American Electric Power (AEP) 10-Q30 Apr 242024 Q1 Quarterly reportFinancial data

Company Profile

Document and Entity Information

Document and Entity Information - shares	3 Months Ended
Document and Entity Information - shares	Mar. 31, 2024	Apr. 30, 2024
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2024
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		527,121,759
Entity Central Index Key	0000004904
Amendment Flag	false
Document Fiscal Year Focus	2024
Document Fiscal Period Focus	Q1
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

Consolidated Statements of Inco

Consolidated Statements of Income - USD ($) $ in Millions		3 Months Ended
Consolidated Statements of Income - USD ($) $ in Millions		Mar. 31, 2024		Mar. 31, 2023
Revenues
Revenue from Contracts with Customers		$ 5,025.7		$ 4,690.9
TOTAL REVENUES		5,025.7		4,690.9
Expenses
Other Operation		762.3		680
Maintenance		317.5		317.3
Depreciation and Amortization		787.1		775.5
Taxes Other Than Income Taxes		410.4		394.9
TOTAL EXPENSES		3,853.1		3,986.1
OPERATING INCOME (LOSS)		1,172.6		704.8
Other Income (Expense):
Other Income		13.6		14.7
Allowance for Equity Funds Used During Construction		43.6		31.3
Non-Service Cost Components of Net Periodic Benefit Cost		45.1		55.5
Interest Expense		(435.6)		(415.7)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS		839.3		390.6
Income Tax Expense (Benefit)		(141.9)		10.4
Equity Earnings (Loss) of Unconsolidated Subsidiaries		24.5		20.2
Net Income (Loss)		1,005.7		400.4
Net Income (Loss) Attributable to Noncontrolling Interests		2.6		3.4
Earnings Attributable to Common Shareholders		$ 1,003.1		$ 397
Earnings Per Share
Weighted Average Number of Basic AEP Common Shares Outstanding		526,552,036		514,176,648
Total Basic Earnings Per Share Attributable to AEP Common Shareholders		$ 1.91		$ 0.77
Weighted Average Number of Diluted AEP Common Shares Outstanding		527,596,395		515,598,090
Total Diluted Earnings Per Share Attributable to AEP Common Shareholders		$ 1.90		$ 0.77
Common Stock, Dividends Per Share, Declared		$ 0.88		$ 0.83
Cash Flow Hedges, Tax		$ (1.6)		$ (40.5)
Amortization of Pension and OPEB Deferred Costs, Tax		(0.2)		(4.3)
Competitive Contracted Renewable Portfolio
Expenses
Asset Impairments and Other Related Charges		0		112
Related Party
Revenues
Revenue from Contracts with Customers		0		0
Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers		2,901.2		2,816.3
Transmission and Distribution Utilities [Member]
Revenues
Revenue from Contracts with Customers		1,483.2		1,455.3
Generation and Marketing [Member]
Revenues
Revenue from Contracts with Customers		515.9		326.9
Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		125.4		92.4
TOTAL REVENUES		(60.8)	[1],[2]	(129.9)	[3],[4]
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold		1,575.8		1,706.4
AEP Texas Inc. [Member]
Revenues
TOTAL REVENUES		466.4		429.5
Expenses
Other Operation		140.8		146.9
Maintenance		22.1		24.4
Depreciation and Amortization		116.7		111
Taxes Other Than Income Taxes		40		43.5
TOTAL EXPENSES		319.6		325.8
OPERATING INCOME (LOSS)		146.8		103.7
Other Income (Expense):
Interest Income		0.5		0.4
Allowance for Equity Funds Used During Construction		8.6		6.3
Non-Service Cost Components of Net Periodic Benefit Cost		3.7		4.8
Interest Expense		(61.5)		(56.9)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS		98.1		58.3
Income Tax Expense (Benefit)		18.4		10.7
Net Income (Loss)		79.7		47.6
Earnings Per Share
Cash Flow Hedges, Tax		1		0
Amortization of Pension and OPEB Deferred Costs, Tax		0		(0.1)
AEP Texas Inc. [Member] \| Related Party
Revenues
Revenue from Contracts with Customers		1.3		1.2
AEP Texas Inc. [Member] \| Transmission and Distribution Utilities [Member]
Revenues
Revenue from Contracts with Customers		463		427.7
AEP Texas Inc. [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		2.1		0.6
TOTAL REVENUES		0	[5]	0	[6]
AEP Transmission Co [Member]
Revenues
Provision for Refund Affiliated		(6)		(4.8)
Provision for Refund-Nonaffiliated		(1.4)		(1)
TOTAL REVENUES		482.8		441.6
Expenses
Other Operation		29.9		29
Maintenance		5.3		4.9
Depreciation and Amortization		105.9		95.2
Taxes Other Than Income Taxes		73.4		74.8
TOTAL EXPENSES		214.5		203.9
OPERATING INCOME (LOSS)		268.3		237.7
Other Income (Expense):
Interest Income		1.9		1.5
Allowance for Equity Funds Used During Construction		17.9		16.4
Interest Expense		(54.8)		(45.2)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS		233.3		210.4
Income Tax Expense (Benefit)		52.1		47.7
Net Income (Loss)		181.2		162.7
Earnings Per Share
Revenues from Related Parties, Net of Provisions for Refund		383.4		352.6
AEP Transmission Co [Member] \| Related Party
Revenues
Revenue from Contracts with Customers		389.4		357.4
AEP Transmission Co [Member] \| AEPTCo Parent [Member]
Revenues
Revenue from Contracts with Customers		0		0
TOTAL REVENUES		0		0
Other Income (Expense):
Net Income (Loss)	[7]	(0.5)		1.1
AEP Transmission Co [Member] \| AEPTCo Parent [Member] \| Related Party
Revenues
Revenue from Contracts with Customers		0		0
AEP Transmission Co [Member] \| State Transcos [Member]
Revenues
TOTAL REVENUES		482.8		441.6
Other Income (Expense):
Net Income (Loss)		181.7		161.6
AEP Transmission Co [Member] \| State Transcos [Member] \| Related Party
Revenues
Revenue from Contracts with Customers		383.4		352.6
AEP Transmission Co [Member] \| Transmission [Member]
Revenues
Revenue from Contracts with Customers		98.4		90
Earnings Per Share
Revenue from Contract with Customers, Net of Provisions for Refund, Including Assessed Tax		97		89
AEP Transmission Co [Member] \| Transmission [Member] \| State Transcos [Member]
Revenues
Revenue from Contracts with Customers		97		89
AEP Transmission Co [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		2.4		0
TOTAL REVENUES		0	[5]	0	[6]
Earnings Per Share
Revenue from Contract with Customers, Net of Provisions for Refund, Including Assessed Tax		2.4
AEP Transmission Co [Member] \| Other Revenues [Member] \| AEPTCo Parent [Member]
Revenues
Revenue from Contracts with Customers		0
AEP Transmission Co [Member] \| Other Revenues [Member] \| State Transcos [Member]
Revenues
Revenue from Contracts with Customers		2.4
Appalachian Power Co [Member]
Revenues
TOTAL REVENUES		1,093		987.7
Expenses
Other Operation		212.6		191.8
Maintenance		80		73.1
Depreciation and Amortization		149.8		143
Taxes Other Than Income Taxes		46		41.8
TOTAL EXPENSES		885.2		789.4
OPERATING INCOME (LOSS)		207.8		198.3
Other Income (Expense):
Interest Income		0.8		0.6
Allowance for Equity Funds Used During Construction		2.9		2.4
Non-Service Cost Components of Net Periodic Benefit Cost		7.1		8.1
Interest Expense		(68.1)		(65.3)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS		150.5		144.1
Income Tax Expense (Benefit)		14		31.6
Net Income (Loss)		136.5		112.5
Earnings Per Share
Cash Flow Hedges, Tax		(0.1)		(0.1)
Amortization of Pension and OPEB Deferred Costs, Tax		(0.1)		(0.2)
Appalachian Power Co [Member] \| Related Party
Revenues
Revenue from Contracts with Customers		63.1		69.6
Appalachian Power Co [Member] \| Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers		1,024.3		914.5
Appalachian Power Co [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		5.6		3.6
TOTAL REVENUES		0.1	[5]	0	[6]
Appalachian Power Co [Member] \| Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold		396.8		339.7
Indiana Michigan Power Co [Member]
Revenues
TOTAL REVENUES		667.4		663
Expenses
Purchased Electricity from AEP Affiliates		61.5		45.1
Other Operation		178.2		169.7
Maintenance		52.4		58.6
Depreciation and Amortization		108.3		125.2
Taxes Other Than Income Taxes		23.3		19.5
TOTAL EXPENSES		546.3		517.3
OPERATING INCOME (LOSS)		121.1		145.7
Other Income (Expense):
Other Income		3.2		0.6
Allowance for Equity Funds Used During Construction		3.3		0.5
Non-Service Cost Components of Net Periodic Benefit Cost		6.7		8
Interest Expense		(26.2)		(33.2)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS		104.8		121.1
Income Tax Expense (Benefit)		(40.2)		18.3
Net Income (Loss)		145		102.8
Earnings Per Share
Cash Flow Hedges, Tax		0		(0.2)
Amortization of Pension and OPEB Deferred Costs, Tax		0		(0.5)
Indiana Michigan Power Co [Member] \| Related Party
Revenues
Revenue from Contracts with Customers		1.8		1.2
Indiana Michigan Power Co [Member] \| Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers		647.8		642.8
Indiana Michigan Power Co [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		2.8		3.1
TOTAL REVENUES		(25.9)	[5]	0	[6]
Indiana Michigan Power Co [Member] \| Other Revenues [Member] \| Related Party
Revenues
Revenue from Contracts with Customers		15		15.9
Indiana Michigan Power Co [Member] \| Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold		122.6		99.2
Ohio Power Co [Member]
Revenues
TOTAL REVENUES		1,023.8		1,034.6
Expenses
Purchased Electricity from AEP Affiliates		46.6		0
Other Operation		293.2		273.8
Maintenance		61.3		44.3
Depreciation and Amortization		105.8		75.2
Taxes Other Than Income Taxes		150.8		135.3
TOTAL EXPENSES		916.4		921.2
OPERATING INCOME (LOSS)		107.4		113.4
Other Income (Expense):
Other Income		0		0.1
Allowance for Equity Funds Used During Construction		5.5		2.8
Non-Service Cost Components of Net Periodic Benefit Cost		5.5		6.5
Interest Expense		(34.6)		(31.1)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS		83.8		91.7
Income Tax Expense (Benefit)		13.2		13.7
Net Income (Loss)		70.6		78
Ohio Power Co [Member] \| Related Party
Revenues
Revenue from Contracts with Customers		5.7		7.6
Ohio Power Co [Member] \| Transmission and Distribution Utilities [Member]
Revenues
Revenue from Contracts with Customers		1,015.4		1,021.8
Ohio Power Co [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		2.7		5.2
TOTAL REVENUES		7.9	[5]	11.1	[6]
Ohio Power Co [Member] \| Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold		258.7		392.6
Public Service Co Of Oklahoma [Member]
Revenues
TOTAL REVENUES		387.8		417
Expenses
Other Operation		96.6		92.1
Maintenance		28.1		28.8
Depreciation and Amortization		67.4		61.1
Taxes Other Than Income Taxes		17		17.3
TOTAL EXPENSES		358		399.4
OPERATING INCOME (LOSS)		29.8		17.6
Other Income (Expense):
Interest Income		0.2		1
Allowance for Equity Funds Used During Construction		2.4		1.5
Non-Service Cost Components of Net Periodic Benefit Cost		2.9		3.6
Interest Expense		(16.8)		(25.2)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS		18.5		(1.5)
Income Tax Expense (Benefit)		(53.5)		0.8
Net Income (Loss)		72		(2.3)
Earnings Per Share
Cash Flow Hedges, Tax		0		(0.4)
Public Service Co Of Oklahoma [Member] \| Related Party
Revenues
Revenue from Contracts with Customers		3.5		0.7
Public Service Co Of Oklahoma [Member] \| Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers		378.1		414.8
Public Service Co Of Oklahoma [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		6.2		1.5
TOTAL REVENUES		0	[5]	0	[6]
Public Service Co Of Oklahoma [Member] \| Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold		148.9		200.1
Southwestern Electric Power Co [Member]
Revenues
TOTAL REVENUES		516.2		515.9
Expenses
Other Operation		112.9		99.2
Maintenance		37.2		37.7
Depreciation and Amortization		78.7		80.4
Taxes Other Than Income Taxes		34.2		36.1
TOTAL EXPENSES		447.6		462.7
OPERATING INCOME (LOSS)		68.6		53.2
Other Income (Expense):
Interest Income		4		5.4
Allowance for Equity Funds Used During Construction		3.4		0.5
Non-Service Cost Components of Net Periodic Benefit Cost		2.6		3.4
Interest Expense		(13.5)		(25)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS		65.1		37.5
Income Tax Expense (Benefit)		(144.1)		(4)
Equity Earnings (Loss) of Unconsolidated Subsidiaries		0.4		0.3
Net Income (Loss)		209.6		41.8
Net Income (Loss) Attributable to Noncontrolling Interests		1.5		1.2
Earnings Attributable to Common Shareholders		208.1		40.6
Earnings Per Share
Cash Flow Hedges, Tax		0		0.1
Amortization of Pension and OPEB Deferred Costs, Tax		0		(0.1)
Southwestern Electric Power Co [Member] \| Related Party
Revenues
Revenue from Contracts with Customers		12.1		11.7
Southwestern Electric Power Co [Member] \| Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers		500.2		503.7
Southwestern Electric Power Co [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		3.9		0.5
TOTAL REVENUES		0	[5]	0	[6]
Southwestern Electric Power Co [Member] \| Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold		184.6		209.3
Reconciling Adjustments [Member]
Revenues
Revenue from Contracts with Customers		0		0
TOTAL REVENUES		(526)		(443.7)
Other Income (Expense):
Net Income (Loss)		0		0
Reconciling Adjustments [Member] \| Related Party
Revenues
Revenue from Contracts with Customers	[8]	(526)		(443.7)
Reconciling Adjustments [Member] \| Other Revenues [Member]
Revenues
TOTAL REVENUES		8	[1],[2]	(0.9)	[3],[4]
Reconciling Adjustments [Member] \| AEP Transmission Co [Member]
Revenues
Revenue from Contracts with Customers		0		0
TOTAL REVENUES		0		0
Other Income (Expense):
Net Income (Loss)		0		0
Reconciling Adjustments [Member] \| AEP Transmission Co [Member] \| Related Party
Revenues
Revenue from Contracts with Customers		0		$ 0
Reconciling Adjustments [Member] \| AEP Transmission Co [Member] \| Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		$ 0

[1] Amounts include affiliated and nonaffiliated revenues. Generation & Marketing includes economic hedge activity. Generation & Marketing includes economic hedge activity. Amounts include affiliated and nonaffiliated revenues. Amounts include affiliated and nonaffiliated revenues. Includes the elimination of AEPTCo Parent’s equity earnings in the State Transcos. Represents inter-segment revenues.

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income (Loss) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Net Income (Loss)	$ 1,005.7	$ 400.4
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	(6.2)	(152.4)
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(0.6)	(16.1)
Reclassifications of KPCo Pension and OPEB Regulatory Assets, Net of Tax	0	16.7
Other Comprehensive Income (Loss), Net of Tax, Total	(6.8)	(151.8)
TOTAL COMPREHENSIVE INCOME (LOSS)	998.9	248.6
Total Comprehensive Income (Loss) Attributable to Noncontrolling Interest	2.6	3.4
TOTAL COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	996.3	245.2
Cash Flow Hedges, Tax	(1.6)	(40.5)
Amortization of Pension and OPEB Deferred Costs, Tax	(0.2)	(4.3)
Reclassifications of KPCo Pension and OPEB Regulatory Assets, Tax	0	4.4
Appalachian Power Co [Member]
Net Income (Loss)	136.5	112.5
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	(0.2)	(0.2)
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(0.3)	(0.8)
Other Comprehensive Income (Loss), Net of Tax, Total	(0.5)	(1)
TOTAL COMPREHENSIVE INCOME (LOSS)	136	111.5
Cash Flow Hedges, Tax	(0.1)	(0.1)
Amortization of Pension and OPEB Deferred Costs, Tax	(0.1)	(0.2)
AEP Texas Inc. [Member]
Net Income (Loss)	79.7	47.6
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	3.9	0
Amortization of Pension and OPEB Deferred Costs, Net of Tax	0	(0.6)
Other Comprehensive Income (Loss), Net of Tax, Total	3.9	(0.6)
TOTAL COMPREHENSIVE INCOME (LOSS)	83.6	47
Cash Flow Hedges, Tax	1	0
Amortization of Pension and OPEB Deferred Costs, Tax	0	(0.1)
Indiana Michigan Power Co [Member]
Net Income (Loss)	145	102.8
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	0.1	(0.7)
Amortization of Pension and OPEB Deferred Costs, Net of Tax	0	(1.9)
Other Comprehensive Income (Loss), Net of Tax, Total	0.1	(2.6)
TOTAL COMPREHENSIVE INCOME (LOSS)	145.1	100.2
Cash Flow Hedges, Tax	0	(0.2)
Amortization of Pension and OPEB Deferred Costs, Tax	0	(0.5)
Ohio Power Co [Member]
Net Income (Loss)	70.6	78
Public Service Co Of Oklahoma [Member]
Net Income (Loss)	72	(2.3)
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	0	(1.5)
Other Comprehensive Income (Loss), Net of Tax, Total		(1.5)
TOTAL COMPREHENSIVE INCOME (LOSS)	72	(3.8)
Cash Flow Hedges, Tax	0	(0.4)
Southwestern Electric Power Co [Member]
Net Income (Loss)	209.6	41.8
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	(0.1)	0.4
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(0.1)	(0.3)
Other Comprehensive Income (Loss), Net of Tax, Total	(0.2)	0.1
TOTAL COMPREHENSIVE INCOME (LOSS)	209.4	41.9
Total Comprehensive Income (Loss) Attributable to Noncontrolling Interest	1.5	1.2
TOTAL COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	207.9	40.7
Cash Flow Hedges, Tax	0	0.1
Amortization of Pension and OPEB Deferred Costs, Tax	0	(0.1)
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
OTHER COMPREHENSIVE INCOME
Other Comprehensive Income (Loss), Net of Tax, Total	$ (0.6)	$ 0.6

