| Other Noncurrent Assets [Member]
LIABILITIES AND EQUITY
Unearned Revenue	12			16
AEP Texas Central Transition Funding Co [Member] \| Variable Interest Entities [Member] \| AEP Texas Inc. [Member]
ASSETS
Current Assets	26.9			27
Net Property, Plant and Equipment	0			0
Other Noncurrent Assets	109.5	[2]		140.9	[3]
Total Assets	136.4			167.9
LIABILITIES AND EQUITY
Current Liabilities	74.5			73.2
Noncurrent Liabilities	57.5			90.4
Equity	4.4			4.3
Total Liabilities and Equity	136.4			167.9
Restoration Funding [Member] \| AEP Texas Inc. [Member] \| Other Noncurrent Assets [Member]
LIABILITIES AND EQUITY
Unearned Revenue	7			7
Restoration Funding [Member] \| Variable Interest Entities [Member] \| AEP Texas Inc. [Member]
ASSETS
Current Assets	25.4			21.1
Net Property, Plant and Equipment	0			0
Other Noncurrent Assets	157.2	[4]		168.8	[5]
Total Assets	182.6			189.9
LIABILITIES AND EQUITY
Current Liabilities	36.7			31.3
Noncurrent Liabilities	144.7			157.4
Equity	1.2			1.2
Total Liabilities and Equity	182.6			189.9
Appalachian Consumer Rate Relief Funding [Member] \| Appalachian Power Co [Member] \| Other Noncurrent Assets [Member]
LIABILITIES AND EQUITY
Unearned Revenue	2			2
Appalachian Consumer Rate Relief Funding [Member] \| Variable Interest Entities [Member] \| Appalachian Power Co [Member]
ASSETS
Current Assets	13.3			13.5
Net Property, Plant and Equipment	0			0
Other Noncurrent Assets	151.8	[6]		164.6	[7]
Total Assets	165.1			178.1
LIABILITIES AND EQUITY
Current Liabilities	29.6			29.3
Noncurrent Liabilities	133.6			146.9
Equity	1.9			1.9
Total Liabilities and Equity	165.1			178.1
AEP Credit, Inc. [Member] \| Variable Interest Entities [Member]
ASSETS
Current Assets	1,186			1,181
Net Property, Plant and Equipment	0			0
Other Noncurrent Assets	9.4			9
Total Assets	1,195.4			1,190
LIABILITIES AND EQUITY
Current Liabilities	1,132.8			1,087.8
Noncurrent Liabilities	0.9			0.9
Equity	61.7			101.3
Total Liabilities and Equity	1,195.4			1,190
Protected Cell Of Energy Insurance Services, Inc. [Member] \| Variable Interest Entities [Member]
ASSETS
Current Assets	195.1			194.5
Net Property, Plant and Equipment	0			0
Other Noncurrent Assets	0			0.3
Total Assets	195.1			194.8
LIABILITIES AND EQUITY
Current Liabilities	39.7			46.4
Noncurrent Liabilities	81.9			79.1
Equity	73.5			69.3
Total Liabilities and Equity	195.1			194.8
Transource Energy [Member] \| Variable Interest Entities [Member]
ASSETS
Current Assets	29.3			23.5
Net Property, Plant and Equipment	496.6			482.3
Other Noncurrent Assets	5.3			2.7
Total Assets	531.2			508.5
LIABILITIES AND EQUITY
Current Liabilities	21.1			22.8
Noncurrent Liabilities	232			218.6
Equity	278.1			267.1
Total Liabilities and Equity	$ 531.2			508.5
Apple Blossom and Black Oak [Member] \| Variable Interest Entities [Member]
ASSETS
Current Assets				8.3
Net Property, Plant and Equipment				216.5
Other Noncurrent Assets				13.6
Total Assets				238.4
LIABILITIES AND EQUITY
Current Liabilities				4.5
Noncurrent Liabilities				5.4
Equity				228.5
Total Liabilities and Equity				238.4
Santa Rita East [Member] \| Variable Interest Entities [Member]
ASSETS
Current Assets				21.3
Net Property, Plant and Equipment				421.6
Other Noncurrent Assets				0.1
Total Assets				443
LIABILITIES AND EQUITY
Current Liabilities				9.6
Noncurrent Liabilities				7.3
Equity				426.1
Total Liabilities and Equity				443
Dry Lake Solar Project [Member] \| Variable Interest Entities [Member]
ASSETS
Current Assets				4
Net Property, Plant and Equipment				142.6
Other Noncurrent Assets				0.3
Total Assets				146.9
LIABILITIES AND EQUITY
Current Liabilities				1
Noncurrent Liabilities				0.7
Equity				145.2
Total Liabilities and Equity				$ 146.9

[1]Amount includes Assets Held for Sale on the balance sheet. See “Planned Disposition of the Competitive Contracted Renewables Portfolio” section of Note 6 for additional information.[2]Includes an intercompany item eliminated in consolidation of $12 million.[3] Includes an intercompany item eliminated in consolidation of $16 million . Includes an intercompany item eliminated in consolidation of $7 million . Includes an intercompany item eliminated in consolidation of $2 million . Includes an intercompany item eliminated in consolidation of $2 million

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Details) - USD ($) $ in Millions		3 Months Ended				6 Months Ended
		Jun. 30, 2023		Jun. 30, 2022		Jun. 30, 2023		Jun. 30, 2022		Dec. 31, 2022
Disaggregation of Revenue
Revenue from Contracts with Customers		$ 4,372.5		$ 4,639.7		$ 9,063.4		$ 9,232.3
Revenues		4,372.5		4,639.7		9,063.4		9,232.3
Revenue, Performance Obligation
Fixed Performance Obligations		403				403
Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		3,459.2		3,367.4		7,247.6		6,736.3
Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,536.1		1,540.9		3,363.3		3,292.3
Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,001		956.5		2,010.3		1,819.1
Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		850.9		804.3		1,733.9	[1]	1,500.2
Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		71.2		65.7		140.1		124.7
Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		940.5		1,077.3		1,917.6		2,022.3
Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		161.1		271.4		376.3		498.9
Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		350.6	[2]	363.3	[3]	677.8	[4]	676.2	[5]
Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		30	[6]	35.3	[7]	51.2	[1]	56.9	[8]
Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		398.8	[6]	407.3	[7]	812.3	[9]	790.3	[10]
Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		117.2	[11]	116.7	[12]	182.5	[13]	235.8	[14]
Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		4,516.9		4,561.4		9,347.7		8,994.4
Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(144.4)		78.3		(284.3)		237.9
Alternative [Member]
Disaggregation of Revenue
Revenues		(15.6)	[6],[15]	(57.4)	[7],[16]	(25.6)	[1],[17]	(63.2)	[8],[18]
Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		94.5		93.5		186.9		187.6
Revenues		(128.8)	[6]	135.7	[7],[19]	(258.7)	[1],[20]	301.1	[8],[21]
2023 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		43.6				43.6
2024-2025[Member]
Revenue, Performance Obligation
Fixed Performance Obligations		161.4				161.4
2026-2027 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		137.1				137.1
After 2027
Revenue, Performance Obligation
Fixed Performance Obligations		60.9				60.9
AEP Texas Inc. [Member]
Disaggregation of Revenue
Revenues		461.2		478.8		890.7		895.5
AEP Texas Inc. [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		1.3		0.8		2.5		1.7
Revenue Textuals
Affiliated Companies - Contracts with Customers		22.9				22.9				$ 11.9
AEP Texas Inc. [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		289.4		331.6		565		607.2
AEP Texas Inc. [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		144.9		174.9		275.6		316.8
AEP Texas Inc. [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		100.6		110.6		197.9		205.5
AEP Texas Inc. [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		35.2		36.6		74.5	[22]	67.2
AEP Texas Inc. [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		8.7		9.5		17		17.7
AEP Texas Inc. [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		163.1		143.8		309.4		276.9
AEP Texas Inc. [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[23]	0	[24]	0	[25]	0	[26]
AEP Texas Inc. [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		163.1	[27]	143.8	[28]	309.4	[29]	276.9	[30]
AEP Texas Inc. [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		10.7	[31]	5.6	[32]	20.4	[33]	14.9	[34]
AEP Texas Inc. [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		463.2		481		894.8		899
AEP Texas Inc. [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(2)		(2.2)		(4.1)		(3.5)
AEP Texas Inc. [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		(2)	[35],[36]	(2.2)	[37],[38]	(4.1)	[22],[39]	(3.5)	[40],[41]
AEP Texas Inc. [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0.5		1.1		1.1		2.2
Revenues		0	[36]	0	[38]	0	[22]	0	[41]
AEP Texas Inc. [Member] \| Short-term Contract with Customer [Member] \| Related Party
Revenue Textuals
Affiliated Companies - Contracts with Customers		0				0				0.1
AEP Transmission Co [Member]
Disaggregation of Revenue
Revenues		444.9		364.4		886.5		764.8
AEP Transmission Co [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		365.8		333.9		723.2		658.9
Revenue Textuals
Affiliated Companies - Contracts with Customers		179.4				179.4				119.5
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	[22]	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		444.7		406.1		883.4		806.4
AEP Transmission Co [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[23]	0	[24]	0	[25]	0	[26]
AEP Transmission Co [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		444.7	[27]	406.1	[28]	883.4	[29]	806.4	[30]
AEP Transmission Co [Member] \| Wholesale Transmission [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		357		330		706		653
AEP Transmission Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		4.1	[31]	0.2	[32]	7.8	[33]	(0.1)	[34]
AEP Transmission Co [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		448.8		406.3		891.2		806.3
AEP Transmission Co [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(3.9)		(41.9)		(4.7)		(41.5)
AEP Transmission Co [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		(3.9)	[35],[36]	(41.9)	[37],[38]	(4.7)	[22],[39]	(41.5)	[40],[41]
AEP Transmission Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenues		0	[36]	0	[38]	0	[22]	0	[41]
AEP Transmission Co [Member] \| Short-term Contract with Customer [Member] \| Related Party
Revenue Textuals
Affiliated Companies - Contracts with Customers		123.1				123.1				113.8
Appalachian Power Co [Member]
Disaggregation of Revenue
Revenues		826.5		773.6		1,814.2		1,680.9
Revenue, Performance Obligation