Condensed Consolidated Statemen

Condensed Consolidated Statements of Changes in Equity - USD ($) $ in Millions	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] Reconciling Adjustments [Member] Other Revenues [Member]	AEP Transmission Co [Member] State Transcos [Member]	AEP Transmission Co [Member] State Transcos [Member] Transmission [Member]	AEP Transmission Co [Member] State Transcos [Member] Other Revenues [Member]	AEP Transmission Co [Member] AEPTCo Parent [Member]		AEP Transmission Co [Member] AEPTCo Parent [Member] Other Revenues [Member]	Indiana Michigan Power Co [Member]	Indiana Michigan Power Co [Member] Vertically Integrated Utilities [Member]	Indiana Michigan Power Co [Member] Other Revenues [Member]		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] 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 (Loss) [Member]	Accumulated Other Comprehensive Income (Loss) [Member] Appalachian Power Co [Member]	Accumulated Other Comprehensive Income (Loss) [Member] AEP Texas Inc. [Member]	Accumulated Other Comprehensive Income (Loss) [Member] Indiana Michigan Power Co [Member]	Accumulated Other Comprehensive Income (Loss) [Member] Public Service Co Of Oklahoma [Member]	Accumulated Other Comprehensive Income (Loss) [Member] Southwestern Electric Power Co [Member]	Noncontrolling Interests [Member]	Noncontrolling Interests [Member] Southwestern Electric Power Co [Member]
Beginning Balance at Dec. 31, 2022																																				$ 5,873																																					$ 3,022.3									$ 2,850.7
Beginning Balance at Dec. 31, 2022	$ 24,122.4																											$ 4,975.4				$ 3,904.3																$ 3,008.3				$ 3,088.1				$ 2,419.1				$ 3,674.8				$ 3,413.1	$ 260.4	$ 56.6	$ 321.2	$ 157.2	$ 0.1	$ 8,051	$ 1,828.7	$ 1,558.2		$ 988.8	$ 837.8	$ 1,042.6	$ 1,442.2	$ 12,345.6		$ 2,891.1	$ 2,354.7		$ 1,963.2	$ 1,929.1	$ 1,218	$ 2,236	$ 83.7	$ (4.8)	$ (8.6)	$ (0.3)	$ 1.3	$ (4.2)	$ 229	$ 0.7
Beginning Balance, Shares at Dec. 31, 2022																																																																525,100,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of Common Stock, Value	41.1																																																															$ 5.1						36
Issuance of Common Stock, Shares																																																																800,000
Common Stock Dividends	(431.8)																																																																													(428.8)	[1]
Common Stock Dividends																																																(31.2)								(17.5)																											(31.2)		(17.5)
Common Stock Dividends																																																												(1.5)																																	(3)	(1.5)
Other Changes in Equity	(12.5)																																																																					(12.7)																							0.2
Capital Contribution from Member																																100				25																50								50												100	25		50		50
Dividends Paid on Common Stock																																				(55)												(31.2)								(17.5)				0																						(55)
Net Income (Loss)	397																																																											40.6																		397								40.6
Net Income (Loss) Attributable to Noncontrolling Interests	3.4																																																											1.2																																	3.4	1.2
Net Income (Loss)	400.4						$ 0			$ (156.4)				$ (13.5)				$ 182.4		$ 125.7				$ 262.2				112.5				47.6				162.7				$ 0		$ 161.6			$ 1.1	[3]		102.8				78				(2.3)				41.8																				112.5	47.6	162.7	102.8	78	(2.3)
Other Comprehensive Income (Loss)	(151.8)																											(1)				(0.6)																(2.6)								(1.5)				0.1																											(151.8)	(1)	(0.6)	(2.6)	(1.5)	0.1
Ending Balance at Mar. 31, 2023																																				6,005.7																																					3,047.3									2,958.4
Ending Balance at Mar. 31, 2023	$ 23,967.8																											5,086.9				4,051.3																3,077.3				3,216.1				2,397.8				3,765.2				$ 3,418.2	260.4	56.6	321.2	157.2	0.1	8,074.3	1,828.7	1,658.2		988.8	887.8	1,042.6	1,492.2	12,313.8		3,003.6	2,402.3		2,034.8	2,007.1	1,198.2	2,276.6	(68.1)	(5.8)	(9.2)	(2.9)	(0.2)	(4.1)	229.6	0.4
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contributions from Parent																												0				100				25																50								50
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
Revenue from Contracts with Customers	$ 4,690.9	$ 2,816.3	$ 1,455.3	$ 326.9	$ 92.4		0				$ 326.9					$ 2.3	[2]		$ 90.1		$ 1,455.3				$ 2,816.3				$ 914.5	$ 3.6			$ 427.7	$ 0.6			$ 90	$ 0		0			$ 89		0				$ 642.8	$ 3.1			$ 1,021.8	$ 5.2			$ 414.8	$ 1.5			$ 503.7	$ 0.5
Revenues	4,690.9				(129.9)	[4],[5]	(443.7)	$ (0.9)	[4],[5]	327		$ (141)	[4],[5]	30.1		1	[4],[5]	455.5		1,464.2		$ 11.1	[4],[5]	2,857.8		$ (0.1)	[4],[5]	987.7		0	[6]	429.5		0	[6]	441.6		0	[6]	0		441.6			0			663		0	[6]	1,034.6		11.1	[6]	417		0	[6]	515.9		0	[6]
Revenues from Related Parties, Net of Provisions for Refund																																				352.6
Revenue from Contract with Customers, Net of Provisions for Refund, Including Assessed Tax																																					89
Beginning Balance at Dec. 31, 2023																																				6,333.3																																					3,043.4									3,289.9
Beginning Balance at Dec. 31, 2023	$ 25,285.9																											5,276.7				4,796.1																3,140.2				3,571.3				$ 2,570.6				3,770.4				$ 3,427.9	260.4	56.6	321.2	157.2	0.1	9,073.9	1,834.5	2,079.6		997.6	1,012.8	1,039.3	1,492.2	12,800.4		3,185.5	2,725.1		2,086.6	2,237.3	1,374.3	2,281.3	(55.5)	(3.7)	(8.6)	(0.6)	(0.2)	(3.4)	39.2	0.2
Beginning Balance, Shares at Dec. 31, 2023	527,369,157																																																							10,482,000								527,400,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of Common Stock, Value	$ 40.6																																																															$ 5.4						35.2
Issuance of Common Stock, Shares																																																																800,000
Common Stock Dividends	(466.9)																																																																													(465.5)	[7]
Common Stock Dividends																																																(37.5)								$ (35)				(50)																							(37.5)		(35)	(50)
Common Stock Dividends																																																												(1.4)																																	(1.4)	(1.4)
Other Changes in Equity	(14.8)																																																																					(14.8)
Capital Contribution from Member																																				25																																					25
Dividends Paid on Common Stock																																				(40)												(37.5)								(35)				(50)																						(40)
Net Income (Loss)	1,003.1																																																											208.1																		1,003.1								208.1
Net Income (Loss) Attributable to Noncontrolling Interests	2.6																																																											1.5																																	2.6	1.5
Net Income (Loss)	1,005.7						0			137.6				(54.3)				209.8		150.3				562.3				136.5				79.7				181.2				0		181.7			(0.5)	[3]		145				70.6				72				209.6																				136.5	79.7	181.2	145	70.6	72
Other Comprehensive Income (Loss)	(6.8)																											(0.5)				3.9																0.1												(0.2)																											(6.8)	(0.5)	3.9	0.1		(0.2)
Ending Balance at Mar. 31, 2024																																				6,499.5																																					$ 3,068.4									$ 3,431.1
Ending Balance at Mar. 31, 2024	$ 25,843.7																											5,512.7				4,879.7																3,247.8				3,641.9				$ 2,607.6				3,928.4				$ 3,433.3	$ 260.4	$ 56.6	$ 321.2	$ 157.2	$ 0.1	$ 9,094.3	1,934.5	$ 2,079.6		$ 997.6	$ 1,012.8	$ 1,039.3	$ 1,492.2	$ 13,338		$ 3,322	$ 2,804.8		$ 2,194.1	$ 2,307.9	$ 1,411.3	$ 2,439.4	$ (62.3)	$ (4.2)	$ (4.7)	$ (0.5)	$ (0.2)	$ (3.6)	$ 40.4	$ 0.3
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contributions from Parent																												100				0				25																0								0											$ 100
Ending Balance, Shares at Mar. 31, 2024	528,199,306																																																							10,482,000								528,200,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Dividends Per Share, Declared	$ 0.88
Revenue from Contracts with Customers	$ 5,025.7	$ 2,901.2	$ 1,483.2	$ 515.9	125.4		0				$ 515.9					14.9	[2]		$ 110.5		$ 1,483.2				$ 2,901.2				$ 1,024.3	5.6			$ 463	2.1			98.4	2.4		0	$ 0		$ 97	$ 2.4	0		$ 0		$ 647.8	2.8			$ 1,015.4	2.7			$ 378.1	6.2			$ 500.2	3.9
Revenues	$ 5,025.7				$ (60.8)	[8],[9]	$ (526)	$ 8	[8],[9]	$ 563.5		$ (42.9)	[8],[9]	$ 52.8		$ (8.1)	[8],[9]	$ 497.3		$ 1,490.2		$ 7.9	[8],[9]	$ 2,947.9		$ (25.7)	[8],[9]	$ 1,093		$ 0.1	[10]	$ 466.4		$ 0	[10]	482.8		0	[10]	$ 0		$ 482.8			$ 0			$ 667.4		$ (25.9)	[10]	$ 1,023.8		$ 7.9	[10]	$ 387.8		$ 0	[10]	$ 516.2		$ 0	[10]
Revenues from Related Parties, Net of Provisions for Refund																																				$ 383.4
Revenue from Contract with Customers, Net of Provisions for Refund, Including Assessed Tax																																					$ 97	$ 2.4

[1]Cash dividends declared per AEP common share were $0.83.[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. Includes the elimination of AEPTCo Parent’s equity earnings in the State Transcos. Generation & Marketing includes economic hedge activity. Amounts include affiliated and nonaffiliated revenues. Amounts include affiliated and nonaffiliated revenues. Generation & Marketing includes economic hedge activity. Amounts include affiliated and nonaffiliated revenues.

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Millions		Mar. 31, 2024	Dec. 31, 2023
Current Assets
Cash and Cash Equivalents		$ 230.7	$ 330.1
Restricted Cash		51.1	48.9
Other Temporary Investments		217	214.3
Accounts Receivable:
Customers		1,000	1,029.9
Accrued Unbilled Revenues		220.9	179.5
Pledged Accounts Receivable - AEP Credit		1,206.8	1,249.4
Miscellaneous		47.2	48.7
Allowance for Uncollectible Accounts		(59.6)	(60.1)
Total Accounts Receivable		2,415.3	2,447.4
Fuel		749.9	853.7
Materials and Supplies		1,020.4	1,025.8
Risk Management Assets		152.7	217.5
Accrued Tax Benefits		89.4	156.2
Regulatory Asset for Under-Recovered Fuel Costs		550.3	514
Prepayments and Other Current Assets		372.8	274.2
TOTAL CURRENT ASSETS		5,849.6	6,082.1
Property, Plant and Equipment
Generation		24,404.1	24,329.5
Transmission		36,253.1	35,934.1
Distribution		29,476.3	28,989.9
Other Property, Plant and Equipment		6,557.2	6,484.9
Construction Work in Progress		6,142.1	5,508
Total Property, Plant and Equipment		102,832.8	101,246.4
Accumulated Depreciation and Amortization		25,036.8	24,553
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		77,796	76,693.4
Other Noncurrent Assets
Regulatory Assets		5,034.1	5,092.4
Securitized Assets		309.7	336.3
Spent Nuclear Fuel and Decommissioning Trusts		4,112.6	3,860.2
Goodwill		52.5	52.5
Long-term Risk Management Assets		314.4	321.2
Operating Lease Assets		603	620.2
Deferred Charges and Other Noncurrent Assets		3,672.7	3,625.7
TOTAL OTHER NONCURRENT ASSETS		14,099	13,908.5
TOTAL ASSETS		97,744.6	96,684
Current Liabilities
Accounts Payable		1,990.9	2,032.5
Short-term Debt:
Securitized Debt for Receivables - AEP Credit	[1]	900	888
Other Short-term Debt		2,837.6	1,942.2
Total Short-term Debt		3,737.6	2,830.2
Long-term Debt Due Within One Year		1,198.6	2,490.5
Risk Management Liabilities		184.4	229.6
Customer Deposits		436.2	423.7
Accrued Taxes		1,675.6	1,800.1
Accrued Interest		507.3	410.2
Obligations Under Operating Leases		107.1	115.7
Other Current Liabilities		1,068.9	1,251.1
TOTAL CURRENT LIABILITIES		10,906.6	11,583.6
Noncurrent Liabilities
Long-term Debt		38,637.3	37,652.7
Deferred Income Tax Liabilities, Net		9,662.1	9,415.7
Long-term Risk Management Liabilities		279.5	241.8
Regulatory Liabilities and Deferred Investment Tax Credits		8,089.4	8,182.4
Asset Retirement Obligations		2,972.9	2,972.5
Employee Benefits and Pension Obligations		230.8	241.7
Obligations Under Operating Leases		509.3	519.4
Deferred Credits and Other Noncurrent Liabilities		561.4	545.8
TOTAL NONCURRENT LIABILITIES		60,942.7	59,772
TOTAL LIABILITIES		71,849.3	71,355.6
Rate Matters
Commitments and Contingencies
Contingently Reedemable Performance Share Awards		51.6	42.5
Total Mezzanine Equity		51.6	42.5
Equity
Common Stock		3,433.3	3,427.9
Paid-in Capital		9,094.3	9,073.9
Retained Earnings		13,338	12,800.4
Accumulated Other Comprehensive Income (Loss)		(62.3)	(55.5)
TOTAL COMMON SHAREHOLDER'S EQUITY		25,803.3	25,246.7
Noncontrolling Interests		40.4	39.2
TOTAL EQUITY		25,843.7	25,285.9
TOTAL LIABILITIES AND EQUITY		$ 97,744.6	$ 96,684
Common Stock, No Par Value		$ 6.50	$ 6.50
Common Stock, Shares Authorized		600,000,000	600,000,000
Common Stock, Shares, Issued		528,199,306	527,369,157
Treasury Stock, Shares		1,184,572	1,184,572
Commodity [Member]
Equity
Cross Default Provisions Maximum Third Party Obligation Amount		$ 50
Subsidiaries [Member]
Current Assets
Restricted Cash		51.1	$ 48.9
Other Temporary Investments		206.1	205
Short-term Debt:
Long-term Debt Due Within One Year		201.5	207.2
Noncurrent Liabilities
Long-term Debt		528.9	556.3
AEP Texas Inc. [Member]
Current Assets
Cash and Cash Equivalents		0.1	0.1
Restricted Cash		42.7	34
Accounts Receivable:
Customers		167.8	176.5
Accrued Unbilled Revenues		85.2	82.3
Miscellaneous		0.7	0.8
Allowance for Uncollectible Accounts		(4.2)	(4.9)
Total Accounts Receivable		270.7	278.5
Materials and Supplies		194	190.4
Prepayments and Other Current Assets		10.6	10
TOTAL CURRENT ASSETS		525.1	520.1
Property, Plant and Equipment
Transmission		6,896.6	6,812.6
Distribution		5,903.8	5,798.8
Other Property, Plant and Equipment		1,148.8	1,145.9
Construction Work in Progress		1,062.7	904.6
Total Property, Plant and Equipment		15,011.9	14,661.9
Accumulated Depreciation and Amortization		1,932.5	1,887.9
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		13,079.4	12,774
Other Noncurrent Assets
Regulatory Assets		317.4	315.3
Securitized Assets		183.1	202.9
Deferred Charges and Other Noncurrent Assets		262.5	178.4
TOTAL OTHER NONCURRENT ASSETS		763	696.6
TOTAL ASSETS		14,367.5	13,990.7
Current Liabilities
Accounts Payable		253.5	192.3
Short-term Debt:
Long-term Debt Due Within One Year		96.2	96
Accrued Taxes		139.5	99.1
Accrued Interest		81.5	49.2
Obligations Under Operating Leases		24.7	28.7
Other Current Liabilities		147.7	152.7
TOTAL CURRENT LIABILITIES		1,041.9	749.4
Noncurrent Liabilities
Long-term Debt		5,782.5	5,793.8
Deferred Income Tax Liabilities, Net		1,238.7	1,227.8
Regulatory Liabilities and Deferred Investment Tax Credits		1,261.2	1,261.4
Obligations Under Operating Leases		50.1	50.9
Deferred Credits and Other Noncurrent Liabilities		113.4	111.3
TOTAL NONCURRENT LIABILITIES		8,445.9	8,445.2
TOTAL LIABILITIES		9,487.8	9,194.6
Rate Matters
Commitments and Contingencies
Equity
Paid-in Capital		2,079.6	2,079.6
Retained Earnings		2,804.8	2,725.1
Accumulated Other Comprehensive Income (Loss)		(4.7)	(8.6)
TOTAL EQUITY		4,879.7	4,796.1
TOTAL LIABILITIES AND EQUITY		14,367.5	13,990.7
AEP Texas Inc. [Member] \| Related Party
Current Assets
Advances to Affiliates		7	7.1
Accounts Receivable:
Affiliated Companies - Contracts with Customers		21.2	23.8
Current Liabilities
Accounts Payable		30.9	27.7
AEP Texas Inc. [Member] \| AEP Texas Transition Funding and Restoration Funding [Member]
Current Assets
Restricted Cash		42.7	34
Other Noncurrent Assets
Securitized Assets		183.1	202.9
Short-term Debt:
Long-term Debt Due Within One Year		96.2	95.9
Accrued Interest		1.7	2
Noncurrent Liabilities
Long-term Debt		114	125.9
AEP Transmission Co [Member]
Current Assets
Cash and Cash Equivalents		0	0
Accounts Receivable:
Customers		80.6	82.2
Total Accounts Receivable		211.7	207.7
Prepayments and Other Current Assets		11.2	4
TOTAL CURRENT ASSETS		520.9	278.8
Property, Plant and Equipment
Transmission		13,832.4	13,723.9
Other Property, Plant and Equipment		503.5	501.4
Construction Work in Progress		1,805	1,563.7
Total Property, Plant and Equipment		16,140.9	15,789
Accumulated Depreciation and Amortization		1,362.7	1,291.3
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		14,778.2	14,497.7
Other Noncurrent Assets
Regulatory Assets		2.4	3.1
Deferred Property Taxes		250.1	286.4
Deferred Charges and Other Noncurrent Assets		7.4	6.5
TOTAL OTHER NONCURRENT ASSETS		259.9	296
TOTAL ASSETS		15,559	15,072.5
Current Liabilities
Accounts Payable		289.6	274.7
Short-term Debt:
Long-term Debt Due Within One Year		145	95
Accrued Taxes		505.3	568.6
Accrued Interest		56.8	39.6
Obligations Under Operating Leases		1.3	1.3
Other Current Liabilities		20.4	24.7
TOTAL CURRENT LIABILITIES		1,167.9	1,286.1
Noncurrent Liabilities
Long-term Debt		5,715.7	5,319.4
Deferred Income Tax Liabilities, Net		1,175.4	1,147.7
Regulatory Liabilities and Deferred Investment Tax Credits		809.4	783.7
Obligations Under Operating Leases		1.2	1.4
Deferred Credits and Other Noncurrent Liabilities		189.9	200.9
TOTAL NONCURRENT LIABILITIES		7,891.6	7,453.1
TOTAL LIABILITIES		9,059.5	8,739.2
Rate Matters
Commitments and Contingencies
Equity
Paid-in Captial		3,068.4	3,043.4
Retained Earnings		3,431.1	3,289.9
TOTAL MEMBER'S EQUITY		6,499.5	6,333.3
TOTAL LIABILITIES AND EQUITY		15,559	15,072.5
AEP Transmission Co [Member] \| Related Party
Current Assets
Advances to Affiliates		298	67.1
Accounts Receivable:
Affiliated Companies - Contracts with Customers		131.1	125.5
Current Liabilities
Accounts Payable		120.7	107.9
Appalachian Power Co [Member]
Current Assets
Cash and Cash Equivalents		7.6	5
Restricted Cash		8.4	14.9
Accounts Receivable:
Customers		191.1	170.3
Accrued Unbilled Revenues		59.8	70.8
Miscellaneous		0.5	0.6
Allowance for Uncollectible Accounts		(2.3)	(2)
Total Accounts Receivable		350	338.5
Fuel		293.6	315
Materials and Supplies		139.8	148.4
Risk Management Assets		8.7	22.4
Regulatory Asset for Under-Recovered Fuel Costs		148.4	155.4
Prepayments and Other Current Assets		25.9	40.5
TOTAL CURRENT ASSETS		1,019.8	1,059
Property, Plant and Equipment
Generation		7,065.3	7,041.3
Transmission		4,747.5	4,711.8
Distribution		5,238.5	5,176.6
Other Property, Plant and Equipment		1,023.1	981.3
Construction Work in Progress		754.5	709.2
Total Property, Plant and Equipment		18,828.9	18,620.2
Accumulated Depreciation and Amortization		5,776	5,688.7
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		13,052.9	12,931.5
Other Noncurrent Assets
Regulatory Assets		1,107.4	1,155.1
Securitized Assets		126.7	133.4
Employee Benefits and Pension Assets		176.3	171.7
Operating Lease Assets		72	73.7
Deferred Charges and Other Noncurrent Assets		197.3	187.5
TOTAL OTHER NONCURRENT ASSETS		1,679.7	1,721.4
TOTAL ASSETS		15,752.4	15,711.9
Current Liabilities
Accounts Payable		286.7	280.4
Short-term Debt:
Long-term Debt Due Within One Year		153.3	538.8
Risk Management Liabilities		18.4	15.9
Customer Deposits		81.4	80
Accrued Taxes		146.9	117.6
Accrued Interest		83	58.9
Obligations Under Operating Leases		14.3	14.6
Other Current Liabilities		132.3	118.8
TOTAL CURRENT LIABILITIES		1,023.3	1,685.9
Noncurrent Liabilities
Long-term Debt		5,517.6	5,049.5
Deferred Income Tax Liabilities, Net		2,019.8	2,011.9
Regulatory Liabilities and Deferred Investment Tax Credits		1,082.5	1,081.9
Asset Retirement Obligations		441.5	442.5
Employee Benefits and Pension Obligations		31.6	32.8
Obligations Under Operating Leases		58.3	59.8
Deferred Credits and Other Noncurrent Liabilities		65.1	70.9
TOTAL NONCURRENT LIABILITIES		9,216.4	8,749.3
TOTAL LIABILITIES		10,239.7	10,435.2
Rate Matters
Commitments and Contingencies
Equity
Common Stock		260.4	260.4
Paid-in Capital		1,934.5	1,834.5
Retained Earnings		3,322	3,185.5
Accumulated Other Comprehensive Income (Loss)		(4.2)	(3.7)
TOTAL EQUITY		5,512.7	5,276.7
TOTAL LIABILITIES AND EQUITY		$ 15,752.4	$ 15,711.9
Common Stock, No Par Value		$ 0	$ 0
Common Stock, Shares Authorized		30,000,000	30,000,000
Common Stock, Shares, Outstanding		13,499,500	13,499,500
Appalachian Power Co [Member] \| Related Party
Current Assets
Advances to Affiliates		$ 37.4	$ 18.9
Accounts Receivable:
Affiliated Companies - Contracts with Customers		100.9	98.8
Current Liabilities
Accounts Payable		107	121.3
Indiana Michigan Power Co [Member]
Current Assets
Cash and Cash Equivalents		5.5	2.1
Accounts Receivable:
Customers		51.1	66.9
Accrued Unbilled Revenues		0.2	0.2
Miscellaneous		4.2	8.2
Total Accounts Receivable		142.9	140.3
Fuel		72.8	88.1
Materials and Supplies		202.2	208.2
Risk Management Assets		11.2	27.8
Regulatory Asset for Under-Recovered Fuel Costs		3.8	14.8
Prepayments and Other Current Assets		41.6	46.7
TOTAL CURRENT ASSETS		480	528
Property, Plant and Equipment
Generation		5,664.8	5,646.8
Transmission		1,917	1,906.4
Distribution		3,322.7	3,254
Other Property, Plant and Equipment		891.3	898.5
Construction Work in Progress		314.4	301.7
Total Property, Plant and Equipment		12,110.2	12,007.4
Accumulated Depreciation and Amortization		4,459	4,378.4
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		7,651.2	7,629
Other Noncurrent Assets
Regulatory Assets		498.2	406.3
Spent Nuclear Fuel and Decommissioning Trusts		4,112.6	3,860.2
Operating Lease Assets		51.2	53.8
Deferred Charges and Other Noncurrent Assets		318.3	330.7
TOTAL OTHER NONCURRENT ASSETS		4,980.3	4,651
TOTAL ASSETS		13,111.5	12,808
Current Liabilities
Accounts Payable		182.1	225.8
Short-term Debt:
Long-term Debt Due Within One Year		76.9	83.7
Customer Deposits		52.1	72.2
Accrued Taxes		133.5	104.7
Accrued Interest		38.1	41.3
Obligations Under Operating Leases		14.9	16.8
Regulatory Liability for Over-Recovered Fuel Costs		22.3	23.2
Other Current Liabilities		74.3	91.9
TOTAL CURRENT LIABILITIES		783.3	830.2
Noncurrent Liabilities
Long-term Debt		3,401.6	3,415.7
Deferred Income Tax Liabilities, Net		1,190.6	1,169.9
Regulatory Liabilities and Deferred Investment Tax Credits		2,262.3	2,052.3
Asset Retirement Obligations		2,123	2,104.3
Obligations Under Operating Leases		37.1	37.7
Deferred Credits and Other Noncurrent Liabilities		65.8	57.7
TOTAL NONCURRENT LIABILITIES		9,080.4	8,837.6
TOTAL LIABILITIES		9,863.7	9,667.8
Rate Matters
Commitments and Contingencies
Equity
Common Stock		56.6	56.6
Paid-in Capital		997.6	997.6
Retained Earnings		2,194.1	2,086.6
Accumulated Other Comprehensive Income (Loss)		(0.5)	(0.6)
TOTAL EQUITY		3,247.8	3,140.2
TOTAL LIABILITIES AND EQUITY		$ 13,111.5	$ 12,808
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
Accounts Receivable:
Affiliated Companies - Contracts with Customers		$ 87.4	$ 65
Current Liabilities
Accounts Payable		115.9	107.3
Indiana Michigan Power Co [Member] \| DCC Fuel [Member]
Short-term Debt:
Long-term Debt Due Within One Year		74.8	81.4
Ohio Power Co [Member]
Current Assets
Cash and Cash Equivalents		12.5	6.4
Accounts Receivable:
Customers		70.8	39.2
Miscellaneous		9.9	2.3
Total Accounts Receivable		212.2	170.7
Materials and Supplies		171.6	175
Renewable Energy Credits		13.4	8.9
Prepayments and Other Current Assets		18.9	16.8
TOTAL CURRENT ASSETS		428.6	377.8
Property, Plant and Equipment
Transmission		3,438.6	3,395.1
Distribution		6,948	6,839.4
Other Property, Plant and Equipment		1,136.1	1,125
Construction Work in Progress		710.4	654
Total Property, Plant and Equipment		12,233.1	12,013.5
Accumulated Depreciation and Amortization		2,765.7	2,713.6
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		9,467.4	9,299.9
Other Noncurrent Assets
Regulatory Assets		416.6	455
Operating Lease Assets		67.4	69.9
Deferred Charges and Other Noncurrent Assets		547.8	641.1
TOTAL OTHER NONCURRENT ASSETS		1,031.8	1,166
TOTAL ASSETS		10,927.8	10,843.7
Current Liabilities
Accounts Payable		305.2	320.7
Short-term Debt:
Risk Management Liabilities		6	6.8
Customer Deposits		76.1	62
Accrued Taxes		605.5	763.3
Obligations Under Operating Leases		13.1	13.5
Other Current Liabilities		176.3	183.3
TOTAL CURRENT LIABILITIES		1,631.9	1,614.3
Noncurrent Liabilities
Long-term Debt		3,367.4	3,366.8
Deferred Income Tax Liabilities, Net		1,158.9	1,152.7
Long-term Risk Management Liabilities		35	43.9
Regulatory Liabilities and Deferred Investment Tax Credits		1,004.5	1,003.6
Obligations Under Operating Leases		54.5	56.7
Deferred Credits and Other Noncurrent Liabilities		33.7	34.4
TOTAL NONCURRENT LIABILITIES		5,654	5,658.1
TOTAL LIABILITIES		7,285.9	7,272.4
Rate Matters
Commitments and Contingencies
Equity
Common Stock		321.2	321.2
Paid-in Capital		1,012.8	1,012.8
Retained Earnings		2,307.9	2,237.3
TOTAL EQUITY		3,641.9	3,571.3
TOTAL LIABILITIES AND EQUITY		$ 10,927.8	$ 10,843.7
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		$ 131.5	$ 129.2
Current Liabilities
Accounts Payable		154.5	154.2
Public Service Co Of Oklahoma [Member]
Current Assets
Cash and Cash Equivalents		3.5	2.5
Accounts Receivable:
Customers		74.1	107.6
Miscellaneous		1	0.8
Total Accounts Receivable		144.2	139.4
Fuel		32.5	33.7
Materials and Supplies		111	106.9
Risk Management Assets		7.9	19
Accrued Tax Benefits		43.7	31
Regulatory Asset for Under-Recovered Fuel Costs		155.8	118.3
Prepayments and Other Current Assets		34.8	18.7
TOTAL CURRENT ASSETS		533.4	469.5
Property, Plant and Equipment
Generation		2,704.8	2,695.5
Transmission		1,240	1,228.3
Distribution		3,513	3,450.8
Other Property, Plant and Equipment		514.6	505.9
Construction Work in Progress		336.9	313.7
Total Property, Plant and Equipment		8,309.3	8,194.2
Accumulated Depreciation and Amortization		2,119.7	2,081.9
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		6,189.6	6,112.3
Other Noncurrent Assets
Regulatory Assets		533.1	522.7
Employee Benefits and Pension Assets		69.6	68.4
Operating Lease Assets		111.1	112.8
Deferred Charges and Other Noncurrent Assets		92.9	49.2
TOTAL OTHER NONCURRENT ASSETS		806.7	753.1
TOTAL ASSETS		7,529.7	7,334.9
Current Liabilities
Accounts Payable		138.5	159.3
Short-term Debt:
Long-term Debt Due Within One Year		125.6	0.6
Risk Management Liabilities		28.5	28.9
Customer Deposits		82.2	81.4
Accrued Taxes		67.3	30.7
Accrued Interest		26.3	30.7
Obligations Under Operating Leases		10.7	10.1
Other Current Liabilities		54.3	106.2
TOTAL CURRENT LIABILITIES		857.8	559
Noncurrent Liabilities
Long-term Debt		2,259.3	2,384
Deferred Income Tax Liabilities, Net		881.6	831.2
Regulatory Liabilities and Deferred Investment Tax Credits		701.6	765.6
Asset Retirement Obligations		85	83.9
Obligations Under Operating Leases		104.7	106.8
Deferred Credits and Other Noncurrent Liabilities		32.1	33.8
TOTAL NONCURRENT LIABILITIES		4,064.3	4,205.3
TOTAL LIABILITIES		4,922.1	4,764.3
Rate Matters
Commitments and Contingencies
Equity
Common Stock		157.2	157.2
Paid-in Capital		1,039.3	1,039.3
Retained Earnings		1,411.3	1,374.3
Accumulated Other Comprehensive Income (Loss)		(0.2)	(0.2)
TOTAL EQUITY		2,607.6	2,570.6
TOTAL LIABILITIES AND EQUITY		$ 7,529.7	$ 7,334.9
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		$ 69.1	$ 31
Current Liabilities
Accounts Payable		59.8	56.7
Southwestern Electric Power Co [Member]
Current Assets
Cash and Cash Equivalents		3.8	2.4
Accounts Receivable:
Customers		32.7	39
Miscellaneous		10.3	8.3
Total Accounts Receivable		104.2	94.5
Fuel		103.4	113.8
Materials and Supplies		84.5	88.4
Accrued Tax Benefits		31.2	28.4
Regulatory Asset for Under-Recovered Fuel Costs		166.3	170.8
Prepayments and Other Current Assets		52.4	40.8
TOTAL CURRENT ASSETS		548.1	541.3
Property, Plant and Equipment
Generation		4,790	4,790.7
Transmission		2,681.1	2,660.6
Distribution		2,881.8	2,824.1
Other Property, Plant and Equipment		819.2	814.4
Construction Work in Progress		644.4	555.8
Total Property, Plant and Equipment		11,816.5	11,645.6
Accumulated Depreciation and Amortization		3,149.8	3,087.2
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		8,666.7	8,558.4
Other Noncurrent Assets
Regulatory Assets		1,138.2	1,131.8
Deferred Charges and Other Noncurrent Assets		395	326.1
TOTAL OTHER NONCURRENT ASSETS		1,533.2	1,457.9
TOTAL ASSETS		10,748	10,557.6
Current Liabilities
Accounts Payable		185.3	198.9
Short-term Debt:
Other Short-term Debt		5.4	4.3
Customer Deposits		74.1	72.5
Accrued Taxes		128.5	58.7
Accrued Interest		37.4	39.9
Obligations Under Operating Leases		8.8	9
Other Current Liabilities		108	169
TOTAL CURRENT LIABILITIES		851.3	686.9
Noncurrent Liabilities
Long-term Debt		3,647.6	3,646.9
Deferred Income Tax Liabilities, Net		1,254.2	1,179.3
Regulatory Liabilities and Deferred Investment Tax Credits		566.9	756.1
Asset Retirement Obligations		240.3	258.6
Employee Benefits and Pension Obligations		43.8	43.1
Obligations Under Operating Leases		120.8	122.5
Deferred Credits and Other Noncurrent Liabilities		94.7	93.8
TOTAL NONCURRENT LIABILITIES		5,968.3	6,100.3
TOTAL LIABILITIES		6,819.6	6,787.2
Rate Matters
Commitments and Contingencies
Equity
Common Stock		0.1	0.1
Paid-in Capital		1,492.2	1,492.2
Retained Earnings		2,439.4	2,281.3
Accumulated Other Comprehensive Income (Loss)		(3.6)	(3.4)
TOTAL COMMON SHAREHOLDER'S EQUITY		3,928.1	3,770.2
Noncontrolling Interests		0.3	0.2
TOTAL EQUITY		3,928.4	3,770.4
TOTAL LIABILITIES AND EQUITY		$ 10,748	$ 10,557.6
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		$ 2.3	$ 2.2
Accounts Receivable:
Affiliated Companies - Contracts with Customers		61.2	47.2
Current Liabilities
Accounts Payable		49.3	45.9
Southwestern Electric Power Co [Member] \| Sabine Mining Co [Member]
Accounts Receivable:
Materials and Supplies		3.2	3.9
Property, Plant and Equipment
Other Property, Plant and Equipment		179.9	182.7
Accumulated Depreciation and Amortization		$ 179.9	$ 182.7

[1] 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 - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Operating Activities
Net Income (Loss)	$ 1,005.7	$ 400.4
Adjustments to Reconcile Net Income (Loss) to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	787.1	775.5
Deferred Income Taxes	(113.3)	68
Allowance for Equity Funds Used During Construction	(43.6)	(31.3)
Mark-to-Market of Risk Management Contracts	40.9	(82)
Property Taxes	(89.2)	(101.6)
Deferred Fuel Over/Under-Recovery, Net	43.4	128
Change in Other Noncurrent Assets	(74.5)	(96)
Change in Other Noncurrent Liabilities	61.8	(58.7)
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	34.9	348.4
Fuel, Materials and Supplies	104.3	(115.9)
Accounts Payable	(99.5)	(255.9)
Accrued Taxes, Net	(57.7)	(150.9)
Other Current Assets	(91.3)	(94.6)
Other Current Liabilities	(66.8)	(127.6)
Net Cash Flows from (Used for) Operating Activities	1,442.2	717.8
Investing Activities
Construction Expenditures	(1,761.7)	(2,090.1)
Purchases of Investment Securities	(590)	(537.3)
Sales of Investment Securities	572.5	517.6
Acquisitions of Nuclear Fuel	(33.7)	(1.7)
Proceeds from Sale of Equity Method Investments	114	0
Other Investing Activities	29.6	12
Net Cash Flows from (Used for) Investing Activities	(1,669.3)	(2,245.2)
Financing Activities
Issuance of Common Stock	40.6	41.1
Issuance of Long-term Debt	859.9	2,847.3
Issuance of Short-term Debt with Original Maturities greater than 90 Days	376.6	97.4
Change in Short-term Debt with Original Maturities less than 90 Days, Net	840.9	(433.7)
Retirement of Long-term Debt	(1,162.2)	(519.5)
Redemption of Short-term Debt with Original Maturities Greater than 90 Days	(310.1)	(153.8)
Principal Payments for Finance Leases Obligations	(17)	(26.8)
Dividends Paid on Common Stock	(466.9)	(431.8)
Other Financing Activities	(31.9)	(55.8)
Net Cash Flows from (Used for) Financing Activities	129.9	1,364.4
Net Increase (Decrease) in Cash and Cash Equivalents	(97.2)	(163)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	379	556.5
Cash and Cash Equivalents at Beginning of Period	330.1
Cash, Cash Equivalents and Restricted Cash at End of Period	281.8	393.5
Cash and Cash Equivalents at End of Period	230.7
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	368.3	311.9
Net Cash Paid (Received) for Income Taxes	16.1	15.8
Cash Received from Sale of Transferable Tax Credits	(62)	0
Noncash Acquisitions Under Finance Leases	7	12.5
Construction Expenditures Included in Current Liabilities as of March 31,	837	1,076.1
Forward Equity Purchase Contract Included in Current and Noncurrent Liabilities as of September 30,	14.8	12.5
Renewable Energy Facilities
Investing Activities
Acquisitions of Renewable Energy Facilities	0	(145.7)
Competitive Contracted Renewable Portfolio
Adjustments to Reconcile Net Income (Loss) to Net Cash Flows from (Used for) Operating Activities:
Loss on the Expected/Completed Sale	0	112
AEP Texas Inc. [Member]
Operating Activities
Net Income (Loss)	79.7	47.6
Adjustments to Reconcile Net Income (Loss) to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	116.7	111
Deferred Income Taxes	6.6	6.4
Allowance for Equity Funds Used During Construction	(8.6)	(6.3)
Mark-to-Market of Risk Management Contracts	(0.2)	0.4
Property Taxes	(84.3)	(88.8)
Change in Other Noncurrent Assets	(17.2)	(18.3)
Change in Other Noncurrent Liabilities	3	(0.8)
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	7.8	24.6
Fuel, Materials and Supplies	(3.6)	(1.1)
Accounts Payable	11.6	3.6
Accrued Taxes, Net	42.6	44.5
Accrued Interest	32.3	23.9
Other Current Assets	1.4	0.9
Other Current Liabilities	(20)	(10.9)
Net Cash Flows from (Used for) Operating Activities	167.8	136.7
Investing Activities
Construction Expenditures	(331.2)	(450.4)
Change in Advances to Affiliates, Net	0.1	0.1
Other Investing Activities	21.1	7.3
Net Cash Flows from (Used for) Investing Activities	(310)	(443)
Financing Activities
Capital Contributions from Parent	0	100
Change in Advances from Affiliates, Net	164.2	354.3
Retirement of Long-term Debt	(11.9)	(136.7)
Principal Payments for Finance Leases Obligations	(1.8)	(1.8)
Other Financing Activities	0.4	0.3
Net Cash Flows from (Used for) Financing Activities	150.9	316.1
Net Increase (Decrease) in Cash and Cash Equivalents	8.7	9.8
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	34.1	32.8
Cash and Cash Equivalents at Beginning of Period	0.1
Cash, Cash Equivalents and Restricted Cash at End of Period	42.8	42.6
Cash and Cash Equivalents at End of Period	0.1
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	26.9	31.6
Noncash Acquisitions Under Finance Leases	1.1	1.8
Construction Expenditures Included in Current Liabilities as of March 31,	158.3	177.5
AEP Texas Inc. [Member] \| Retained Earnings [Member]
Operating Activities
Net Income (Loss)	79.7	47.6
AEP Transmission Co [Member]
Operating Activities
Net Income (Loss)	181.2	162.7
Adjustments to Reconcile Net Income (Loss) to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	105.9	95.2
Deferred Income Taxes	25	20.6
Allowance for Equity Funds Used During Construction	(17.9)	(16.4)
Property Taxes	36.3	34.6
Provision for Refund Affiliated	6	4.8
Change in Other Noncurrent Assets	(0.4)	0.9
Change in Other Noncurrent Liabilities	(6.1)	6.6
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(4)	(12.5)
Fuel, Materials and Supplies	0	(4.1)
Accounts Payable	5.4	41
Accrued Taxes, Net	(63.2)	(59.9)
Other Current Assets	1	1
Other Current Liabilities	10.8	29.6
Net Cash Flows from (Used for) Operating Activities	274	299.3
Investing Activities
Construction Expenditures	(336.5)	(439.7)
Change in Advances to Affiliates, Net	(230.9)	(293.1)
Other Investing Activities	7.8	(0.8)
Net Cash Flows from (Used for) Investing Activities	(559.6)	(733.6)
Financing Activities
Capital Contributions from Parent	25	25
Issuance of Long-term Debt	446.1	689.2
Change in Advances from Affiliates, Net	(145.5)	(224.9)
Dividends Paid on Common Stock	(40)	(55)
Net Cash Flows from (Used for) Financing Activities	285.6	434.3
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	33.3	16.2
Construction Expenditures Included in Current Liabilities as of March 31,	191	305.4
AEP Transmission Co [Member] \| Retained Earnings [Member]
Operating Activities
Net Income (Loss)	181.2	162.7
Financing Activities
Dividends Paid on Common Stock	(40)	(55)
Appalachian Power Co [Member]
Operating Activities
Net Income (Loss)	136.5	112.5
Adjustments to Reconcile Net Income (Loss) to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	149.8	143
Deferred Income Taxes	(12.8)	10.3
Allowance for Equity Funds Used During Construction	(2.9)	(2.4)
Mark-to-Market of Risk Management Contracts	11.8	60.1
Deferred Fuel Over/Under-Recovery, Net	62.4	26
Change in Other Noncurrent Assets	3.9	(5.5)
Change in Other Noncurrent Liabilities	6.5	(33)
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(10.6)	54.5
Fuel, Materials and Supplies	30	(59.3)
Increase (Decrease) in Margin Deposits Outstanding	11	(11.1)
Accounts Payable	(24.7)	(156.1)
Accrued Taxes, Net	33	23.6
Other Current Assets	0	2.9
Other Current Liabilities	12.4	(1.2)
Net Cash Flows from (Used for) Operating Activities	406.3	164.3
Investing Activities
Construction Expenditures	(236)	(287.4)
Change in Advances to Affiliates, Net	(18.5)	1.1
Other Investing Activities	3.6	1.5
Net Cash Flows from (Used for) Investing Activities	(250.9)	(284.8)
Financing Activities
Capital Contributions from Parent	100	0
Issuance of Long-term Debt	395.8	0
Change in Advances from Affiliates, Net	(339.6)	128
Retirement of Long-term Debt	(313.4)	(13)
Principal Payments for Finance Leases Obligations	(2.2)	(2)
Other Financing Activities	0.1	0.2
Net Cash Flows from (Used for) Financing Activities	(159.3)	113.2
Net Increase (Decrease) in Cash and Cash Equivalents	(3.9)	(7.3)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	19.9	21.9
Cash and Cash Equivalents at Beginning of Period	5
Cash, Cash Equivalents and Restricted Cash at End of Period	16	14.6
Cash and Cash Equivalents at End of Period	7.6
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	41.5	37.9
Noncash Acquisitions Under Finance Leases	0.3	0.6
Construction Expenditures Included in Current Liabilities as of March 31,	107.3	122.6
Appalachian Power Co [Member] \| Retained Earnings [Member]
Operating Activities
Net Income (Loss)	136.5	112.5
Indiana Michigan Power Co [Member]
Operating Activities
Net Income (Loss)	145	102.8
Adjustments to Reconcile Net Income (Loss) to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	108.3	125.2
Deferred Income Taxes	(60.3)	(3.3)
Amortization (Deferral) of Incremental Nuclear Refueling Outage Expenses, Net	(11.8)	18.1
Allowance for Equity Funds Used During Construction	(3.3)	(0.5)
Mark-to-Market of Risk Management Contracts	27.1	8.8
Amortization of Nuclear Fuel	24.4	25
Deferred Fuel Over/Under-Recovery, Net	10.1	3.8
Change in Other Noncurrent Assets	(34)	(4.3)
Change in Other Noncurrent Liabilities	35.3	3.7
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(2.1)	52.7
Fuel, Materials and Supplies	21.3	(24.1)
Accounts Payable	(13.5)	(27.8)
Accrued Taxes, Net	28.8	21.1
Other Current Assets	11.9	(1.9)
Other Current Liabilities	(37.3)	(41.8)
Net Cash Flows from (Used for) Operating Activities	249.9	257.5
Investing Activities
Construction Expenditures	(142.3)	(141.7)
Change in Advances to Affiliates, Net	0	(37)
Purchases of Investment Securities	(588.5)	(536.3)
Sales of Investment Securities	569.5	517.6
Acquisitions of Nuclear Fuel	(33.7)	(1.7)
Other Investing Activities	2.7	3.3
Net Cash Flows from (Used for) Investing Activities	(192.3)	(195.8)
Financing Activities
Issuance of Long-term Debt	0	499.8
Change in Advances from Affiliates, Net	9.9	(249.9)
Retirement of Long-term Debt	(25.4)	(274.3)
Principal Payments for Finance Leases Obligations	(1.6)	(1.9)
Dividends Paid on Common Stock	(37.5)	(31.2)
Other Financing Activities	0.4	0.1
Net Cash Flows from (Used for) Financing Activities	(54.2)	(57.4)
Net Increase (Decrease) in Cash and Cash Equivalents	3.4	4.3
Cash and Cash Equivalents at Beginning of Period	2.1	4.2
Cash and Cash Equivalents at End of Period	5.5	8.5
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	38.7	44.4
Net Cash Paid (Received) for Income Taxes	0	2.4
Noncash Acquisitions Under Finance Leases	0.5	2.2
Construction Expenditures Included in Current Liabilities as of March 31,	63.1	61.3
Indiana Michigan Power Co [Member] \| Retained Earnings [Member]
Operating Activities
Net Income (Loss)	145	102.8
Ohio Power Co [Member]
Operating Activities
Net Income (Loss)	70.6	78
Adjustments to Reconcile Net Income (Loss) to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	105.8	75.2
Deferred Income Taxes	(0.6)	2.1
Allowance for Equity Funds Used During Construction	(5.5)	(2.8)
Mark-to-Market of Risk Management Contracts	(9.7)	7.2
Property Taxes	95	92
Change in Other Noncurrent Assets	10.1	(43.2)
Change in Other Noncurrent Liabilities	11.4	(21.7)
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(40.2)	(20.3)
Fuel, Materials and Supplies	(1.1)	(4.8)
Accounts Payable	(32.4)	(5.5)
Increase (Decrease) in Contract with Customer, Liability	14.2	(22.7)
Accrued Taxes, Net	(157.5)	(157.9)
Other Current Assets	(3.4)	(2.2)
Other Current Liabilities	1.5	(7.7)
Net Cash Flows from (Used for) Operating Activities	58.2	(34.3)
Investing Activities
Construction Expenditures	(241.1)	(262)
Other Investing Activities	5.2	4.9
Net Cash Flows from (Used for) Investing Activities	(235.9)	(257.1)
Financing Activities
Capital Contributions from Parent	0	50
Change in Advances from Affiliates, Net	184.7	241.7
Principal Payments for Finance Leases Obligations	(1.3)	(1.2)
Other Financing Activities	0.4	0.4
Net Cash Flows from (Used for) Financing Activities	183.8	290.9
Net Increase (Decrease) in Cash and Cash Equivalents	6.1	(0.5)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	6.4	9.6
Cash and Cash Equivalents at Beginning of Period	6.4
Cash, Cash Equivalents and Restricted Cash at End of Period	12.5	9.1
Cash and Cash Equivalents at End of Period	12.5
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	19.1	20.9
Noncash Acquisitions Under Finance Leases	0.5	0.6
Construction Expenditures Included in Current Liabilities as of March 31,	104.8	109.9
Ohio Power Co [Member] \| Retained Earnings [Member]
Operating Activities
Net Income (Loss)	70.6	78
Public Service Co Of Oklahoma [Member]
Operating Activities
Net Income (Loss)	72	(2.3)
Adjustments to Reconcile Net Income (Loss) to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	67.4	61.1
Deferred Income Taxes	(15.5)	12.2
Allowance for Equity Funds Used During Construction	(2.4)	(1.5)
Mark-to-Market of Risk Management Contracts	12.5	13.9
Property Taxes	(45.9)	(45.6)
Deferred Fuel Over/Under-Recovery, Net	(37.6)	49.4
Change in Other Noncurrent Assets	(18.4)	(9.7)
Change in Other Noncurrent Liabilities	1.7	1.4
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(4.8)	27.2
Fuel, Materials and Supplies	(2.9)	12.9
Accounts Payable	(4.5)	(62.8)
Accrued Taxes, Net	23.9	24.9
Other Current Assets	(16.1)	0.4
Other Current Liabilities	(46.9)	(7.5)
Net Cash Flows from (Used for) Operating Activities	(17.5)	74
Investing Activities
Construction Expenditures	(156.9)	(146.8)
Other Investing Activities	1	0.4
Net Cash Flows from (Used for) Investing Activities	(155.9)	(292.1)
Financing Activities
Issuance of Long-term Debt	0	469.9
Change in Advances from Affiliates, Net	210.2	(233.5)
Retirement of Long-term Debt	(0.1)	(0.1)
Principal Payments for Finance Leases Obligations	(0.8)	(0.8)
Dividends Paid on Common Stock	(35)	(17.5)
Other Financing Activities	0.1	(0.1)
Net Cash Flows from (Used for) Financing Activities	174.4	217.9
Net Increase (Decrease) in Cash and Cash Equivalents	1	(0.2)
Cash and Cash Equivalents at Beginning of Period	2.5	4
Cash and Cash Equivalents at End of Period	3.5	3.8
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	30.3	22.3
Cash Received from Sale of Transferable Tax Credits	(24.9)	0
Noncash Acquisitions Under Finance Leases	0.4	0.2
Construction Expenditures Included in Current Liabilities as of March 31,	47.9	63.4
Public Service Co Of Oklahoma [Member] \| Renewable Energy Facilities
Investing Activities
Acquisitions of Renewable Energy Facilities	0	(145.7)
Public Service Co Of Oklahoma [Member] \| Retained Earnings [Member]
Operating Activities
Net Income (Loss)	72	(2.3)
Southwestern Electric Power Co [Member]
Operating Activities
Net Income (Loss)	209.6	41.8
Adjustments to Reconcile Net Income (Loss) to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	78.7	80.4
Deferred Income Taxes	(118.5)	10.8
Allowance for Equity Funds Used During Construction	(3.4)	(0.5)
Mark-to-Market of Risk Management Contracts	1.7	9.9
Property Taxes	(74.3)	(77.5)
Deferred Fuel Over/Under-Recovery, Net	22.8	42.9
Change in Other Noncurrent Assets	(10.2)	7.2
Change in Other Noncurrent Liabilities	(0.3)	(3.3)
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(9.7)	29.9
Fuel, Materials and Supplies	9.4	(4.3)
Accounts Payable	(29.6)	(47.8)
Accrued Taxes, Net	67	62.3
Other Current Assets	(17.7)	7.3
Other Current Liabilities	(55.7)	(48.9)
Net Cash Flows from (Used for) Operating Activities	69.8	110.2
Investing Activities
Construction Expenditures	(182.6)	(201.9)
Change in Advances to Affiliates, Net	(0.1)	0
Other Investing Activities	3	0.4
Net Cash Flows from (Used for) Investing Activities	(179.7)	(201.5)
Financing Activities
Capital Contributions from Parent	0	50
Issuance of Long-term Debt	0	347.3
Change in Short-term Debt with Original Maturities less than 90 Days, Net	1.1	16
Change in Advances from Affiliates, Net	165.8	(291.9)
Retirement of Long-term Debt	0	(94.1)
Principal Payments for Finance Leases Obligations	(4.4)	(14.8)
Dividends Paid on Common Stock	(50)	0
Dividends Paid on Common Stock	(1.4)	(1.5)
Other Financing Activities	0.2	0.1
Net Cash Flows from (Used for) Financing Activities	111.3	11.1
Net Increase (Decrease) in Cash and Cash Equivalents	1.4	(80.2)
Cash and Cash Equivalents at Beginning of Period	2.4	88.4
Cash and Cash Equivalents at End of Period	3.8	8.2
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	41.2	45.3
Cash Received from Sale of Transferable Tax Credits	(19.9)	0
Noncash Acquisitions Under Finance Leases	0.4	0.9
Construction Expenditures Included in Current Liabilities as of March 31,	$ 79.4	$ 113.3