Fixed Performance Obligations		77.3				77.3
Appalachian Power Co [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		61.1		63.1		130.7		120
Revenue Textuals
Affiliated Companies - Contracts with Customers		121.5				121.5				94
Appalachian Power Co [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		706.1		647.9		1,559.9		1,434.2
Appalachian Power Co [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		324.8		313.2		795.3		771.2
Appalachian Power Co [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		163.6		152.6		334.9		306.5
Appalachian Power Co [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		192.5		161.9		378.3	[22]	315.7
Appalachian Power Co [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		25.2		20.2		51.4		40.8
Appalachian Power Co [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		108.1		104.3		229.7		201.6
Appalachian Power Co [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		64.2	[23]	63.5	[24]	144.4	[25]	119.7	[26]
Appalachian Power Co [Member] \| Wholesale Generation [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		38		42		85		78
Appalachian Power Co [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		43.9	[27]	40.8	[28]	85.3	[29]	81.9	[30]
Appalachian Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		11.8	[31]	20.6	[32]	24.8	[33]	44.9	[34]
Appalachian Power Co [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		826		772.8		1,814.4		1,680.7
Appalachian Power Co [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		0.5		0.8		(0.2)		0.2
Appalachian Power Co [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		0.5	[35],[36]	0.8	[37],[38]	(0.2)	[22],[39]	0.1	[40],[41]
Appalachian Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2.9		5.6		6.5		8.9
Revenues		0	[36]	0	[38]	0	[22]	0.1	[41]
Appalachian Power Co [Member] \| Short-term Contract with Customer [Member] \| Related Party
Revenue Textuals
Affiliated Companies - Contracts with Customers		68.1				68.1				64.5
Appalachian Power Co [Member] \| 2023 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		8.1				8.1
Appalachian Power Co [Member] \| 2024-2025[Member]
Revenue, Performance Obligation
Fixed Performance Obligations		32.2				32.2
Appalachian Power Co [Member] \| 2026-2027 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		25.4				25.4
Appalachian Power Co [Member] \| After 2027
Revenue, Performance Obligation
Fixed Performance Obligations		11.6				11.6
Indiana Michigan Power Co [Member]
Disaggregation of Revenue
Revenues		599.2		631		1,262.2		1,256.2
Revenue, Performance Obligation
Fixed Performance Obligations		24.3				24.3
Indiana Michigan Power Co [Member] \| Related Party
Revenue Textuals
Affiliated Companies - Contracts with Customers		113.3				113.3				104
Indiana Michigan Power Co [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		483.7		495		1,016.1		991.2
Indiana Michigan Power Co [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		185.2		195.2		424.8		427
Indiana Michigan Power Co [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		141.4		138.6		280.3		265.2
Indiana Michigan Power Co [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		155.9		160		308.5	[22]	296.5
Indiana Michigan Power Co [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1.2		1.2		2.5		2.5
Indiana Michigan Power Co [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		73.1		102.9		185.2		202.1
Indiana Michigan Power Co [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		63.5	[23]	94.2	[24]	167.5	[25]	184.6	[26]
Indiana Michigan Power Co [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		9.6	[27]	8.7	[28]	17.7	[29]	17.5	[30]
Indiana Michigan Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		45	[31]	25.8	[32]	66.4	[33]	55.7	[34]
Indiana Michigan Power Co [Member] \| Other Revenues [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		17
Indiana Michigan Power Co [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		601.8		623.7		1,267.7		1,249
Indiana Michigan Power Co [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(2.6)		7.3		(5.5)		7.2
Indiana Michigan Power Co [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		(2.6)	[35],[36]	7.3	[37],[38]	(5.5)	[22],[39]	7.3	[40],[41]
Indiana Michigan Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2.4		2.8		5.5		5.6
Revenues		0	[36]	0	[38]	0	[22]	(0.1)	[41]
Indiana Michigan Power Co [Member] \| Other Revenues [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers				19		35		29
Indiana Michigan Power Co [Member] \| Short-term Contract with Customer [Member] \| Related Party
Revenue Textuals
Affiliated Companies - Contracts with Customers		47.3				47.3				75.3
Indiana Michigan Power Co [Member] \| 2023 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		2.2				2.2
Indiana Michigan Power Co [Member] \| 2024-2025[Member]
Revenue, Performance Obligation
Fixed Performance Obligations		8.8				8.8
Indiana Michigan Power Co [Member] \| 2026-2027 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		8.8				8.8