Significant Accounting Matters

Significant Accounting Matters	3 Months Ended
Significant Accounting Matters	Mar. 31, 2024
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 months ended March 31, 2024 is not necessarily indicative of results that may be expected for the year ending December 31, 2024. The condensed financial statements are unaudited and should be read in conjunction with the audited 2023 financial statements and notes thereto, which are included in the Registrants’ Annual Reports on Form 10-K as filed with the SEC on February 26, 2024. 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 March 31, 2024 2023 (in millions, except per share data) $/share $/share Earnings Attributable to AEP Common Shareholders $ 1,003.1 $ 397.0 Weighted-Average Number of Basic AEP Common Shares Outstanding 526.6 $ 1.91 514.2 $ 0.77 Weighted-Average Dilutive Effect of Stock-Based Awards 1.0 (0.01) 1.4 — Weighted-Average Number of Diluted AEP Common Shares Outstanding 527.6 $ 1.90 515.6 $ 0.77 There were no antidilutive shares outstanding as of March 31, 2024 and 2023. 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: March 31, 2024 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 230.7 $ 0.1 $ 7.6 Restricted Cash 51.1 42.7 8.4 Total Cash, Cash Equivalents and Restricted Cash $ 281.8 $ 42.8 $ 16.0 December 31, 2023 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 330.1 $ 0.1 $ 5.0 Restricted Cash 48.9 34.0 14.9 Total Cash, Cash Equivalents and Restricted Cash $ 379.0 $ 34.1 $ 19.9

New Accounting Standards

New Accounting Standards	3 Months Ended
New Accounting Standards	Mar. 31, 2024
New Accounting Standards	NEW ACCOUNTING STANDARDS The disclosures in this note apply to all Registrants unless indicated otherwise. Management reviews the FASB’s standard-setting process and the SEC’s rulemaking activity to determine the relevance, if any, to the Registrants’ business. The following standards/rules will impact the Registrants’ financial statements. SEC Climate Disclosure Rule On March 6, 2024, the SEC adopted final rules that require Registrants to disclose certain climate-related information in registration statements and annual reports. The final rules require Registrants to disclose, among other things, material climate-related risks, activities to mitigate such risks and information about Registrant’s board of directors oversight and management’s role in managing material climate-related risks. The final rules also require the Registrants to provide information related to any climate-related targets or goals that are material to Registrant’s business, results of operations, or financial condition. A majority of the reporting requirements are applicable to the fiscal year beginning in 2025, with the addition of assurance reporting for greenhouse gas emissions starting in 2029 for large accelerated filers. Litigation challenging the new rules was filed by multiple parties in multiple jurisdictions, which have been consolidated and assigned to the U.S. Court of Appeals for the Eighth Circuit. On April 4, 2024, the SEC issued an order staying the final climate disclosure rules pending the completion of judicial review at the Court of Appeals. The Registrants are currently evaluating the impact of the final rules on their respective consolidated financial statements and related disclosures. ASU 2023-09 “Improvements to Income Tax Disclosures” (ASU 2023-09) In December 2023, the FASB issued ASU 2023-09, to address investors’ suggested enhancements to (a) better understand an entity’s exposure to potential changes in jurisdictional tax legislation and the ensuing risks and opportunities, (b) assess income tax information that affects cash flow forecasts and capital allocation decisions and (c) identify potential opportunities to increase future cash flows. The new standard requires an annual rate reconciliation disclosure of the following categories regardless of materiality: state and local income tax net of federal income tax effect, foreign tax effects, effect of changes in tax laws or rates enacted in the current period, effect of cross-border tax laws, tax credits, changes in valuation allowances, nontaxable or nondeductible items and changes in unrecognized tax benefits. The new standard also requires an annual disclosure of the amount of income taxes paid (net of refunds received) disaggregated by federal, state and foreign taxes and by individual jurisdictions that are equal to or greater than 5 percent of total income taxes paid. Disclosure of income (loss) from continuing operations before income tax expense (benefit) disaggregated between domestic and foreign jurisdictions and income tax expense (benefit) from continuing operations disaggregated by federal, state and foreign jurisdictions is required. The new standard removes the requirement to disclose the cumulative amount of each type of temporary difference when a deferred tax liability is not recognized because of the exceptions to comprehensive recognition of deferred taxes related to subsidiaries and corporate joint ventures. The amendments in the new standard may be applied on either a prospective or retrospective basis for public business entities for fiscal years beginning after December 15, 2024 with early adoption permitted. Management has not yet made a decision to early adopt the amendments to this standard or how to apply them. ASU 2023-07 “Improvements to Reportable Segment Disclosures” (ASU 2023-07) In November 2023, the FASB issued ASU 2023-07, to address investors’ observations that there is limited information disclosed about segment expenses and to better understand expense categories and amounts included in segment profit or loss. The new standard requires annual and interim disclosure of (a) the categories and amounts of significant segment expenses (determined by management using both qualitative and quantitative factors) that are regularly provided to the CODM and included within each reported measure of segment profit or loss, (b) the amounts and a qualitative description of “other segment items”, defined as the difference between reported segment revenues less the significant segment expenses and each reported measure of segment profit or loss disclosed, (c) reportable segment profit or loss and assets that are currently only required annually, (d) the CODM’s title and position, and an explanation of how the CODM uses the reported measure(s) of segment profit or loss in assessing segment performance and deciding how to allocate resources and (e) a requirement that entities with a single reportable segment provide all disclosures required by ASU 2023-07 and all existing segment disclosures in Topic 280. Additionally, this new standard allows disclosure of one or more of additional profit or loss measures if the CODM uses more than one measure provided that at least one of the disclosed measures is determined in a manner “most consistent with the measurement principles under GAAP”. If multiple measures are presented, additional disclosure is required about how the CODM uses each measure to assess performance and decide how to allocate resources. The amendments in the new standard are effective on a retrospective basis for all entities for fiscal years beginning after December 15, 2023 and interim periods within fiscal periods beginning after December 15, 2024 with early adoption permitted. Management plans to adopt ASU 2023-07 effective for the 2024 10-K.

Comprehensive Income

Comprehensive Income	3 Months Ended
Comprehensive Income	Mar. 31, 2024
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 March 31, 2024 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2023 $ 104.9 $ (8.1) $ (152.3) $ (55.5) Change in Fair Value Recognized in AOCI, Net of Tax 5.5 12.4 — 17.9 Amount of (Gain) Loss Reclassified from AOCI Purchased Electricity, Fuel and Other Consumables Used for Electric Generation (a) (29.3) — — (29.3) Interest Expense (a) — (1.2) — (1.2) Amortization of Prior Service Cost (Credit) — — (1.3) (1.3) Amortization of Actuarial (Gains) Losses — — 0.5 0.5 Reclassifications from AOCI, before Income Tax Benefit (29.3) (1.2) (0.8) (31.3) Income Tax Benefit (6.1) (0.3) (0.2) (6.6) Reclassifications from AOCI, Net of Income Tax Benefit (23.2) (0.9) (0.6) (24.7) Net Current Period Other Comprehensive Income (Loss) (17.7) 11.5 (0.6) (6.8) Balance in AOCI as of March 31, 2024 $ 87.2 $ 3.4 $ (152.9) $ (62.3) Cash Flow Hedges Pension Three Months Ended March 31, 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 (195.3) 5.2 (12.9) (203.0) Amount of (Gain) Loss Reclassified from AOCI Purchased Electricity, Fuel and Other Consumables Used for Electric Generation (a) 47.0 — — 47.0 Interest Expense (a) — 0.7 — 0.7 Amortization of Prior Service Cost (Credit) — — (5.3) (5.3) Amortization of Actuarial (Gains) Losses — — 1.2 1.2 Reclassifications from AOCI, before Income Tax (Expense) Benefit 47.0 0.7 (4.1) 43.6 Income Tax (Expense) Benefit 9.9 0.1 (0.9) 9.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 37.1 0.6 (3.2) 34.5 Reclassifications of KPCo Pension and OPEB Regulatory Assets from AOCI, Before Income Tax (Expense) Benefit — — 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) (158.2) 5.8 0.6 (151.8) Balance in AOCI as of March 31, 2023 $ 65.3 $ 6.1 $ (139.5) $ (68.1) (a) Amounts reclassified to the referenced line item on the statements of income.

Rate Matters

Rate Matters	3 Months Ended
Rate Matters	Mar. 31, 2024
Rate Matters	RATE MATTERS The disclosures in this note apply to all Registrants unless indicated otherwise. As discussed in the 2023 Annual Report, the Registrants are involved in rate and regulatory proceedings at the FERC and their state commissions. The Rate Matters note within the 2023 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 2024 and updates the 2023 Annual Report. Regulated Generating Units (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 in balance with reliability and other factors, which has resulted in, and in the future may result in, a proposal to retire 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. See the “2020 Texas Base Rate Case” section below for additional information. 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. In April 2024, the LPSC approved a unanimous settlement agreement filed by SWEPCo, LPSC staff and certain intervenors that resolved the prudency of the retirement of the Dolet Hills Power Station and resulted in a disallowance of $14 million in the first quarter of 2024. 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. In July 2023, Texas ALJs issued a proposal for decision that concluded the decision to retire the Pirkey Plant was prudent. In September 2023, the PUCT rejected the ALJs proposal for decision concluding the retirement of the Pirkey Plant was prudent. In the open meeting, the commissioners expressed their concerns that the analysis in support of SWEPCo’s decision to retire the Pirkey Plant was not robust enough and that SWEPCo should have re-evaluated the decision following Winter Storm Uri. The treatment of the cost of recovery of the Pirkey Plant is expected to be addressed in a future rate case. As of March 31, 2024, the Texas jurisdictional share of the net book value of the Pirkey Plant was $68 million. To the extent any portion of the Texas jurisdictional share of the net book value of the Pirkey Plant is not recoverable, it could reduce future net income and cash flows and impact financial condition. 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 2022 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 March 31, 2024, 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 $ 96.7 $ 168.9 $ 20.7 (b) 2026 (c) $ 15.1 Welsh Plant, Units 1 and 3 335.6 135.7 58.1 (d) 2028 (e) (f) 39.2 (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 March 31, 2024, SWEPCo’s share of the net investment in the Dolet Hills Power Station was $86 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 March 31, 2024, SWEPCo had a net under-recovered fuel balance of $72 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 $35 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 up to $55 million, including denial of recovery of the $35 million deferral, with refunds to customers over five years. In February 2024, an ALJ issued a final recommendation which included a proposed $55 million refund to customers and the denial of recovery of the $35 million deferral. SWEPCo filed a motion to present oral arguments with the LPSC to dispute the ALJ’s recommendations. In April 2024, the LPSC approved a unanimous settlement agreement filed by SWEPCo, LPSC staff and certain intervenors that resolved the fuel recovery dispute and resulted in a fuel disallowance of $11 million. The remaining $24 million regulatory asset balance will be recovered over three years with interest. 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 September 2023, the PUCT approved an unopposed settlement agreement that provides recovery of $48 million of Oxbow mine related costs through 2035. If any of these costs are not recoverable or customer refunds are required, 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 March 31, 2024, SWEPCo’s share of the net investment in the Pirkey Plant was $185 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 March 31, 2024, SWEPCo had a net under-recovered fuel balance of $72 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 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. The LPSC established a procedural schedule stating staff and intervenor testimony is due in November 2024 and a hearing is scheduled for March 2025. In September 2023, the PUCT approved an unopposed settlement agreement that provides recovery of $33 million of Sabine related fuel costs through 2035. If any of these costs are not recoverable or customer refunds are required, 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 March 31, December 31, 2024 2023 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Welsh Plant, Units 1 and 3 Accelerated Depreciation $ 135.7 $ 125.6 Pirkey Plant Accelerated Depreciation 121.0 114.4 Unrecovered Winter Storm Fuel Costs (a) 90.8 97.2 Other Regulatory Assets Pending Final Regulatory Approval 14.3 49.8 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 404.9 408.9 NOLC Costs 67.7 — Other Regulatory Assets Pending Final Regulatory Approval 89.4 78.5 Total Regulatory Assets Pending Final Regulatory Approval $ 923.8 $ 874.4 (a) Includes $37 million and $37 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of March 31, 2024 and December 31, 2023, respectively. See the “February 2021 Severe Winter Weather Impacts in SPP” section below for additional information. AEP Texas March 31, December 31, 2024 2023 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Not Earning a Return Storm-Related Costs $ 38.4 $ 37.7 Line Inspection Costs 7.4 5.7 Vegetation Management Program 5.2 5.2 Texas Retail Electric Provider Bad Debt Expense 4.1 4.0 Other Regulatory Assets Pending Final Regulatory Approval 12.1 11.7 Total Regulatory Assets Pending Final Regulatory Approval $ 67.2 $ 64.3 APCo March 31, December 31, 2024 2023 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Other Regulatory Assets Pending Final Regulatory Approval $ 0.7 $ 0.6 Regulatory Assets Currently Not Earning a Return Storm-Related Costs - West Virginia 91.2 91.5 Plant Retirement Costs – Asset Retirement Obligation Costs 25.9 25.9 Other Regulatory Assets Pending Final Regulatory Approval 11.1 7.5 Total Regulatory Assets Pending Final Regulatory Approval $ 128.9 $ 125.5 I&M March 31, December 31, 2024 2023 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Other Regulatory Assets Pending Final Regulatory Approval $ 0.2 $ 0.2 Regulatory Assets Currently Not Earning a Return Storm-Related Costs - Indiana 29.7 29.7 NOLC Costs - Indiana 20.2 — Other Regulatory Assets Pending Final Regulatory Approval 4.6 3.3 Total Regulatory Assets Pending Final Regulatory Approval $ 54.7 $ 33.2 OPCo March 31, December 31, 2024 2023 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Not Earning a Return Storm-Related Costs $ 23.6 $ 23.6 Total Regulatory Assets Pending Final Regulatory Approval $ 23.6 $ 23.6 PSO March 31, December 31, 2024 2023 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Not Earning a Return Storm-Related Costs $ 88.8 $ 88.5 NOLC Costs 12.1 — Other Regulatory Assets Pending Final Regulatory Approval 2.9 0.2 Total Regulatory Assets Pending Final Regulatory Approval $ 103.8 $ 88.7 SWEPCo March 31, December 31, 2024 2023 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Welsh Plant, Units 1 and 3 Accelerated Depreciation $ 135.7 $ 125.6 Pirkey Plant Accelerated Depreciation 121.0 114.4 Unrecovered Winter Storm Fuel Costs (a) 90.8 97.2 Dolet Hills Power Station Accelerated Depreciation (b) 12.0 12.0 Other Regulatory Assets Pending Final Regulatory Approval 1.4 26.0 Regulatory Assets Currently Not Earning a Return Storm-Related Costs - Louisiana, Texas 51.4 56.0 NOLC Costs 35.4 — Other Regulatory Assets Pending Final Regulatory Approval 13.9 13.7 Total Regulatory Assets Pending Final Regulatory Approval $ 461.6 $ 444.9 (a) Includes $37 million and $37 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of March 31, 2024 and December 31, 2023, respectively. See the “February 2021 Severe Winter Weather Impacts in SPP” section below for additional information. (b) Amounts include the FERC jurisdiction. 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 March 31, 2024, AEP Texas’ cumulative revenues from interim base rate increases that are subject to a prudency review is approximately $1.1 billion. The 2024 AEP Texas base rate case described below 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. 2024 AEP Texas Base Rate Case In February 2024, AEP Texas filed a request with the PUCT for a $164 million annual base rate increase over its adjusted test year revenues which include interim transmission and distribution rate updates. AEP Texas’s request is based upon a proposed 10.6% ROE with a capital structure of 55% debt and 45% common equity. The rate case seeks a prudence determination on all capital additions included in interim rates since 2018. The procedural schedule for this case states intervenor testimony is due May 2024 and a hearing is scheduled for June 2024. If any of these costs are not recoverable or refunds of revenues collected under interim transmission and distribution rates are ordered to be returned, it could reduce future net income and cash flows and impact financial condition. APCo and WPCo Rate Matters (Applies to AEP and APCo) ENEC (Expanded Net Energy Cost) Filings In January 2024, the WVPSC issued an order resolving the Companies’ 2021-2023 ENEC cases. In the order, the WVPSC: (a) disallowed $232 million in ENEC under-recovered costs as of February 28, 2023 ($136 million related to APCo) and (b) approved the recovery of $321 million of ENEC under-recovered costs as of February 28, 2023 ($174 million related to APCo) plus a 4% carrying charge rate over a ten-year recovery period starting September 1, 2024. In February 2024, the Companies filed briefs with the West Virginia Supreme Court to initiate an appeal of this order. The West Virginia Supreme Court will hear oral arguments in September 2024, after which it will issue a decision on the appeal. The Companies will submit their annual ENEC update filing with the WVPSC in the second quarter of 2024 proposing that updated ENEC rates become effective September 1, 2024. 2023 Virginia Base Rate Case In March 2024, APCo filed a request with the Virginia SCC for a $95 million annual increase in base rates based upon a proposed 10.8% ROE and a proposed capital structure of 51% debt and 49% common equity. The requested increase in base rates is primarily due to incremental rate base, proposed capital structure changes including an increase in ROE and proposed increases in distribution and generation operation and maintenance expenses. Staff testimony is due in August 2024 and a hearing is scheduled for September 2024. An order is expected in the second half of 2024. If any costs included in this filing are not approved for recovery, 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 March 31, 2024, AEP’s share of ETT’s cumulative revenues that are subject to a prudency review is approximately $1.7 billion. A base rate review could produce a refund to customers 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 $1.7 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 Rockport Plant UPA with AEGCo 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 Rockport Plant UPA with AEGCo. 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. In January 2024, I&M received staff testimony in I&M’s 2022 PSCR Reconciliation for the 12-month period ending December 31, 2022 recommending disallowances of purchased power costs of $2 million associated with the OVEC ICPA that were alleged to be above market in applying the MPSC’s Code of Conduct rules. Similar to the 2021 PSCR Reconciliation, 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 $6 million. In April 2024, the MPSC issued an order on I&M’s 2021 PSCR Reconciliation that: (a) disallowed $1 million of purchased power costs associated with the OVEC ICPA that the MPSC concluded were above market, (b) disallowed $10 million of purchased power costs under the Rockport Plant UPA with AEGCo that the MPSC concluded were “energy only” and above market and (c) disallowed $497 thousand of PSCR costs due to I&M’s shortfall in achieving Michigan’s one percent energy waste reduction savings level in 2020. As of March 31, 2024, I&M’s financial statements reflect the impacts of this disallowance. I&M expects to appeal the MPSC’s order. In March 2024, I&M submitted its 2023 PSCR Reconciliation to the MPSC. An MPSC order on I&M’s 2022 PSCR Reconciliation is expected in the second half of 2024. The MPSC has yet to issue a procedural schedule for I&M’s 2023 PSCR Reconciliation. If any PSCR costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. 2023 Indiana Base Rate Case In August 2023, I&M filed a request with the IURC for a $116 million annual increase in Indiana base rates based upon a 2024 forecasted test year, a proposed 10.5% ROE and a proposed capital structure of 48.8% debt and 51.2% common equity. I&M proposed that the annual increase in base rates be implemented in two steps, with the first increase effective in mid-2024, following an IURC order, and the second increase effective in January 2025. The proposed annual increase includes a $41 million increase related to depreciation expense, driven by increased depreciation rates and increased capital investments, and a $15 million increase related to storm expenses. I&M’s Indiana base case filing requests recovery of certain historical period regulatory asset balances and proposes deferral accounting for certain future investments and tax related issues, including corporate alternative minimum tax expense and PTCs related to the Cook Plant. In December 2023, I&M and intervenors reached a settlement agreement that was submitted to the IURC recommending a two-step increase in Indiana rates with a $28 million annual increase effective upon an IURC order and the remaining $34 million annual increase effective in January 2025. The recommended revenue increase includes: (a) a 9.85% ROE, (b) a two-step update of I&M’s capital structure with a capital structure of 50% for both debt and common equity effective upon an IURC order and I&M will submit an updated capital structure in January 2025 with the common equity component adjusted to no more than 51.2%, (c) a $25 million increase related to depreciation expense and (d) an $11 million increase related to storm expenses. A hearing was held in January 2024 and an order is expected in the second quarter of 2024. If any costs included in this filing are not approved for recovery, it could reduce future net income and cash flows and impact financial condition. 2023 Michigan Base Rate Case In September 2023, I&M filed a request with the MPSC for a $34 million annual increase in Michigan base rates based upon a 2024 forecasted test year, a proposed 10.5% ROE and a capital structure of 49.4% debt and 50.6% common equity. The proposed annual increase includes an $11 million annual increase in depreciation expense driven by increased capital investment. I&M’s Michigan base case filing requests recovery of certain historical period regulatory asset balances and proposes deferral accounting for certain future investments and tax related issues, including corporate alternative minimum tax (CAMT) expense and PTCs related to the Cook Plant. In January 2024, Michigan staff and various intervenors submitted testimony recommending changes in base rates ranging from a $6 million annual decrease to a $19 million annual increase. These changes are based on ROEs ranging from 9.7% to 9.9% and capital structures ranging from 49.4% debt and 50.6% equity to 52% debt and 48% equity. Staff and intervenors also proposed in testimony certain disallowances related to regulatory assets and capital investments, the exclusion of CAMT from any future deferrals and the prospective inclusion of PTCs related to the Cook Plant in I&M’s PSCR. A hearing was held in February 2024. If any costs included in this filing are not approved for recovery, it could reduce future net income and cash flows and impact financial condition. KPCo Rate Matters (Applies to AEP) Investigation of the Service, Rates and Facilities of KPCo In June 2023, 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. In December 2023 and February 2024, KPCo and certain intervenors filed testimony with the KPSC. In February 2024, KPCo filed a motion to strike and exclude intervenor testimony. In March 2024, the KPSC denied KPCo’s February 2024 motion. A hearing is expected in 2024. If any fines or penalties are levied against KPCo relating to the show cause order, it could 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. In conjunction with its June 2023 filing, KPCo further requested to finance through the issuance of securitization bonds, approximately $471 million of regulatory assets. KPCo’s proposal did not address the disposition of its 50% interest in Mitchell Plant, which will be addressed in the future. As of March 31, 2024, the net book value of KPCo’s share of the Mitchell Plant, before cost of removal including CWIP and inventory, was $543 million. If any of these costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. In November 2023, KPCo filed an uncontested settlement agreement with the KPSC, that included an annual base rate increase of $75 million, based upon a 9.75% ROE. Settlement parties agreed that the KPSC should approve KPCo’s securitization request, and that the approximately $471 million regulatory assets requested for securitization are comprised of prudently incurred costs. In January 2024, the KPSC issued an order modifying the November 2023 uncontested settlement agreement and approving an annual base rate increase of $60 million based upon a 9.75% ROE effective with billing cycles mid-January 2024. The order reduced KPCo’s base rate revenue requirement by $14 million to allow recovery of actual test year PJM transmission costs instead of KPCo’s requested annual level of costs based on PJM 2023 projected transmission revenue requirements. In February 2024, KPCo filed an appeal with the Commonwealth of Kentucky Franklin Circuit Court, challenging among other aspects of the order the $14 million base rate revenue requirement reduction. In January 2024, consistent with the November 2023 uncontested settlement agreement, the KPSC issued a financing order approving KPCo’s request to securitize certain regulatory assets balances as of the time securitization bonds are issued and concluding that costs requested for recovery through securitization were prudently incurred. The KPSC’s financing order includes certain additional requirements related to securitization bond structuring, marketing, placement and issuance that were not reflected in KPCo’s proposal. As a result, in January 2024, KPCo filed a request for rehearing with the KPSC to clarify certain aspects of these additional requirements. In February 2024, the KPSC denied KPCo’s rehearing requests. In accordance with Kentucky statutory requirements and the financing order, the issuance of the securitized bonds is subject to final review by the KPSC after bond pricing. KPCo expects to proceed with the securitized bond issuance process and to complete the securitization process in the second half of 2024, subject to market conditions. As of March 31, 2024, regulatory asset balances expected to be recovered through securitization total $476 million and include: (a) $288 million of plant retirement costs, (b) $79 million of deferred storm costs related to 2020, 2021, 2022 and 2023 major storms, (c) $46 million of deferred purchased power expenses, (d) $62 million of under-recovered purchased power rider costs and (e) $1 million of deferred issuance-related expenses including KPSC advisor expenses. If any of these costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. Fuel Adjustment Clause (FAC) Review In December 2023, KPCo received intervenor testimony in its FAC review for the two-year period ending October 31, 2022, recommending a disallowance ranging from $44 million to $60 million of its total $432 million purchased power cost recoveries as a result of proposed modifications to the ratemaking methodology that limits purchased power costs recoverable through the FAC. A hearing was held in February 2024 and an order is expected in the second quarter of 2024. If any fuel costs are not recoverable or refunds are ordered, it could reduce future net income and cash flows and impact financial condition. Rockport Offset Recovery In January 2024, KPCo filed an application with the KPSC seeking to recover an allowed cost (Rockport Offset) of $41 million in accordance with the terms of the settlement agreement in the 2017 Kentucky Base Rate Case permitting KPCo to use the level of non-fuel, non-environmental Rockport Plant UPA expense included in base rates to earn its authorized ROE in 2023 since the Rockport UPA ended in December 2022. An estimated Rockport Offset of $23 million was recovered through a rider, subject to true-up, during the 12-months ended December 2023. In February 2024, the KPSC issued an order allowing KPCo to collect the remaining $18 million through interim rates, subject to refund, over twelve months starting in March 2024. In April 2024, KPCo submitted to the KPSC a request for decision on the record. An order is expected in 2024. Through the first quarter of 2024, the Rockport Offset true-up is reflected in revenues to the extent amounts have been billed to customers, as KPCo has not met the requirements of alternative revenue recognition in accordance with the accounting guidance for “Regulated Operations”. If the Rockport Offset is not recoverable or refunds are ordered, 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. In May 2023, as part of the OVEC cost recovery audits pending before the PUCO, intervenors filed positions claiming that costs incurred by OPCo during the 2020 audit period were imprudent and should be disallo

Commitments, Guarantees and Con

Commitments, Guarantees and Contingencies	3 Months Ended
Commitments, Guarantees and Contingencies	Mar. 31, 2024
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 2023 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, AEP Texas, APCo and I&M) 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. In March 2024, AEP increased its $4 billion revolving credit facility to $5 billion and extended the due date from March 2027 to March 2029. Also, in March 2024, AEP extended the due date of its $1 billion revolving credit facility from March 2025 to March 2027. AEP may issue up to $1.2 billion as letters of credit, under these revolving credit facilities, on behalf of subsidiaries. As of March 31, 2024, no letters of credit were issued under either 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 March 31, 2024 were as follows: Company Amount Maturity (in millions) AEP $ 247.4 April 2024 to March 2025 AEP Texas 1.8 July 2024 APCo 6.3 September 2024 I&M 2.9 September 2024 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 March 31, 2024, 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 March 31, 2024, 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 $ 44.6 AEP Texas 10.7 APCo 5.8 I&M 4.1 OPCo 7.1 PSO 4.5 SWEPCo 5.1 ENVIRONMENTAL CONTINGENCIES (Applies to all Registrants except AEPTCo) Proposed Revisions to CCR Rule In April 2024, the Federal EPA finalized revisions to the CCR Rule to expand the scope of the rule to include inactive impoundments at inactive facilities (“legacy CCR surface impoundments”) as well as to establish requirements for currently exempt solid waste management units that involve the direct placement of CCR on the land (“CCR management units”). The Federal EPA is requiring that owners and operators of legacy surface impoundments comply with all of the existing CCR Rule requirements applicable to inactive CCR surface impoundments at active facilities, except for the location restrictions and liner design criteria. The rule establishes compliance deadlines for legacy surface impoundments to meet regulatory requirements, including a requirement to initiate closure within five years after the effective date of the final rule. The rule requires evaluations to be completed at both active facilities and inactive facilities with one or more legacy surface impoundments. AEP is evaluating the applicability of the rule to current and former plant sites and is working to develop estimates of compliance costs, which are expected to be material, including costs to upgrade or close and replace legacy CCR surface impoundments and to conduct any required remedial actions including removal of coal ash. Closure and post-closure estimated costs for facilities subject to the original CCR Rule have been included in ARO in accordance with the requirements in the Federal EPA’s original CCR rule. Material ARO revisions will be necessary to address the expanded scope of facilities subject to the revised rule. Additional material ARO revisions may occur on a site-by-site basis if groundwater monitoring activities conclude that corrective actions are required to mitigate groundwater impacts. AEP may incur significant additional costs complying with the Federal EPA’s CCR Rule, including costs to upgrade or close and replace surface impoundments and landfills used to manage CCR and to conduct any required remedial actions including removal of coal ash. AEP would need to seek cost recovery through regulated rates, including proposing new regulatory mechanisms for cost recovery where existing mechanisms are not applicable, for which regulatory approval cannot be assured. The rule could have a material adverse impact on net income, cash flows and financial condition if AEP cannot ultimately recover any additional costs of compliance. Management is also evaluating potential legal challenges to the revised rule. 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. Management is currently evaluating applying for license extensions for both units. 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 in April 2022. In June 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. In September 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. In January 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. In March 2023, the federal district court issued an order granting the motion to dismiss with prejudice and denying the New York plaintiffs’ motion to intervene. In April 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. The defendants will continue to defend against the claims. Management does not believe the range of potential losses that is reasonably possible of occurring will have a material impact on results of operations, cash flows or financial condition. 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 considered the 2023 litigation demand letter and formed a committee of the Board (the “Demand Review Committee”) to investigate, review, monitor and analyze the allegations in the letter and make a recommendation to the AEP Board regarding a reasonable and appropriate response to the same. The AEP Board will act in response to the letter as appropriate. Management does not believe the range of potential losses that is reasonably possible of occurring will have a material impact on results of operations, cash flows or financial condition. 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. The SEC staff has advanced its discussions with certain parties involved in the investigation, including AEP, concerning the staff’s intentions regarding potential claims under the securities laws. AEP and the SEC are engaged in discussions about a possible resolution of the SEC’s investigation and potential claims under the securities laws. Any resolution or filed claims, the outcome of which cannot be predicted, may subject AEP to civil penalties and other remedial measures. Discussions are continuing and management does not believe the range of potential losses that is reasonably possible of occurring as a result of this investigation, or possible resolution thereof, will have a material impact on results of operations, cash flows or financial condition. 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 assertions related to the CCR Rule (see “Environmental Issues - CCR Rule” section of Management’s Discussion and Analysis of Financial Condition and Results of Operations for additional information), including an assertion 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 any determinations of noncompliance by the Federal EPA with various aspects of the CCR Rule consistent with 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. In January 2024, Gavin Power LLC also filed a complaint with the United States District Court for the Southern District of Ohio, alleging various violations of the Administrative Procedure Act and asserting that the Federal EPA, through its prior inaction, has waived and is estopped from raising certain objections raised in the Gavin Denial. Management cannot predict the outcome of that litigation. Litigation Regarding Justice Thermal Coal Contract In December 2023, APCo filed a suit in the Franklin County Ohio Court of Common Pleas seeking a declaratory judgment confirming APCo’s right to terminate a long-term coal contract with Justice Thermal LLC (“Justice Thermal”) based on Justice Thermal’s failure to perform under the contract. APCo terminated that contract in January 2024, and in April 2024 APCo filed an amended complaint seeking a declaration that the termination was proper and also seeking damages for Justice Thermal’s breach of contract. Justice Thermal filed an answer and counterclaim in April 2024, contesting the validity of the contract termination and asserting counterclaims. Justice Thermal’s counterclaims allege that APCo breached the contract, assert a claim for fraud relating to APCo’s alleged fabrication of coal sample analyses, and seek damages. APCo will continue to pursue its claims and defend against the counterclaims. Management is unable to determine a range of potential losses that is reasonably possible of occurring.

Acquisitions and Dispositions

Acquisitions and Dispositions	3 Months Ended
Acquisitions and Dispositions	Mar. 31, 2024
Acquisitions and Dispositions	ACQUISITIONS AND DISPOSITIONS The disclosures in this note apply to AEP unless indicated otherwise. ACQUISITIONS 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,” AEP management determined that the acquisition of the Rock Falls Wind Facility represents an asset acquisition. The lease obligations related to Rock Falls were not material as at the time of acquisition. DISPOSITIONS 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 (the portfolio) within the Generation & Marketing segment. 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 portfolio and AEP signed an agreement with a nonaffiliated party. 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 and determining the carrying value of the portfolio exceeded the estimated fair value. In August 2023, AEP completed the sale of the entire portfolio to the nonaffiliated party and received cash proceeds of approximately $1.2 billion, net of taxes and transaction costs. Disposition of NMRD (Generation & Marketing Segment) (Applies to AEP) In December 2023, AEP and the joint owner signed an agreement to sell NMRD to a nonaffiliated third party and the sale was completed in February 2024. AEP received cash proceeds of approximately $107 million, net of taxes and transaction costs. The transaction did not have a material impact on net income or financial condition.

Benefit Plans

Benefit Plans	3 Months Ended
Benefit Plans	Mar. 31, 2024
Benefit Plans	BENEFIT PLANS The disclosures in this note apply to all Registrants except AEPTCo. AEPSC sponsors a qualified pension plan and two unfunded non-qualified pension plans. Substantially all AEP subsidiary employees are covered by the qualified plan or both the qualified and a non-qualified pension plan. AEPSC 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 March 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 25.6 $ 2.2 $ 2.4 $ 3.3 $ 2.4 $ 1.5 $ 1.9 Interest Cost 51.9 4.3 6.2 6.0 4.7 2.5 3.1 Expected Return on Plan Assets (80.2) (6.4) (10.7) (10.8) (8.2) (4.3) (4.4) Amortization of Net Actuarial Loss 1.1 0.1 0.1 0.1 0.1 — 0.1 Net Periodic Benefit Cost (Credit) $ (1.6) $ 0.2 $ (2.0) $ (1.4) $ (1.0) $ (0.3) $ 0.7 Three Months Ended March 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 23.6 $ 2.0 $ 2.3 $ 3.0 $ 2.1 $ 1.4 $ 1.9 Interest Cost 54.8 4.6 6.6 6.2 4.9 2.7 3.5 Expected Return on Plan Assets (84.8) (7.0) (11.2) (11.0) (8.5) (4.6) (4.8) Amortization of Net Actuarial Loss 0.3 — — — — — — Net Periodic Benefit Cost (Credit) $ (6.1) $ (0.4) $ (2.3) $ (1.8) $ (1.5) $ (0.5) $ 0.6 OPEB Three Months Ended March 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 1.1 $ 0.1 $ 0.1 $ 0.1 $ 0.1 $ 0.1 $ 0.1 Interest Cost 10.5 0.8 1.7 1.2 1.1 0.5 0.7 Expected Return on Plan Assets (27.8) (2.3) (4.0) (3.4) (3.0) (1.4) (1.9) Amortization of Prior Service Credit (3.2) (0.3) (0.5) (0.4) (0.3) (0.2) (0.3) Amortization of Net Actuarial Loss 0.8 0.1 0.1 0.1 0.1 — 0.1 Net Periodic Benefit Credit $ (18.6) $ (1.6) $ (2.6) $ (2.4) $ (2.0) $ (1.0) $ (1.3) Three Months Ended March 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 1.1 $ 0.1 $ 0.1 $ 0.2 $ 0.1 $ 0.1 $ 0.1 Interest Cost 11.6 0.9 1.8 1.3 1.2 0.6 0.7 Expected Return on Plan Assets (27.4) (2.3) (4.0) (3.4) (2.9) (1.5) (1.8) Amortization of Prior Service Credit (15.8) (1.3) (2.3) (2.2) (1.6) (1.0) (1.2) Amortization of Net Actuarial Loss 3.7 0.3 0.6 0.5 0.4 0.2 0.2 Net Periodic Benefit Credit $ (26.8) $ (2.3) $ (3.8) $ (3.6) $ (2.8) $ (1.6) $ (2.0)