Indiana Michigan Power Co [Member] \| After 2027
Revenue, Performance Obligation
Fixed Performance Obligations		4.5				4.5
Ohio Power Co [Member]
Disaggregation of Revenue
Revenues		879.1		822.9		1,913.7		1,652.9
Ohio Power Co [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		8.2		3.9		15.8		7.6
Revenue Textuals
Affiliated Companies - Contracts with Customers		126.5				126.5				100.9
Ohio Power Co [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		807.5		737.2		1,789.4		1,496.6
Ohio Power Co [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		429.3		386.7		955.3		845.4
Ohio Power Co [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		257.8		221.1		536.3		415.8
Ohio Power Co [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		116.8		126		290.4	[22]	228.7
Ohio Power Co [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		3.6		3.4		7.4		6.7
Ohio Power Co [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		21		21.1		38.9		42.9
Ohio Power Co [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[23]	0	[24]	0	[25]	0	[26]
Ohio Power Co [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		21	[27]	21.1	[28]	38.9	[29]	42.9	[30]
Ohio Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		45.5	[31]	60.2	[32]	78.7	[33]	104.8	[34]
Ohio Power Co [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		874		818.5		1,907		1,644.3
Ohio Power Co [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		5.1		4.4		6.7		8.6
Ohio Power Co [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		(0.9)	[35],[36]	(2.4)	[37],[38]	(10.4)	[22],[39]	(4.5)	[40],[41]
Ohio Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2.1		1.8		7.3		3.9
Revenues		6	[36]	6.8	[38]	17.1	[22]	13.1	[41]
Ohio Power Co [Member] \| Short-term Contract with Customer [Member] \| Related Party
Revenue Textuals
Affiliated Companies - Contracts with Customers		68.6				68.6				49.9
Public Service Co Of Oklahoma [Member]
Disaggregation of Revenue
Revenues		474.7		442.9		891.7		830.5
Public Service Co Of Oklahoma [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		0.1		0.8		0.8		1.4
Revenue Textuals
Affiliated Companies - Contracts with Customers		67.1				67.1				52.2
Public Service Co Of Oklahoma [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		454.3		424.7		856.8		787.9
Public Service Co Of Oklahoma [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		186.5		185.2		357.4		351.1
Public Service Co Of Oklahoma [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		131.7		121.2		240.8		218.7
Public Service Co Of Oklahoma [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		107.8		92.5		206.1	[22]	171.1
Public Service Co Of Oklahoma [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		28.3		25.8		52.5		47
Public Service Co Of Oklahoma [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		14.2		9.4		26.4		28.5
Public Service Co Of Oklahoma [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		4.3	[23]	0.3	[24]	5.2	[25]	9.8	[26]
Public Service Co Of Oklahoma [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		9.9	[27]	9.1	[28]	21.2	[29]	18.7	[30]
Public Service Co Of Oklahoma [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		7.2	[31]	9.6	[32]	9.5	[33]	15	[34]
Public Service Co Of Oklahoma [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		475.7		443.7		892.7		831.4
Public Service Co Of Oklahoma [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(1)		(0.8)		(1)		(0.9)
Public Service Co Of Oklahoma [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		(1)	[35],[36]	(0.8)	[37],[38]	(1)	[22],[39]	(0.9)	[40],[41]
Public Service Co Of Oklahoma [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2.2		2.1		3.7		2.7
Revenues		0	[36]	0	[38]	0	[22]	0	[41]
Public Service Co Of Oklahoma [Member] \| Short-term Contract with Customer [Member] \| Related Party
Revenue Textuals
Affiliated Companies - Contracts with Customers		30.6				30.6				18.8
Southwestern Electric Power Co [Member]
Disaggregation of Revenue
Revenues		537.8		536.6		1,053.7		1,031.4
Southwestern Electric Power Co [Member] \| Related Party
Revenue Textuals
Affiliated Companies - Contracts with Customers		63.6				63.6				65.4
Southwestern Electric Power Co [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		452.1		436.1		878.3		829.6
Southwestern Electric Power Co [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		185.1		188.6		361		364.5
Southwestern Electric Power Co [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		153.8		146		297.3		276.5
Southwestern Electric Power Co [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		110.6		97.1		214.8	[22]	181.8
Southwestern Electric Power Co [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2.6		4.4		5.2		6.8
Southwestern Electric Power Co [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		82.2		96.7		164.7		193.1
Southwestern Electric Power Co [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		43.9	[23]	57.4	[24]	83.5	[25]	118.6	[26]