Business Segments

Business Segments	3 Months Ended
Business Segments	Mar. 31, 2024
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 energy management services. • Marketing, risk management and retail activities in ERCOT, MISO, PJM and SPP. • Competitive generation in PJM. The remainder of AEP’s activities are presented as Corporate and Other. While not considered a reportable segment, Corporate and Other primarily includes the purchasing of receivables from certain AEP utility subsidiaries, Parent’s guarantee revenue received from affiliates, investment income, interest income and interest expense, income tax expense and other nonallocated costs. AEP’s CODM makes operating decisions, allocates resources to and assesses performance based on these operating segments. AEP measures segment profit or loss based on net income (loss). Net income (loss) includes intercompany revenues and expenses that are eliminated on the Consolidated Financial Statements. In addition, direct interest expense and income taxes are included in net income (loss). The tables below represent AEP’s reportable segment income statement information for the three months ended March 31, 2024 and 2023 and reportable segment balance sheet information as of March 31, 2024 and December 31, 2023. Three Months Ended March 31, 2024 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) Revenues from: External Customers $ 2,901.2 $ 1,483.2 $ 110.5 $ 515.9 $ 14.9 $ — $ 5,025.7 Other Operating Segments 46.7 7.0 386.8 47.6 37.9 (526.0) (b) — Total Revenues $ 2,947.9 $ 1,490.2 $ 497.3 $ 563.5 $ 52.8 $ (526.0) $ 5,025.7 Net Income (Loss) $ 562.3 $ 150.3 $ 209.8 $ 137.6 $ (54.3) $ — $ 1,005.7 Three Months Ended March 31, 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 $ 2,816.3 $ 1,455.3 $ 90.1 $ 326.9 $ 2.3 $ — $ 4,690.9 Other Operating Segments 41.5 8.9 365.4 0.1 27.8 (443.7) (b) — Total Revenues $ 2,857.8 $ 1,464.2 $ 455.5 $ 327.0 $ 30.1 $ (443.7) $ 4,690.9 Net Income (Loss) $ 262.2 $ 125.7 $ 182.4 $ (156.4) $ (13.5) $ — $ 400.4 March 31, 2024 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Consolidated (in millions) Total Assets $ 52,379.2 $ 25,283.4 $ 17,067.4 $ 2,257.5 $ 5,164.3 (c) $ (4,407.2) (d) $ 97,744.6 December 31, 2023 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Consolidated (in millions) Total Assets $ 51,802.1 $ 24,838.4 $ 16,575.6 $ 2,598.5 $ 5,194.0 (c) $ (4,324.6) (d) $ 96,684.0 (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) Represents inter-segment revenues. (c) Includes elimination of AEP Parent’s investments in wholly-owned subsidiary companies. (d) Reconciling Adjustments for Total Assets primarily include elimination of intercompany advances to affiliates and intercompany accounts receivable. 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 CODM 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 months ended March 31, 2024 and 2023 and reportable segment balance sheet information as of March 31, 2024 and December 31, 2023. Three Months Ended March 31, 2024 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo Consolidated (in millions) Revenues from: External Customers $ 97.0 $ — $ — $ 97.0 Sales to AEP Affiliates 383.4 — — 383.4 Other Revenues 2.4 — — 2.4 Total Revenues $ 482.8 $ — $ — $ 482.8 Net Income (Loss) $ 181.7 $ (0.5) (a) $ — $ 181.2 Three Months Ended March 31, 2023 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo Consolidated (in millions) Revenues from: External Customers $ 89.0 $ — $ — $ 89.0 Sales to AEP Affiliates 352.6 — — 352.6 Total Revenues $ 441.6 $ — $ — $ 441.6 Net Income $ 161.6 $ 1.1 (a) $ — $ 162.7 March 31, 2024 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Total Assets $ 15,609.4 $ 5,949.9 (b) $ (6,000.3) (c) $ 15,559.0 December 31, 2023 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Total Assets $ 15,120.6 $ 5,486.6 (b) $ (5,534.7) (c) $ 15,072.5 (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	3 Months Ended
Derivatives and Hedging	Mar. 31, 2024
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 March 31, 2024 December 31, 2023 Primary Risk AEP AEP Texas APCo I&M OPCo PSO SWEPCo AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power (MWhs) 233.5 — 7.0 3.4 2.2 2.2 1.6 246.8 — 16.8 5.9 2.2 4.1 2.9 Natural Gas (MMBtus) 176.8 — 43.0 — — 49.0 19.7 151.6 — 37.3 — — 34.9 17.9 Heating Oil and Gasoline (Gallons) 7.7 2.0 1.1 1.2 1.3 0.8 1.0 6.5 1.8 1.0 0.6 1.2 0.7 0.9 Interest Rate (USD) $ 69.6 $ — $ — $ — $ — $ — $ — $ 80.1 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt (USD) $ 1,500.0 $ 150.0 $ — $ — $ — $ — $ — $ 1,300.0 $ 150.0 $ — $ — $ — $ — $ — 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 $86 million and $46 million as of March 31, 2024 and December 31, 2023, 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 March 31, 2024 and December 31, 2023. The amount of cash collateral paid to third-parties netted against short-term and long-term risk management liabilities was immaterial for the Registrants as of March 31, 2024 and December 31, 2023. Location and Fair Value of Derivative Assets and Liabilities Recognized In the Balance Sheet The following tables represent the gross fair value of the Registrants’ derivative activity on the balance sheets. The derivative instruments are disclosed as gross. They 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.” 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. March 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Assets: (in millions) Current Risk Management Assets Risk Management Contracts - Commodity $ 436.2 $ 0.2 $ 9.9 $ 15.5 $ 0.1 $ 8.5 $ 5.5 Hedging Contracts - Commodity 35.4 — — — — — — Hedging Contracts - Interest Rate 8.3 2.3 — — — — — Total Current Risk Management Assets 479.9 2.5 9.9 15.5 0.1 8.5 5.5 Long-term Risk Management Assets Risk Management Contracts - Commodity 525.0 — 1.2 — — — — Hedging Contracts - Commodity 81.0 — — — — — — Hedging Contracts - Interest Rate — — — — — — — Total Long-term Risk Management Assets 606.0 — 1.2 — — — — Total Assets $ 1,085.9 $ 2.5 $ 11.1 $ 15.5 $ 0.1 $ 8.5 $ 5.5 Liabilities: Current Risk Management Liabilities Risk Management Contracts - Commodity $ 456.9 $ — $ 21.0 $ 9.0 $ 6.0 $ 29.1 $ 9.5 Hedging Contracts - Commodity 5.1 — — — — — — Hedging Contracts - Interest Rate 46.1 0.1 — — — — — Total Current Risk Management Liabilities 508.1 0.1 21.0 9.0 6.0 29.1 9.5 Long-term Risk Management Liabilities Risk Management Contracts - Commodity 430.0 — 3.3 — 35.0 2.8 1.8 Hedging Contracts - Commodity 0.6 — — — — — — Hedging Contracts - Interest Rate 70.4 — — — — — — Total Long-term Risk Management Liabilities 501.0 — 3.3 — 35.0 2.8 1.8 Total Liabilities $ 1,009.1 $ 0.1 $ 24.3 $ 9.0 $ 41.0 $ 31.9 $ 11.3 Total MTM Derivative Contract Net Assets (Liabilities) Recognized $ 76.8 $ 2.4 $ (13.2) $ 6.5 $ (40.9) $ (23.4) $ (5.8) December 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Assets: (in millions) Current Risk Management Assets Risk Management Contracts - Commodity $ 555.1 $ — $ 24.6 $ 30.1 $ — $ 19.7 $ 12.0 Hedging Contracts - Commodity 56.7 — — — — — — Hedging Contracts - Interest Rate — — — — — — — Total Current Risk Management Assets 611.8 — 24.6 30.1 — 19.7 12.0 Long-term Risk Management Assets Risk Management Contracts - Commodity 468.8 — 0.3 12.0 — — 0.5 Hedging Contracts - Commodity 86.8 — — — — — — Hedging Contracts - Interest Rate — — — — — — — Total Long-term Risk Management Assets 555.6 — 0.3 12.0 — — 0.5 Total Assets $ 1,167.4 $ — $ 24.9 $ 42.1 $ — $ 19.7 $ 12.5 Liabilities: Current Risk Management Liabilities Risk Management Contracts - Commodity $ 588.0 $ 0.2 $ 18.5 $ 5.4 $ 6.9 $ 29.7 $ 14.9 Hedging Contracts - Commodity 8.2 — — — — — — Hedging Contracts - Interest Rate 50.5 2.7 — — — — — Total Current Risk Management Liabilities 646.7 2.9 18.5 5.4 6.9 29.7 14.9 Long-term Risk Management Liabilities Risk Management Contracts - Commodity 377.6 — 6.9 0.2 43.9 1.0 1.7 Hedging Contracts - Commodity 2.2 — — — — — — Hedging Contracts - Interest Rate 56.9 — — — — — — Total Long-term Risk Management Liabilities 436.7 — 6.9 0.2 43.9 1.0 1.7 Total Liabilities $ 1,083.4 $ 2.9 $ 25.4 $ 5.6 $ 50.8 $ 30.7 $ 16.6 Total MTM Derivative Contract Net Assets (Liabilities) Recognized $ 84.0 $ (2.9) $ (0.5) $ 36.5 $ (50.8) $ (11.0) $ (4.1) Offsetting Assets and Liabilities The following tables show the net amounts of assets and liabilities presented on the balance sheets. The gross amounts offset include counterparty netting of risk management and hedging contracts and associated cash collateral in accordance with accounting guidance for “Derivatives and Hedging.” All derivative contracts subject to a master netting arrangement or similar agreement are offset on the balance sheets. March 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Assets: (in millions) Current Risk Management Assets Gross Amounts Recognized $ 479.9 $ 2.5 $ 9.9 $ 15.5 $ 0.1 $ 8.5 $ 5.5 Gross Amounts Offset (327.2) — (1.2) (4.3) — (0.6) (0.2) Net Amounts Presented 152.7 2.5 8.7 11.2 0.1 7.9 5.3 Long-term Risk Management Assets Gross Amounts Recognized 606.0 — 1.2 — — — — Gross Amounts Offset (291.6) — (1.2) — — — — Net Amounts Presented 314.4 — — — — — — Total Assets $ 467.1 $ 2.5 $ 8.7 $ 11.2 $ 0.1 $ 7.9 $ 5.3 Liabilities: Current Risk Management Liabilities Gross Amounts Recognized $ 508.1 $ 0.1 $ 21.0 $ 9.0 $ 6.0 $ 29.1 $ 9.5 Gross Amounts Offset (323.7) — (2.6) (8.3) — (0.6) (0.2) Net Amounts Presented 184.4 0.1 18.4 0.7 6.0 28.5 9.3 Long-term Risk Management Liabilities Gross Amounts Recognized 501.0 — 3.3 — 35.0 2.8 1.8 Gross Amounts Offset (221.5) — (1.2) — — — — Net Amounts Presented 279.5 — 2.1 — 35.0 2.8 1.8 Total Liabilities $ 463.9 $ 0.1 $ 20.5 $ 0.7 $ 41.0 $ 31.3 $ 11.1 Total MTM Derivative Contract Net Assets (Liabilities) $ 3.2 $ 2.4 $ (11.8) $ 10.5 $ (40.9) $ (23.4) $ (5.8) December 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Assets: (in millions) Current Risk Management Assets Gross Amounts Recognized $ 611.8 $ — $ 24.6 $ 30.1 $ — $ 19.7 $ 12.0 Gross Amounts Offset (394.3) — (2.2) (2.3) — (0.7) (0.4) Net Amounts Presented 217.5 — 22.4 27.8 — 19.0 11.6 Long-term Risk Management Assets Gross Amounts Recognized 555.6 — 0.3 12.0 — — 0.5 Gross Amounts Offset (234.4) — (0.3) (0.2) — — (0.5) Net Amounts Presented 321.2 — — 11.8 — — — Total Assets $ 538.7 $ — $ 22.4 $ 39.6 $ — $ 19.0 $ 11.6 Liabilities: Current Risk Management Liabilities Gross Amounts Recognized $ 646.7 $ 2.9 $ 18.5 $ 5.4 $ 6.9 $ 29.7 $ 14.9 Gross Amounts Offset (417.1) (0.2) (2.6) (3.4) (0.1) (0.8) (0.5) Net Amounts Presented 229.6 2.7 15.9 2.0 6.8 28.9 14.4 Long-term Risk Management Liabilities Gross Amounts Recognized 436.7 — 6.9 0.2 43.9 1.0 1.7 Gross Amounts Offset (194.9) — (0.3) (0.2) — — (0.5) Net Amounts Presented 241.8 — 6.6 — 43.9 1.0 1.2 Total Liabilities $ 471.4 $ 2.7 $ 22.5 $ 2.0 $ 50.7 $ 29.9 $ 15.6 Total MTM Derivative Contract Net Assets (Liabilities) $ 67.3 $ (2.7) $ (0.1) $ 37.6 $ (50.7) $ (10.9) $ (4.0) 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 March 31, 2024 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ (25.7) $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues (44.7) — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.1 (25.8) — — — Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 1.0 — 0.9 — — — — Maintenance 0.1 — — — — — — Regulatory Assets (a) 13.5 0.2 (0.1) (1.6) 8.6 (1.2) 4.9 Regulatory Liabilities (a) 52.7 0.2 13.1 2.2 — 18.3 15.0 Total Gain (Loss) on Risk Management Contracts $ (3.1) $ 0.4 $ 14.0 $ (25.2) $ 8.6 $ 17.1 $ 19.9 Three Months Ended March 31, 2023 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ (5.3) $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues (147.4) — — — — — — Electric Generation, Transmission and Distribution Revenues — — — (5.3) — — — Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 0.7 — 0.6 — — — — Maintenance 0.1 — — — — — — Regulatory Assets (a) (24.8) (0.4) (7.1) (0.5) (12.3) (1.2) (1.5) Regulatory Liabilities (a) (1.5) — (26.2) 1.2 — 18.0 11.9 Total Gain (Loss) on Risk Management Contracts $ (178.2) $ (0.4) $ (32.7) $ (4.6) $ (12.3) $ 16.8 $ 10.4 (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 March 31, 2024 December 31, 2023 March 31, 2024 December 31, 2023 (in millions) Long-term Debt (a) (b) $ (860.2) $ (878.2) $ 86.7 $ 68.4 (a) Amounts included within Noncurrent Liabilities line item Long-term Debt on the Balance Sheet. (b) Amounts include $(28) million and $(30) million as of March 31, 2024 and December 31, 2023, 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 March 31, 2024 2023 (in millions) Gain (Loss) on Interest Rate Contracts: Fair Value Hedging Instruments (a) $ (16.4) $ 6.9 Fair Value Portion of Long-term Debt (a) 16.4 (6.9) (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, Fuel and Other Consumables Used for Electric Generation 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 months ended March 31, 2024 and 2023, 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 March 31, 2024, AEP and AEP Texas applied cash flow hedging to outstanding interest rate derivatives and the other Registrant Subsidiaries did not. During the three months ended March 31, 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. 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 the Registrants’ Balance Sheets March 31, 2024 December 31, 2023 Portion Expected to Portion Expected to AOCI be Reclassed to AOCI be Reclassed to Gain (Loss) Net Income During Gain (Loss) Net Income During Net of Tax the Next Twelve Months Net of Tax the Next Twelve Months Commodity Interest Rate Commodity Interest Rate Commodity Interest Rate Commodity Interest Rate (in millions) AEP $ 87.2 $ 3.4 $ 24.0 $ 3.6 $ 104.9 $ (8.1) $ 38.3 $ 3.2 AEP Texas — 4.4 — 0.5 — 0.5 — 0.2 APCo — 5.7 — 0.8 — 5.9 — 0.8 I&M — (5.4) — (0.4) — (5.5) — (0.4) PSO — (0.2) — — — (0.2) — — SWEPCo — 1.2 — 0.3 — 1.3 — 0.3 As of March 31, 2024 the maximum length of time that AEP is hedging its exposure to variability in future cash flows related to forecasted transactions is 84 months. 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. The Registrants had no derivative contracts with collateral triggering events in a net liability position as of March 31, 2024 and December 31, 2023. 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 $116 million and $107 million and no cash collateral posted as of March 31, 2024 and December 31, 2023, respectively. If a cross-acceleration provision would have been triggered, settlement at fair value would have been required. The Registrant Subsidiaries’ derivative contracts with cross-acceleration provisions outstanding as of March 31, 2024 and December 31, 2023 were not material. 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 contracts with cross-default provisions in a net liability position of $235 million and $242 million and no cash collateral posted as of March 31, 2024 and December 31, 2023, respectively, after considering contractual netting arrangements. If a cross-default provision would have been triggered, settlement at fair value would have been required. APCo, PSO and SWEPCo had derivative contracts with cross-default provisions in a net liability position of $16 million, $31 million and $10 million, respectively, and no cash collateral posted as of March 31, 2024. APCo, PSO and SWEPCo had derivative contracts with cross-default provisions in a net liability position of $22 million, $29 million and $15 million, respectively, and no cash collateral posted as of December 31, 2023. The other Registrant Subsidiaries had no derivative contracts with cross-default provisions outstanding as of March 31, 2024 and December 31, 2023.

Fair Value Measurements

Fair Value Measurements	3 Months Ended
Fair Value Measurements	Mar. 31, 2024
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: March 31, 2024 December 31, 2023 Company Book Value Fair Value Book Value Fair Value (in millions) AEP $ 39,835.9 $ 36,392.2 $ 40,143.2 $ 37,325.7 AEP Texas 5,878.7 5,289.7 5,889.8 5,400.7 AEPTCo 5,860.7 5,066.3 5,414.4 4,796.9 APCo 5,670.9 5,370.8 5,588.3 5,390.1 I&M 3,478.5 3,182.3 3,499.4 3,291.6 OPCo 3,367.4 2,912.1 3,366.8 2,992.1 PSO 2,384.9 2,130.2 2,384.6 2,154.3 SWEPCo 3,647.6 3,170.6 3,646.9 3,209.7 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: March 31, 2024 Gross Gross Unrealized Unrealized Fair Other Temporary Investments and Restricted Cash Cost Gains Losses Value (in millions) Restricted Cash (a) $ 51.1 $ — $ — $ 51.1 Other Cash Deposits 15.4 — — 15.4 Fixed Income Securities – Mutual Funds (b) 164.7 — (6.8) 157.9 Equity Securities – Mutual Funds 14.7 29.0 — 43.7 Total Other Temporary Investments and Restricted Cash $ 245.9 $ 29.0 $ (6.8) $ 268.1 December 31, 2023 Gross Gross Unrealized Unrealized Fair Other Temporary Investments and Restricted Cash Cost Gains Losses Value (in millions) Restricted Cash (a) $ 48.9 $ — $ — $ 48.9 Other Cash Deposits 13.9 — — 13.9 Fixed Income Securities – Mutual Funds (b) 165.9 — (6.2) 159.7 Equity Securities – Mutual Funds 14.8 25.9 — 40.7 Total Other Temporary Investments and Restricted Cash $ 243.5 $ 25.9 $ (6.2) $ 263.2 (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 March 31, 2024 2023 (in millions) Proceeds from Investment Sales $ 3.0 $ — Purchases of Investments 1.5 1.0 Gross Realized Gains on Investment Sales 0.3 — Gross Realized Losses on Investment Sales 0.2 — 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: March 31, 2024 December 31, 2023 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 $ 25.2 $ — $ — $ — $ 16.8 $ — $ — $ — Fixed Income Securities: United States Government 1,267.0 16.5 (4.2) (25.7) 1,273.0 28.6 (3.9) (33.2) Corporate Debt 123.3 2.5 (6.0) (5.1) 132.1 4.8 (5.2) (8.6) State and Local Government 1.7 — — — 1.7 — — — Subtotal Fixed Income Securities 1,392.0 19.0 (10.2) (30.8) 1,406.8 33.4 (9.1) (41.8) Equity Securities - Domestic 2,695.4 2,119.1 (1.1) — 2,436.6 1,869.5 (0.9) — Spent Nuclear Fuel and Decommissioning Trusts $ 4,112.6 $ 2,138.1 $ (11.3) $ (30.8) $ 3,860.2 $ 1,902.9 $ (10.0) $ (41.8) The following table provides the securities activity within the decommissioning and SNF trusts: Three Months Ended March 31, 2024 2023 (in millions) Proceeds from Investment Sales $ 569.5 $ 517.6 Purchases of Investments 588.5 536.3 Gross Realized Gains on Investment Sales 5.4 48.5 Gross Realized Losses on Investment Sales 1.2 8.6 The base cost of fixed income securities was $1.4 billion and $1.4 billion as of March 31, 2024 and December 31, 2023, respectively. The base cost of equity securities was $577 million and $568 million as of March 31, 2024 and December 31, 2023, respectively. The fair value of fixed income securities held in the nuclear trust funds, summarized by contractual maturities, as of March 31, 2024 was as follows: Fair Value of Fixed Income Securities (in millions) Within 1 year $ 338.8 After 1 year through 5 years 598.0 After 5 years through 10 years 186.6 After 10 years 268.6 Total $ 1,392.0 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 March 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments and Restricted Cash Restricted Cash $ 51.1 $ — $ — $ — $ 51.1 Other Cash Deposits (a) — — — 15.4 15.4 Fixed Income Securities – Mutual Funds 157.9 — — — 157.9 Equity Securities – Mutual Funds (b) 43.7 — — — 43.7 Total Other Temporary Investments and Restricted Cash 252.7 — — 15.4 268.1 Risk Management Assets Risk Management Commodity Contracts (c) (d) 3.6 679.7 257.5 (593.9) 346.9 Cash Flow Hedges: Commodity Hedges (c) — 94.5 18.7 (1.3) 111.9 Interest Rate Hedges — 8.3 — — 8.3 Total Risk Management Assets 3.6 782.5 276.2 (595.2) 467.1 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 13.3 — — 11.9 25.2 Fixed Income Securities: United States Government — 1,267.0 — — 1,267.0 Corporate Debt — 123.3 — — 123.3 State and Local Government — 1.7 — — 1.7 Subtotal Fixed Income Securities — 1,392.0 — — 1,392.0 Equity Securities – Domestic (b) 2,695.4 — — — 2,695.4 Total Spent Nuclear Fuel and Decommissioning Trusts 2,708.7 1,392.0 — 11.9 4,112.6 Total Assets $ 2,965.0 $ 2,174.5 $ 276.2 $ (567.9) $ 4,847.8 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (d) $ 21.0 $ 688.4 $ 157.1 $ (520.3) $ 346.2 Cash Flow Hedges: Commodity Hedges (c) — 2.5 — (1.3) 1.2 Interest Rate Hedges — 1.7 — — 1.7 Fair Value Hedges — 114.8 — — 114.8 Total Risk Management Liabilities $ 21.0 $ 807.4 $ 157.1 $ (521.6) $ 463.9 AEP Assets and Liabilities Measured at Fair Value on a Recurring Basis December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments and Restricted Cash Restricted Cash $ 48.9 $ — $ — $ — $ 48.9 Other Cash Deposits (a) — — — 13.9 13.9 Fixed Income Securities – Mutual Funds 159.7 — — — 159.7 Equity Securities – Mutual Funds (b) 40.7 — — — 40.7 Total Other Temporary Investments and Restricted Cash 249.3 — — 13.9 263.2 Risk Management Assets Risk Management Commodity Contracts (c) (f) 9.7 736.9 274.3 (617.0) 403.9 Cash Flow Hedges: Commodity Hedges (c) — 123.5 19.8 (8.5) 134.8 Total Risk Management Assets 9.7 860.4 294.1 (625.5) 538.7 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 7.8 — — 9.0 16.8 Fixed Income Securities: United States Government — 1,273.0 — — 1,273.0 Corporate Debt — 132.1 — — 132.1 State and Local Government — 1.7 — — 1.7 Subtotal Fixed Income Securities — 1,406.8 — — 1,406.8 Equity Securities – Domestic (b) 2,436.6 — — — 2,436.6 Total Spent Nuclear Fuel and Decommissioning Trusts 2,444.4 1,406.8 — 9.0 3,860.2 Total Assets $ 2,703.4 $ 2,267.2 $ 294.1 $ (602.6) $ 4,662.1 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (f) $ 24.7 $ 783.8 $ 154.1 $ (600.3) $ 362.3 Cash Flow Hedges: Commodity Hedges (c) — 9.6 0.6 (8.5) 1.7 Interest Rate Hedges — 9.0 — — 9.0 Fair Value Hedges — 98.4 — — 98.4 Total Risk Management Liabilities $ 24.7 $ 900.8 $ 154.7 $ (608.8) $ 471.4 AEP Texas Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 42.7 $ — $ — $ — $ 42.7 Risk Management Assets Risk Management Commodity Contracts (c) — 0.2 — 2.3 2.5 Cash Flow Hedges: Interest Rate Hedges — 2.3 — (2.3) — Total Risk Management Assets — 2.5 — — 2.5 Total Assets $ 42.7 $ 2.5 $ — $ — $ 45.2 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ — $ — $ 0.1 $ 0.1 Cash Flow Hedges: Interest Rate Hedges — 0.1 — (0.1) — Total Liabilities $ — $ 0.1 $ — $ — $ 0.1 December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 34.0 $ — $ — $ — $ 34.0 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 0.2 $ — $ (0.2) $ — Cash Flow Hedges: Interest Rate Hedges — 2.7 — — 2.7 Total Risk Management Liabilities $ — $ 2.9 $ — $ (0.2) $ 2.7 APCo Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 8.4 $ — $ — $ — $ 8.4 Risk Management Assets Risk Management Commodity Contracts (c) — 2.1 8.6 (2.0) 8.7 Total Assets $ 8.4 $ 2.1 $ 8.6 $ (2.0) $ 17.1 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 19.3 $ 4.6 $ (3.4) $ 20.5 December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 14.9 $ — $ — $ — $ 14.9 Risk Management Assets Risk Management Commodity Contracts (c) — 1.1 23.5 (2.2) 22.4 Total Assets $ 14.9 $ 1.1 $ 23.5 $ (2.2) $ 37.3 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 24.0 $ 1.1 $ (2.6) $ 22.5 I&M Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ 13.1 $ 1.8 $ (3.7) $ 11.2 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 13.3 — — 11.9 25.2 Fixed Income Securities: United States Government — 1,267.0 — — 1,267.0 Corporate Debt — 123.3 — — 123.3 State and Local Government — 1.7 — — 1.7 Subtotal Fixed Income Securities — 1,392.0 — — 1,392.0 Equity Securities - Domestic (b) 2,695.4 — — — 2,695.4 Total Spent Nuclear Fuel and Decommissioning Trusts 2,708.7 1,392.0 — 11.9 4,112.6 Total Assets $ 2,708.7 $ 1,405.1 $ 1.8 $ 8.2 $ 4,123.8 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 7.6 $ 0.8 $ (7.7) $ 0.7 December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ 37.4 $ 4.5 $ (2.3) $ 39.6 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 7.8 — — 9.0 16.8 Fixed Income Securities: United States Government — 1,273.0 — — 1,273.0 Corporate Debt — 132.1 — — 132.1 State and Local Government — 1.7 — — 1.7 Subtotal Fixed Income Securities — 1,406.8 — — 1,406.8 Equity Securities - Domestic (b) 2,436.6 — — — 2,436.6 Total Spent Nuclear Fuel and Decommissioning Trusts 2,444.4 1,406.8 — 9.0 3,860.2 Total Assets $ 2,444.4 $ 1,444.2 $ 4.5 $ 6.7 $ 3,899.8 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 3.7 $ 1.7 $ (3.4) $ 2.0 OPCo Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ 0.1 $ — $ — $ 0.1 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ — $ 41.0 $ — $ 41.0 December 31, 2023 Level 1 Level 2 Level 3 Other Total Liabilities: (in millions) Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 0.2 $ 50.6 $ (0.1) $ 50.7 PSO Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ 0.1 $ 8.4 $ (0.6) $ 7.9 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 31.2 $ 0.7 $ (0.6) $ 31.3 December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ — $ 19.7 $ (0.7) $ 19.0 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 29.6 $ 1.1 $ (0.8) $ 29.9 SWEPCo Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ 0.1 $ 5.5 $ (0.3) $ 5.3 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 11.1 $ 0.2 $ (0.2) $ 11.1 December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ 0.5 $ 12.0 $ (0.9) $ 11.6 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 15.7 $ 0.9 $ (1.0) $ 15.6 (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 March 31, 2024 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $(14) million in 2024 and $(3) million in periods 2025-2027; Level 2 matures $(65) million in 2024, $51 million in periods 2025-2027 and $5 million in periods 2028-2029; Level 3 matures $34 million in 2024, $55 million in periods 2025-2027, $23 million in periods 2028-2029 and $(12) million in periods 2030-2032. 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, 2023 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $(11) million in 2024 and $(4) million in 2025-2027; Level 2 matures $(99) million in 2024, $(44) million in periods 2025-2027, $7 million in periods 2028-2029 and $2 million in periods 2030-2033; Level 3 matures $74 million in 2024, $43 million in periods 2025-2027, $18 million in periods 2028-2029 and $(16) million in periods 2030-2033. Risk management commodity contracts are substantially comprised of power contracts. 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 March 31, 2024 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of December 31, 2023 $ 139.4 $ 22.4 $ 2.8 $ (50.6) $ 18.6 $ 11.1 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 46.9 9.2 3.2 (0.4) 18.5 14.7 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) 11.3 — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 0.6 — — — — — Settlements (96.6) (26.8) (4.8) 2.6 (31.3) (23.6) Transfers into Level 3 (d) (e) 4.6 — — — — — Transfers out of Level 3 (e) 2.1 — — — — 0.5 Changes in Fair Value Allocated to Regulated Jurisdictions (f) 10.8 (0.8) (0.2) 7.4 1.9 2.6 Balance as of March 31, 2024 $ 119.1 $ 4.0 $ 1.0 $ (41.0) $ 7.7 $ 5.3 Three Months Ended March 31, 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) (7.1) (31.9) 1.2 (1.3) 16.6 12.9 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) 14.8 — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) (13.9) — — — — — Settlements (96.6) (27.3) (4.2) 1.0 (34.3) (23.0) Transfers into Level 3 (d) (e) (6.1) — — — — — Transfers out of Level 3 (e) 1.0 — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) (7.4) (4.2) (0.5) (6.6) 3.3 1.7 Balance as of March 31, 2023 $ 45.1 $ 5.7 $ 1.1 $ (46.9) $ 9.3 $ 5.8 (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 March 31, 2024 Significant Input/Range Type of Fair Value Valuation Unobservable Weighted Company Input Assets Liabilities Technique Input Low High Average (a) (in millions) AEP Energy Contracts $ 246.5 $ 146.1 Discounted Cash Flow Forward Market Price (b) $ 10.31 $ 169.47 $ 49.39 AEP FTRs 29.7 11.0 Discounted Cash Flow Forward Market Price (b) (79.90) 23.79 (0.35) APCo FTRs 8.6 4.6 Discounted Cash Flow Forward Market Price (b) (0.38) 5.05 0.61 I&M FTRs 1.8 0.8 Discounted Cash Flow Forward Market Price (b) 0.03 6.82 0.84 OPCo Energy Contracts — 41.0 Discounted Cash Flow Forward Market Price (b) 19.72 75.88 47.20 PSO FTRs 8.4 0.7 Discounted Cash Flow Forward Market Price (b) (79.90) 3.13 (3.48) SWEPCo FTRs 5.5 0.2 Discounted Cash Flow Forward Market Price (b) (79.90) 3.13 (3.48) December 31, 2023 Significant Input/Range Type of Fair Value Valuation Unobservable Weighted Company Input Assets Liabilities Technique Input Low High Average (a) (in millions) AEP Energy Contracts $ 225.5 $ 144.9 Discounted Cash Flow Forward Market Price (b) $ 5.21 $ 153.77 $ 45.05 AEP Natural Gas Contracts — 0.5 Discounted Cash Flow Forward Market Price (c) 3.11 3.11 3.11 AEP FTRs 68.6 9.3 Discounted Cash Flow Forward Market Price (b) (25.45) 17.07 — APCo FTRs 23.5 1.1 Discounted Cash Flow Forward Market Price (b) (1.04) 6.45 1.36 I&M FTRs 4.5 1.7 Discounted Cash Flow Forward Market Price (b) (1.48) 8.40 (0.85) OPCo Energy Contracts — 50.6 Discounted Cash Flow Forward Market Price (b) 22.92 67.53 42.85 PSO FTRs 19.7 1.1 Discounted Cash Flow Forward Market Price (b) (25.45) 4.80 (4.33) SWEPCo Natural Gas Contracts — 0.5 Discounted Cash Flow Forward Market Price (c) 3.11 3.11 3.11 SWEPCo FTRs 12.0 0.4 Discounted Cash Flow Forward Market Price (b) (25.45) 4.80 (4.33) (a) The weighted average is the product of the forward market price of the underlying commodity and volume weighted by term. (b) Represents market prices in dollars per MWh. (c) Represents market prices in dollars per MMBtu. 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 March 31, 2024 and December 31, 2023: 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	3 Months Ended
Income Taxes	Mar. 31, 2024
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 2024 and 2023, adjusted for tax expense associated with certain discrete items. In the first quarter of 2024, I&M, PSO, and SWEPCo recorded tax benefits of $61 million, $49 million, and $114 million, respectively, related to the reduction of a regulatory liability associated with the IRS PLRs received, driving a reduction to the interim ETR resulting in AEP’s tax rate of (16.5)% as shown below. The ETR for each of the Registrants are included in the following tables: Three Months Ended March 31, 2024 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 % 0.2 % 2.6 % 2.4 % 3.9 % 1.0 % 3.7 % 1.7 % Tax Reform Excess ADIT Reversal (2.3) % (1.3) % 0.2 % (13.4) % (0.5) % (6.0) % (2.0) % 4.6 % Remeasurement of Excess ADIT (29.7) % — % — % — % (58.2) % — % (263.3) % (224.7) % Production and Investment Tax Credits (6.8) % (0.2) % — % (0.1) % (1.1) % — % (49.6) % (23.8) % Flow Through — % 0.1 % 0.3 % (0.3) % (2.8) % 0.6 % 0.2 % 0.6 % AFUDC Equity (1.2) % (1.5) % (1.8) % (0.4) % (0.7) % (1.0) % (1.3) % (1.3) % Discrete Tax Adjustments 0.2 % — % — % — % — % — % 0.9 % 1.3 % Other 0.2 % 0.5 % — % 0.1 % — % 0.2 % 1.2 % (0.8) % Effective Income Tax Rate (16.5) % 18.8 % 22.3 % 9.3 % (38.4) % 15.8 % (289.2) % (221.4) % Three Months Ended March 31, 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 1.9 % 0.3 % 2.6 % 2.4 % 3.6 % 1.0 % 3.2 % (0.4) % Tax Reform Excess ADIT Reversal (6.2) % (1.5) % 0.3 % (4.6) % (7.9) % (6.8) % (18.7) % (3.8) % Production and Investment Tax Credits (9.7) % (0.2) % — % — % (1.1) % — % (55.7) % (26.4) % Flow Through 0.1 % 0.2 % 0.3 % 0.6 % (1.8) % 0.5 % 0.3 % 0.5 % AFUDC Equity (1.4) % (1.5) % (1.6) % (0.7) % (0.5) % (0.8) % (1.4) % (0.8) % Discrete Tax Adjustments (3.2) % — % — % 3.2 % 1.8 % — % — % — % Other 0.1 % 0.1 % 0.1 % — % — % — % (2.0) % (0.8) % Effective Income Tax Rate 2.6 % 18.4 % 22.7 % 21.9 % 15.1 % 14.9 % (53.3) % (10.7) % 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 2017-2020 tax returns to May 31, 2025, to allow time for the current IRS audit to be completed including a refund claim approval by the Congressional Joint Committee on Taxation. 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 immaterial IRS proposed adjustments on the 2017 tax return. The IRS exam is complete, and AEP is currently waiting on 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. AEP and subsidiaries are applicable corporations for purposes of the CAMT in 2024. 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 are presented in the operating section of the statements of cash flows consistent with the presentation of cash taxes paid. AEP presents the loss on sale of tax credits through income tax expense. In June 2023, the IRS issued temporary regulations related to the transfer of tax credits. In 2023, AEP, on behalf of PSO, SWEPCo and AEP Energy Supply, LLC, entered into transferability agreements with nonaffiliated parties to sell 2023 generated PTCs resulting in cash proceeds of approximately $174 million with $102 million received in 2023, $62 million received in the first quarter of 2024 and the remaining $10 million was received in April 2024. AEP expects to continue to explore the ability to efficiently monetize its tax credits through third party transferability agreements.

Financing Activities

Financing Activities	3 Months Ended
Financing Activities	Mar. 31, 2024
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 2023, 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 $1.7 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 three months ended March 31, 2024. 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 March 31, 2024 December 31, 2023 (in millions) Senior Unsecured Notes $ 34,606.1 $ 33,779.4 Pollution Control Bonds 1,771.0 1,771.6 Notes Payable 163.5 193.3 Securitization Bonds 343.8 368.9 Spent Nuclear Fuel Obligation (a) 304.4 300.4 Junior Subordinated Notes 1,588.2 2,388.1 Other Long-term Debt 1,058.9 1,341.5 Total Long-term Debt Outstanding 39,835.9 40,143.2 Long-term Debt Due Within One Year 1,198.6 2,490.5 Long-term Debt $ 38,637.3 $ 37,652.7 (a) Pursuant to the Nuclear Waste Policy Act of 1982, I&M, a nuclear licensee, has an obligation to the United States Department of Energy for SNF disposal. The obligation includes a one-time fee for nuclear fuel consumed prior to April 7, 1983. Trust fund assets related to this obligation were $355 million and $348 million as of March 31, 2024 and December 31, 2023, respectively, and are included in Spent Nuclear Fuel and Decommissioning Trusts on the balance sheets. Long-term Debt Activity Long-term debt and other securities issued, retired and principal payments made during the first three months of 2024 are shown in the following tables: Principal Interest Company Type of Debt Amount (a) Rate Due Date Issuances: (in millions) (%) AEPTCo Senior Unsecured Notes $ 450.0 5.15 2034 APCo Senior Unsecured Notes 400.0 5.65 2034 Non-Registrant: Transource Energy Other Long-term Debt 18.0 Variable 2025 Total Issuances $ 868.0 (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 Junior Subordinated Notes $ 805.0 2.03 2024 AEP Texas Securitization Bonds 11.9 2.06 2025 APCo Other Long-term Debt 300.0 Variable 2024 APCo Securitization Bonds 13.4 3.77 2028 I&M Notes Payable 1.2 Variable 2024 I&M Notes Payable 0.9 Variable 2025 I&M Notes Payable 4.0 0.93 2025 I&M Notes Payable 5.0 3.44 2026 I&M Notes Payable 6.8 5.93 2027 I&M Notes Payable 6.8 6.01 2028 I&M Other Long-term Debt 0.7 6.00 2025 PSO Other Long-term Debt 0.1 3.00 2027 Non-Registrant: AEGCo Notes Payable 5.0 2.43 2028 Transource Energy Senior Unsecured Notes 1.4 2.75 2050 Total Retirements and Principal Payments $ 1,162.2 Long-term Debt Subsequent Events In April 2024, APCo remarketed $86 million of Pollution Control Bonds. In April 2024, I&M issued $80 million of 6.41% Notes Payable due in 2028. In April 2024, I&M retired $8 million of Notes Payable related to DCC Fuel. In April 2024, WPCo issued $450 million of 6.89% Notes Payable due in 2034. In April 2024, WPCo retired $265 million of Other Long-term Debt. 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 0.2% of consolidated tangible net assets as of March 31, 2024. 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 (Applies to all Registrant Subsidiaries) AEP subsidiaries use a corporate borrowing program to meet their short-term borrowing needs. 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 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 March 31, 2024 and December 31, 2023 are included in Advances to Affiliates and Advances from Affiliates, respectively, on the Registrant Subsidiaries’ balance sheets. The Utility Money Pool participants’ money pool activity and corresponding authorized borrowing limits for the three months ended March 31, 2024 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 March 31, 2024 Limit (in millions) AEP Texas $ 267.9 $ — $ 191.2 $ — $ (267.9) $ 600.0 AEPTCo 313.3 298.0 178.5 75.3 272.9 820.0 (a) APCo 399.5 51.1 205.5 20.3 37.4 750.0 I&M 125.5 — 60.2 — (73.2) 500.0 OPCo 295.2 — 143.4 — (295.2) 500.0 PSO 264.6 — 128.8 — (264.6) 750.0 SWEPCo 254.5 — 161.1 — (254.5) 750.0 (a) Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions. The activity in the above table does not include short-term lending activity of certain AEP nonutility subsidiaries. AEP Texas’ wholly-owned subsidiary, AEP Texas North Generation Company, LLC and SWEPCo’s wholly-owned subsidiary, Mutual Energy SWEPCo, LLC participate in the Nonutility Money Pool. The amounts of outstanding loans to the Nonutility Money Pool as of March 31, 2024 and December 31, 2023 are included in Advances to Affiliates on the subsidiaries’ balance sheets. The Nonutility Money Pool participants’ activity for the three months ended March 31, 2024 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 March 31, 2024 (in millions) AEP Texas $ 7.1 $ 7.0 $ 7.0 SWEPCo 2.3 2.2 2.3 AEP has a direct financing relationship with AEPTCo to meet its short-term borrowing needs. The amounts of borrowings from AEP as of March 31, 2024 and December 31, 2023 are included in Advances from Affiliates on AEPTCo’s balance sheets. AEPTCo’s direct financing activities with AEP and corresponding authorized borrowing limit for the three months ended March 31, 2024 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 March 31, 2024 March 31, 2024 Borrowing Limit (in millions) $ 44.4 $ 148.5 $ 4.4 $ 72.9 $ 3.7 $ — $ 50.0 (a) (a) Amount represents the authorized short-term borrowing limit from FERC or state regulatory agencies not otherwise included in the utility money pool above. The maximum and minimum interest rates for funds either borrowed from or loaned to the Utility Money Pool are summarized in the following table: Three Months Ended March 31, 2024 2023 Maximum Interest Rate 5.79 % 5.42 % Minimum Interest Rate 5.66 % 4.66 % The average interest rates for funds borrowed from and loaned to the Utility Money Pool are summarized in the following table: Average Interest Rate for Funds Average Interest Rate for Funds Borrowed from the Utility Money Pool Loaned to the Utility Money Pool for Three Months Ended March 31, for Three Months Ended March 31, Company 2024 2023 2024 2023 AEP Texas 5.71 % 5.18 % — % — % AEPTCo 5.72 % 5.09 % 5.70 % 5.29 % APCo 5.74 % 5.14 % 5.72 % 5.12 % I&M 5.73 % 5.12 % — % 5.16 % OPCo 5.71 % 5.17 % — % — % PSO 5.71 % 4.84 % — % 5.11 % SWEPCo 5.71 % 5.12 % — % — % Maximum, minimum and average interest rates for funds loaned to the Nonutility Money Pool are summarized in the following table: Three Months Ended March 31, 2024 Three Months Ended March 31, 2023 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 5.79 % 5.66 % 5.72 % 5.42 % 4.66 % 5.12 % SWEPCo 5.79 % 5.66 % 5.72 % 5.42 % 4.66 % 5.13 % 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 Three Months for Funds for Funds for Funds for Funds for Funds for Funds Ended Borrowed Borrowed Loaned Loaned Borrowed Loaned March 31, from AEP from AEP to AEP to AEP from AEP to AEP 2024 5.79 % 5.66 % 5.79 % 5.66 % 5.74 % 5.71 % 2023 5.38 % 4.53 % 5.38 % 4.53 % 5.03 % 5.15 % Short-term Debt (Applies to AEP and SWEPCo) Outstanding short-term debt was as follows: March 31, 2024 December 31, 2023 Outstanding Interest Outstanding Interest Company Type of Debt Amount Rate (a) Amount Rate (a) (dollars in millions) AEP Securitized Debt for Receivables (b) $ 900.0 5.54 % $ 888.0 5.65 % AEP Commercial Paper 2,832.2 5.61 % 1,937.9 5.69 % SWEPCo Notes Payable 5.4 7.68 % 4.3 7.71 % Total Short-term Debt $ 3,737.6 $ 2,830.2 (a) Weighted-average rate as of March 31, 2024 and December 31, 2023, 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 $900 million from bank conduits to purchase receivables and expires in September 2025. As of March 31, 2024, 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 March 31, 2024 2023 (dollars in millions) Effective Interest Rates on Securitization of Accounts Receivable 5.61 % 4.86 % Net Uncollectible Accounts Receivable Written-Off $ 8.1 $ 6.9 March 31, 2024 December 31, 2023 (in millions) Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts $ 1,164.2 $ 1,207.4 Short-term – Securitized Debt of Receivables 900.0 888.0 Delinquent Securitized Accounts Receivable 58.2 52.2 Bad Debt Reserves Related to Securitization 42.6 42.0 Unbilled Receivables Related to Securitization 336.9 409.8 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. 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 March 31, 2024 December 31, 2023 (in millions) APCo $ 196.5 $ 184.6 I&M 167.0 156.4 OPCo 536.0 541.7 PSO 96.3 134.6 SWEPCo 144.2 168.3 The fees paid to AEP Credit for customer accounts receivable sold were: Three Months Ended March 31, Company 2024 2023 (in millions) APCo $ 4.2 $ 4.9 I&M 4.1 3.9 OPCo 7.4 7.3 PSO 3.4 3.2 SWEPCo 4.8 4.3 The proceeds on the sale of receivables to AEP Credit were: Three Months Ended March 31, Company 2024 2023 (in millions) APCo $ 536.0 $ 506.2 I&M 529.7 525.4 OPCo 845.7 884.4 PSO 361.6 416.3 SWEPCo 425.4 437.6