Southwestern Electric Power Co [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		38.3	[27]	39.3	[28]	81.2	[29]	74.5	[30]
Southwestern Electric Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		7	[31]	6	[32]	14.9	[33]	11.3	[34]
Southwestern Electric Power Co [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		541.3		538.8		1,057.9		1,034
Southwestern Electric Power Co [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(3.5)		(2.2)		(4.2)		(2.6)
Southwestern Electric Power Co [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		(3.5)	[35],[36]	(2.2)	[37],[38]	(4.2)	[22],[39]	(2.6)	[40],[41]
Southwestern Electric Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0.8		0.4		1.3		1
Revenues		0	[36]	0	[38]	0	[22]	0	[41]
Southwestern Electric Power Co [Member] \| Short-term Contract with Customer [Member] \| Related Party
Revenue Textuals
Affiliated Companies - Contracts with Customers		42.4				42.4				$ 19.1
Consolidation Eliminations [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Revenues		(464.2)		(373.3)		(907.9)		(765.5)
Consolidation Eliminations [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		(464.2)		(373.3)		(907.9)		(765.5)
Consolidation Eliminations [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(0.1)		0		(0.3)		(0.4)
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		(0.1)		0		(0.3)	[1]	(0.4)
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		(415.9)		(337.1)		(817.7)		(708.7)
Consolidation Eliminations [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0.1		0.1		0.1		0.1
Consolidation Eliminations [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(402.8)	[2]	(332)	[3]	(804.6)	[4]	(693.8)	[5]
Consolidation Eliminations [Member] \| Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(3.1)	[6]	(2.9)	[7]	(3.2)	[1]	(3.7)	[8]
Consolidation Eliminations [Member] \| Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(10.1)	[6]	(2.3)	[7]	(10)	[9]	(11.3)	[10]
Consolidation Eliminations [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(39.9)	[11]	(21.1)	[12]	(83.6)	[13]	(39.7)	[14]
Consolidation Eliminations [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(455.9)		(358.2)		(901.6)		(748.8)
Consolidation Eliminations [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(8.3)		(15.1)		(6.3)		(16.7)
Consolidation Eliminations [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		(6.3)	[6],[15]	(13.1)	[7],[16]	(3.4)	[1],[17]	(11.8)	[8],[18]
Consolidation Eliminations [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenues		(2)	[6]	(2)	[7],[19]	(2.9)	[1],[20]	(4.9)	[8],[21]
Consolidation Eliminations [Member] \| AEP Transmission Co [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Revenues		0		0		0		0
Consolidation Eliminations [Member] \| AEP Transmission Co [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Vertically Integrated Utilities [Member]
Disaggregation of Revenue
Revenues		2,674.5		2,648.5		5,532.3		5,335.9
Vertically Integrated Utilities [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		45.5		53.5		87		94.1
Vertically Integrated Utilities [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,362.5		2,298.8		4,893.4		4,632.9
Vertically Integrated Utilities [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		962		979.3		2,132.4		2,130.1
Vertically Integrated Utilities [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		642.7		624.8		1,276.1		1,197.7
Vertically Integrated Utilities [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		698.9		641.8		1,369.2	[1]	1,204.8
Vertically Integrated Utilities [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		58.9		52.9		115.7		100.3
Vertically Integrated Utilities [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		254.9		297.1		552.4		589.6
Vertically Integrated Utilities [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		141.4		188.3		324.2		375.5
Vertically Integrated Utilities [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		113.5	[2]	108.8	[3]	228.2	[4]	214.1	[5]
Vertically Integrated Utilities [Member] \| Wholesale Transmission [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers						80
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	[6]	0	[7]	0	[9]	0	[10]
Vertically Integrated Utilities [Member] \| Retail, Trading and Marketing Revenues [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers				5
Vertically Integrated Utilities [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		61.9	[11]	49.2	[12]	94.5	[13]	110.8	[14]
Vertically Integrated Utilities [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,679.3		2,645.1		5,540.3		5,333.3
Vertically Integrated Utilities [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(4.8)		3.4		(8)		2.6
Vertically Integrated Utilities [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		(4.9)	[6],[15]	3.3	[7],[16]	(8)	[1],[17]	2.5	[8],[18]
Vertically Integrated Utilities [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenues		0.1	[6]	0.1	[7],[19]	0	[1],[20]	0.1	[8],[21]
Transmission And Distribution Utilities [Member]
Disaggregation of Revenue
Revenues		1,340.2		1,301.6		2,804.4		2,548.4
Transmission And Distribution Utilities [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		9.4		4.8		18.3		9.4
Transmission And Distribution Utilities [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,096.8		1,068.6		2,354.5		2,103.8
Transmission And Distribution Utilities [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		574.1		561.6		1,230.9		1,162.2
Transmission And Distribution Utilities [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		358.3		331.7		734.2		621.4
Transmission And Distribution Utilities [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		152.1		162.5		365	[1]	295.8
Transmission And Distribution Utilities [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		12.3		12.8		24.4		24.4
Transmission And Distribution Utilities [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		184.1		164.9		348.3		319.8
Transmission And Distribution Utilities [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Transmission And Distribution Utilities [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		184.1	[2]	164.9	[3]	348.3	[4]	319.8	[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	[6]	0	[7]	0	[9]	0	[10]
Transmission And Distribution Utilities [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		56.1	[11]	65.9	[12]	98.9	[13]	119.7	[14]
Transmission And Distribution Utilities [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,337		1,299.4		2,801.7		2,543.3
Transmission And Distribution Utilities [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		3.2		2.2		2.7		5.1
Transmission And Distribution Utilities [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		(2.9)	[6],[15]	(4.6)	[7],[16]	(14.5)	[1],[17]	(8)	[8],[18]
Transmission And Distribution Utilities [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenues		6.1	[6]	6.8	[7],[19]	17.2	[1],[20]	13.1	[8],[21]
AEP Transmission Holdco [Member]
Disaggregation of Revenue
Revenues		458.6		378.8		914.1		790.2
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	[1]	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		455.8		421.6		905.9		836.1
AEP Transmission Holdco [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
AEP Transmission Holdco [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		455.8	[2]	421.6	[3]	905.9	[4]	836.1	[5]
AEP Transmission Holdco [Member] \| Wholesale Transmission [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		360		334		712		661
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	[6]	0	[7]	0	[9]	0	[10]
AEP Transmission Holdco [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		4.3	[11]	0.2	[12]	7.9	[13]	0	[14]
AEP Transmission Holdco [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		460.1		421.8		913.8		836.1
AEP Transmission Holdco [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(1.5)		(43)		0.3		(45.9)
AEP Transmission Holdco [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		(1.5)	[6],[15]	(43)	[7],[16]	0.3	[1],[17]	(45.9)	[8],[18]
AEP Transmission Holdco [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenues		0	[6]	0	[7],[19]	0	[1],[20]	0	[8],[21]
Generation And Marketing [Member]
Disaggregation of Revenue
Revenues		331.4		659.6		658.4		1,278.9
Generation And Marketing [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		13.2		5.2		13.3		15
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	[1]	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		460.4		529.5		927.8		981
Generation And Marketing [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		19.6		83		52		123.3
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		33.1	[6]	38.2	[7]	54.4	[1]	60.6	[8]
Generation And Marketing [Member] \| Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		407.7	[6]	408.3	[7]	821.4	[9]	797.1	[10]
Generation And Marketing [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		6.2	[11]	1.6	[12]	6.8	[13]	10.2	[14]
Generation And Marketing [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		466.6		531.1		934.6		991.2
Generation And Marketing [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(135.2)		128.5		(276.2)		287.7
Generation And Marketing [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		0	[6],[15]	0	[7],[16]	0	[1],[17]	0	[8],[18]
Generation And Marketing [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenues		(135.2)	[6],[42]	128.5	[7],[19]	(276.2)	[1],[20]	287.7	[8],[21]
Generation And Marketing [Member] \| Retail, Trading and Marketing \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers						10		11
Other Segments [Member]
Disaggregation of Revenue
Revenues	[43]	32		24.5		62.1		44.4
Other Segments [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers	[43]	25.8		10.1		53.6		19.3
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	[1]	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		1.2		1.3		0.9		4.5
Other Segments [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		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		1.2	[6]	1.3	[7]	0.9	[9]	4.5	[10]
Other Segments [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		28.6	[11]	20.9	[12]	58	[13]	34.8	[14]
Other Segments [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		29.8		22.2		58.9		39.3
Other Segments [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		2.2		2.3		3.2		5.1
Other Segments [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		0	[6],[15]	0	[7],[16]	0	[1],[17]	0	[8],[18]
Other Segments [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers	[43]	6.2		14.4		8.5		25.1
Revenues		2.2	[6]	$ 2.3	[7],[19]	3.2	[1],[20]	5.1	[8],[21]
Corporate and Other \| Other Revenues [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		$ 26
Corporate and Other \| Other Revenues [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers						$ 55		$ 19

[1]Amounts include affiliated and nonaffiliated revenues.[2]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $360 million. The remaining affiliated amounts were immaterial.[3]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $334 million. The remaining affiliated amounts were immaterial.[4]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $712 million. The affiliated revenue for Vertically Integrated Utilities was $80 million. The remaining affiliated amounts were immaterial.[5]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $661 million. The remaining affiliated amounts were immaterial.[6]Amounts include affiliated and nonaffiliated revenues.[7]Amounts include affiliated and nonaffiliated revenues[8]Amounts include affiliated and nonaffiliated revenues.[9]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $10 million. The remaining affiliated amounts were immaterial.[10]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $11 million. The remaining affiliated amounts were immaterial.[11]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $26 million. The remaining affiliated amounts were immaterial.[12]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Vertically Integrated Utilities was $5 million. The remaining affiliated amounts were immaterial.[13]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $55 million. The remaining affiliated amounts were immaterial.[14]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $19 million. The remaining affiliated amounts were immaterial.[15]Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues.[16]Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues.[17]Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues.[18]Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues.[19]Generation & Marketing includes economic hedge activity.[20]Generation & Marketing includes economic hedge activity.[21]Generation & Marketing includes economic hedge activity.[22]Amounts include affiliated and nonaffiliated revenues.[23]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $38 million primarily related to the PPA with KGPCo.[24]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $42 million primarily related to the PPA with KGPCo.[25]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $85 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial.[26]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $78 million primarily relating to the PPA with KGPCo.[27]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $357 million. The remaining affiliated amounts were immaterial.[28]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $330 million. The remaining affiliated amounts were immaterial.[29]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $706 million. The remaining affiliated amounts were immaterial.[30]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $653 million. The remaining affiliated amounts were immaterial.[31]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.[32]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $19 million primarily related to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial.[33]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $35 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial.[34]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $29 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial.[35]Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues.[36]Amounts include affiliated and nonaffiliated revenues.[37]Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues.[38]Amounts include affiliated and nonaffiliated revenues.[39]Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues.[40]Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues.[41]Amounts include affiliated and nonaffiliated revenues.[42]Generation & Marketing includes economic hedge activity.[43]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.