Variable Interest Entities

Variable Interest Entities	3 Months Ended
Variable Interest Entities	Mar. 31, 2024
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. Management believes that significant assumptions and judgments were applied consistently. AEP holds ownership interests in businesses with varying ownership structures. Partnership interests and other variable interests are evaluated to determine if each entity is a VIE, and if so, whether or not the VIE should be consolidated into AEP’s financial statements. AEP has not provided material financial or other support that was not previously contractually required to any of its consolidated VIEs. If an entity is determined not to be a VIE, or if the entity is determined to be a VIE and AEP is not deemed to be the primary beneficiary, the entity is accounted for under the equity method of accounting. Consolidated Variable Interests Entities The Annual Report on Form 10-K for the year ended December 31, 2023 includes a detailed discussion of the Registrants’ consolidated VIEs. The balances below represent the assets and liabilities of consolidated VIEs. These balances include intercompany transactions that are eliminated upon consolidation. March 31, 2024 Consolidated VIEs SWEPCo I&M AEP Texas Transition Funding AEP Texas Restoration Funding APCo Appalachian Consumer Rate Relief Funding AEP Credit Protected Transource Energy (in millions) ASSETS Current Assets $ 5.1 $ 75.3 $ 40.1 $ 20.4 $ 6.3 $ 1,165.3 $ 211.6 $ 31.7 Net Property, Plant and Equipment — 129.5 — — — — — 536.9 Other Noncurrent Assets 140.1 63.5 55.3 (a) 139.7 (b) 130.3 (c) 10.2 — 9.3 Total Assets $ 145.2 $ 268.3 $ 95.4 $ 160.1 $ 136.6 $ 1,175.5 $ 211.6 $ 577.9 LIABILITIES AND EQUITY Current Liabilities $ 22.8 $ 75.1 $ 76.3 $ 36.4 $ 29.0 $ 1,113.7 $ 52.3 $ 22.5 Noncurrent Liabilities 122.1 193.2 14.7 122.4 105.7 1.0 90.8 258.8 Equity 0.3 — 4.4 1.3 1.9 60.8 68.5 296.6 Total Liabilities and Equity $ 145.2 $ 268.3 $ 95.4 $ 160.1 $ 136.6 $ 1,175.5 $ 211.6 $ 577.9 (a) Includes an intercompany item eliminated in consolidation of $6 million. (b) Includes an intercompany item eliminated in consolidation of $6 million. (c) Includes an intercompany item eliminated in consolidation of $2 million . December 31, 2023 Consolidated VIEs SWEPCo I&M AEP Texas Transition Funding AEP Texas Restoration Funding APCo AEP Credit Protected Transource Energy (in millions) ASSETS Current Assets $ 4.2 $ 81.9 $ 25.5 $ 27.5 $ 13.3 $ 1,208.8 $ 205.3 $ 36.9 Net Property, Plant and Equipment — 153.8 — — — — — 533.4 Other Noncurrent Assets 150.7 81.7 71.4 (a) 145.6 (b) 138.2 (c) 9.6 — 5.1 Total Assets $ 154.9 $ 317.4 $ 96.9 $ 173.1 $ 151.5 $ 1,218.4 $ 205.3 $ 575.4 LIABILITIES AND EQUITY Current Liabilities $ 19.9 $ 81.7 $ 75.5 $ 36.8 $ 29.9 $ 1,155.0 $ 49.2 $ 45.3 Noncurrent Liabilities 134.8 235.7 17.0 135.1 119.7 0.9 91.7 241.5 Equity 0.2 — 4.4 1.2 1.9 62.5 64.4 288.6 Total Liabilities and Equity $ 154.9 $ 317.4 $ 96.9 $ 173.1 $ 151.5 $ 1,218.4 $ 205.3 $ 575.4 (a) Includes an intercompany item eliminated in consolidation of $8 million . (b) Includes an intercompany item eliminated in consolidation of $6 million . (c) Includes an intercompany item eliminated in consolidation of $2 million . 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, 2023 includes a detailed discussion of significant variable interests in non-consolidated VIEs and other significant equity method investments. As of December 31, 2023, AEP no longer owns interests in four joint ventures due to the sale of the Competitive Contracted Renewables Portfolio. Previously held by AEP Wind Holdings, LLC, the interests were accounted for under the equity method. See the “Disposition of the Competitive Contracted Renewables Portfolio” section of Note 6 for additional information.

Revenue from Contracts with Cus

Revenue from Contracts with Customers	3 Months Ended
Revenue from Contracts with Customers	Mar. 31, 2024
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 March 31, 2024 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation & Marketing Corporate and Other Reconciling Adjustments AEP Consolidated (in millions) Retail Revenues: Residential Revenues $ 1,212.3 $ 703.8 $ — $ — $ — $ — $ 1,916.1 Commercial Revenues 645.1 397.0 — — — — 1,042.1 Industrial Revenues (a) 647.1 136.1 — — — (0.2) 783.0 Other Retail Revenues 55.3 13.9 — — — — 69.2 Total Retail Revenues 2,559.8 1,250.8 — — — (0.2) 3,810.4 Wholesale and Competitive Retail Revenues: Generation Revenues 235.9 — — 27.4 — 0.1 263.4 Transmission Revenues (b) 118.9 179.8 488.7 — — (418.6) 368.8 Renewable Generation Revenues (a) — — — 6.3 — (1.4) 4.9 Retail, Trading and Marketing Revenues (c) — — — 571.4 0.5 (46.2) 525.7 Total Wholesale and Competitive Retail Revenues 354.8 179.8 488.7 605.1 0.5 (466.1) 1,162.8 Other Revenues from Contracts with Customers (d) 59.7 51.0 8.1 1.3 60.4 (68.7) 111.8 Total Revenues from Contracts with Customers 2,974.3 1,481.6 496.8 606.4 60.9 (535.0) 5,085.0 Other Revenues: Alternative Revenue Programs (e) (0.7) 0.7 0.5 — — 1.0 1.5 Other Revenues (a) (f) (25.7) 7.9 — (42.9) (8.1) 8.0 (60.8) Total Other Revenues (26.4) 8.6 0.5 (42.9) (8.1) 9.0 (59.3) Total Revenues $ 2,947.9 $ 1,490.2 $ 497.3 $ 563.5 $ 52.8 $ (526.0) $ 5,025.7 (a) Amounts include affiliated and nonaffiliated revenues. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $387 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $46 million. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $48 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. Three Months Ended March 31, 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 $ 1,170.4 $ 656.8 $ — $ — $ — $ — $ 1,827.2 Commercial Revenues 633.4 375.9 — — — — 1,009.3 Industrial Revenues 670.3 212.9 — — — (0.2) 883.0 Other Retail Revenues 56.8 12.1 — — — — 68.9 Total Retail Revenues 2,530.9 1,257.7 — — — (0.2) 3,788.4 Wholesale and Competitive Retail Revenues: Generation Revenues 182.8 — — 32.4 — — 215.2 Transmission Revenues (a) 114.7 164.2 450.1 — — (401.8) 327.2 Renewable Generation Revenues (b) — — — 21.3 — (0.1) 21.2 Retail, Trading and Marketing Revenues (b) — — — 413.7 (0.3) 0.1 413.5 Total Wholesale and Competitive Retail Revenues 297.5 164.2 450.1 467.4 (0.3) (401.8) 977.1 Other Revenues from Contracts with Customers (c) 32.6 42.8 3.6 0.6 29.4 (43.7) 65.3 Total Revenues from Contracts with Customers 2,861.0 1,464.7 453.7 468.0 29.1 (445.7) 4,830.8 Other Revenues: Alternative Revenue Programs (d) (3.1) (11.6) 1.8 — — 2.9 (10.0) Other Revenues (b) (e) (0.1) 11.1 — (141.0) 1.0 (0.9) (129.9) Total Other Revenues (3.2) (0.5) 1.8 (141.0) 1.0 2.0 (139.9) Total Revenues $ 2,857.8 $ 1,464.2 $ 455.5 $ 327.0 $ 30.1 $ (443.7) $ 4,690.9 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $357 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 $29 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 March 31, 2024 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 147.3 $ — $ 526.3 $ 224.8 $ 556.5 $ 158.2 $ 182.4 Commercial Revenues 110.9 — 188.3 144.8 286.1 103.0 140.0 Industrial Revenues (a) 35.6 — 196.4 147.9 100.5 80.3 95.0 Other Retail Revenues 9.7 — 28.1 1.3 4.2 21.5 2.6 Total Retail Revenues 303.5 — 939.1 518.8 947.3 363.0 420.0 Wholesale Revenues: Generation Revenues (b) — — 85.1 137.3 — 2.2 47.1 Transmission Revenues (c) 155.9 475.4 47.1 10.1 23.8 10.8 39.6 Total Wholesale Revenues 155.9 475.4 132.2 147.4 23.8 13.0 86.7 Other Revenues from Contracts with Customers (d) 8.8 8.1 21.7 27.6 42.2 12.0 9.6 Total Revenues from Contracts with Customers 468.2 483.5 1,093.0 693.8 1,013.3 388.0 516.3 Other Revenues: Alternative Revenue Programs (e) (1.8) (0.7) (0.1) (0.5) 2.6 (0.2) (0.1) Other Revenues (a) — — 0.1 (25.9) 7.9 — — Total Other Revenues (1.8) (0.7) — (26.4) 10.5 (0.2) (0.1) Total Revenues $ 466.4 $ 482.8 $ 1,093.0 $ 667.4 $ 1,023.8 $ 387.8 $ 516.2 (a) Amounts include affiliated and nonaffiliated revenues. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $41 million primarily related to the PPA with KGPCo. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $384 million, APCo was $21 million and SWEPCo was $14 million. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $18 million primarily related 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. Three Months Ended March 31, 2023 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 130.7 $ — $ 470.5 $ 239.6 $ 526.0 $ 170.9 $ 175.9 Commercial Revenues 97.3 — 171.3 138.9 278.5 109.1 143.5 Industrial Revenues 39.3 — 185.8 152.6 173.6 98.3 104.2 Other Retail Revenues 8.3 — 26.2 1.3 3.8 24.2 2.6 Total Retail Revenues 275.6 — 853.8 532.4 981.9 402.5 426.2 Wholesale Revenues: Generation Revenues (a) — — 80.2 104.0 — 0.9 39.6 Transmission Revenues (b) 146.3 438.7 41.4 8.1 17.9 11.3 42.9 Total Wholesale Revenues 146.3 438.7 121.6 112.1 17.9 12.2 82.5 Other Revenues from Contracts with Customers (c) 9.7 3.7 13.0 21.4 33.2 2.3 7.9 Total Revenues from Contracts with Customers 431.6 442.4 988.4 665.9 1,033.0 417.0 516.6 Other Revenues: Alternative Revenue Programs (d) (2.1) (0.8) (0.7) (2.9) (9.5) — (0.7) Other Revenues (e) — — — — 11.1 — — Total Other Revenues (2.1) (0.8) (0.7) (2.9) 1.6 — (0.7) Total Revenues $ 429.5 $ 441.6 $ 987.7 $ 663.0 $ 1,034.6 $ 417.0 $ 515.9 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $47 million primarily related to the PPA with KGPCo. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $349 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $18 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. 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 March 31, 2024. 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 2024 2025-2026 2027-2028 After 2028 Total (in millions) AEP $ 62.3 $ 166.8 $ 84.1 $ 24.7 $ 337.9 APCo 12.1 32.2 24.3 11.7 80.3 I&M 3.3 8.8 8.8 4.5 25.4 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 March 31, 2024 and December 31, 2023. 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 March 31, 2024 and December 31, 2023. 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 March 31, 2024 and December 31, 2023. 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: AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) March 31, 2024 $ — $ 129.2 $ 77.8 $ 55.8 $ 72.3 $ 10.8 $ 16.1 December 31, 2023 — 123.2 71.7 44.0 70.1 12.4 27.4

Pay vs Performance Disclosure

Pay vs Performance Disclosure - USD ($) $ in Millions	3 Months Ended
Pay vs Performance Disclosure - USD ($) $ in Millions	Mar. 31, 2024	Mar. 31, 2023
Pay vs Performance Disclosure
Net Income (Loss)	$ 1,005.7	$ 400.4

Insider Trading Arrangements

Insider Trading Arrangements	3 Months Ended
Insider Trading Arrangements	Mar. 31, 2024
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)	3 Months Ended
Significant Accounting Matters (Policies)	Mar. 31, 2024
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 months ended March 31, 2024 is not necessarily indicative of results that may be expected for the year ending December 31, 2024. The condensed financial statements are unaudited and should be read in conjunction with the audited 2023 financial statements and notes thereto, which are included in the Registrants’ Annual Reports on Form 10-K as filed with the SEC on February 26, 2024.
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)	3 Months Ended
Derivatives and Hedging (Policies)	Mar. 31, 2024
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) Cross-Acceleration Triggers Cross-Default Triggers (Applies to AEP, APCo, I&M, PSO and SWEPCo)

Fair Value Measurements (Polici

Fair Value Measurements (Policies)	3 Months Ended
Fair Value Measurements (Policies)	Mar. 31, 2024
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 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.
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.

Variable Interest Entities (Pol

Variable Interest Entities (Policies)	3 Months Ended
Variable Interest Entities (Policies)	Mar. 31, 2024
Variable Interest Entities	The accounting guidance for “Variable Interest Entities” is a consolidation model that considers if a company has a variable interest in a VIE. A VIE is a legal entity that possesses any of the following conditions: the entity’s equity at risk is not sufficient to permit the legal entity to finance its activities without additional subordinated financial support, equity owners are unable to direct the activities that most significantly impact the legal entity’s economic performance (or they possess disproportionate voting rights in relation to the economic interest in the legal entity), or the equity owners lack the obligation to absorb the legal entity’s expected losses or the right to receive the legal entity’s expected residual returns. Entities are required to consolidate a VIE when it is determined that they have a controlling financial interest in a VIE and therefore, are the primary beneficiary of that VIE, as defined by the accounting guidance for “Variable Interest Entities.” In determining whether AEP is the primary beneficiary of a VIE, management considers whether AEP has the power to direct the most significant activities of the VIE and is obligated to absorb losses or receive the expected residual returns that are significant to the VIE. Management believes that significant assumptions and judgments were applied consistently. AEP holds ownership interests in businesses with varying ownership structures. Partnership interests and other variable interests are evaluated to determine if each entity is a VIE, and if so, whether or not the VIE should be consolidated into AEP’s financial statements. AEP has not provided material financial or other support that was not previously contractually required to any of its consolidated VIEs. If an entity is determined not to be a VIE, or if the entity is determined to be a VIE and AEP is not deemed to be the primary beneficiary, the entity is accounted for under the equity method of accounting.

Significant Accounting Matter_2

Significant Accounting Matters (Tables)	3 Months Ended
Significant Accounting Matters (Tables)	Mar. 31, 2024
Reconciliation of Cash, Cash Equivalents and Restricted Cash	March 31, 2024 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 230.7 $ 0.1 $ 7.6 Restricted Cash 51.1 42.7 8.4 Total Cash, Cash Equivalents and Restricted Cash $ 281.8 $ 42.8 $ 16.0 December 31, 2023 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 330.1 $ 0.1 $ 5.0 Restricted Cash 48.9 34.0 14.9 Total Cash, Cash Equivalents and Restricted Cash $ 379.0 $ 34.1 $ 19.9
Earnings Per Share	Three Months Ended March 31, 2024 2023 (in millions, except per share data) $/share $/share Earnings Attributable to AEP Common Shareholders $ 1,003.1 $ 397.0 Weighted-Average Number of Basic AEP Common Shares Outstanding 526.6 $ 1.91 514.2 $ 0.77 Weighted-Average Dilutive Effect of Stock-Based Awards 1.0 (0.01) 1.4 — Weighted-Average Number of Diluted AEP Common Shares Outstanding 527.6 $ 1.90 515.6 $ 0.77

Comprehensive Income (Tables)

Comprehensive Income (Tables)	3 Months Ended
Comprehensive Income (Tables)	Mar. 31, 2024
Changes in Accumulated Other Comprehensive Income (Loss) by Component	Cash Flow Hedges Pension Three Months Ended March 31, 2024 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2023 $ 104.9 $ (8.1) $ (152.3) $ (55.5) Change in Fair Value Recognized in AOCI, Net of Tax 5.5 12.4 — 17.9 Amount of (Gain) Loss Reclassified from AOCI Purchased Electricity, Fuel and Other Consumables Used for Electric Generation (a) (29.3) — — (29.3) Interest Expense (a) — (1.2) — (1.2) Amortization of Prior Service Cost (Credit) — — (1.3) (1.3) Amortization of Actuarial (Gains) Losses — — 0.5 0.5 Reclassifications from AOCI, before Income Tax Benefit (29.3) (1.2) (0.8) (31.3) Income Tax Benefit (6.1) (0.3) (0.2) (6.6) Reclassifications from AOCI, Net of Income Tax Benefit (23.2) (0.9) (0.6) (24.7) Net Current Period Other Comprehensive Income (Loss) (17.7) 11.5 (0.6) (6.8) Balance in AOCI as of March 31, 2024 $ 87.2 $ 3.4 $ (152.9) $ (62.3) Cash Flow Hedges Pension Three Months Ended March 31, 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 (195.3) 5.2 (12.9) (203.0) Amount of (Gain) Loss Reclassified from AOCI Purchased Electricity, Fuel and Other Consumables Used for Electric Generation (a) 47.0 — — 47.0 Interest Expense (a) — 0.7 — 0.7 Amortization of Prior Service Cost (Credit) — — (5.3) (5.3) Amortization of Actuarial (Gains) Losses — — 1.2 1.2 Reclassifications from AOCI, before Income Tax (Expense) Benefit 47.0 0.7 (4.1) 43.6 Income Tax (Expense) Benefit 9.9 0.1 (0.9) 9.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 37.1 0.6 (3.2) 34.5 Reclassifications of KPCo Pension and OPEB Regulatory Assets from AOCI, Before Income Tax (Expense) Benefit — — 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) (158.2) 5.8 0.6 (151.8) Balance in AOCI as of March 31, 2023 $ 65.3 $ 6.1 $ (139.5) $ (68.1) (a) Amounts reclassified to the referenced line item on the statements of income.

Rate Matters (Tables)

Rate Matters (Tables)	3 Months Ended
Rate Matters (Tables)	Mar. 31, 2024
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 $ 96.7 $ 168.9 $ 20.7 (b) 2026 (c) $ 15.1 Welsh Plant, Units 1 and 3 335.6 135.7 58.1 (d) 2028 (e) (f) 39.2 (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)
Regulatory Assets Pending Final Regulatory Approval	AEP March 31, December 31, 2024 2023 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Welsh Plant, Units 1 and 3 Accelerated Depreciation $ 135.7 $ 125.6 Pirkey Plant Accelerated Depreciation 121.0 114.4 Unrecovered Winter Storm Fuel Costs (a) 90.8 97.2 Other Regulatory Assets Pending Final Regulatory Approval 14.3 49.8 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 404.9 408.9 NOLC Costs 67.7 — Other Regulatory Assets Pending Final Regulatory Approval 89.4 78.5 Total Regulatory Assets Pending Final Regulatory Approval $ 923.8 $ 874.4 (a) Includes $37 million and $37 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of March 31, 2024 and December 31, 2023, respectively. See the “February 2021 Severe Winter Weather Impacts in SPP” section below for additional information. AEP Texas March 31, December 31, 2024 2023 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Not Earning a Return Storm-Related Costs $ 38.4 $ 37.7 Line Inspection Costs 7.4 5.7 Vegetation Management Program 5.2 5.2 Texas Retail Electric Provider Bad Debt Expense 4.1 4.0 Other Regulatory Assets Pending Final Regulatory Approval 12.1 11.7 Total Regulatory Assets Pending Final Regulatory Approval $ 67.2 $ 64.3 APCo March 31, December 31, 2024 2023 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Other Regulatory Assets Pending Final Regulatory Approval $ 0.7 $ 0.6 Regulatory Assets Currently Not Earning a Return Storm-Related Costs - West Virginia 91.2 91.5 Plant Retirement Costs – Asset Retirement Obligation Costs 25.9 25.9 Other Regulatory Assets Pending Final Regulatory Approval 11.1 7.5 Total Regulatory Assets Pending Final Regulatory Approval $ 128.9 $ 125.5 I&M March 31, December 31, 2024 2023 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Other Regulatory Assets Pending Final Regulatory Approval $ 0.2 $ 0.2 Regulatory Assets Currently Not Earning a Return Storm-Related Costs - Indiana 29.7 29.7 NOLC Costs - Indiana 20.2 — Other Regulatory Assets Pending Final Regulatory Approval 4.6 3.3 Total Regulatory Assets Pending Final Regulatory Approval $ 54.7 $ 33.2 OPCo March 31, December 31, 2024 2023 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Not Earning a Return Storm-Related Costs $ 23.6 $ 23.6 Total Regulatory Assets Pending Final Regulatory Approval $ 23.6 $ 23.6 PSO March 31, December 31, 2024 2023 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Not Earning a Return Storm-Related Costs $ 88.8 $ 88.5 NOLC Costs 12.1 — Other Regulatory Assets Pending Final Regulatory Approval 2.9 0.2 Total Regulatory Assets Pending Final Regulatory Approval $ 103.8 $ 88.7 SWEPCo March 31, December 31, 2024 2023 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Welsh Plant, Units 1 and 3 Accelerated Depreciation $ 135.7 $ 125.6 Pirkey Plant Accelerated Depreciation 121.0 114.4 Unrecovered Winter Storm Fuel Costs (a) 90.8 97.2 Dolet Hills Power Station Accelerated Depreciation (b) 12.0 12.0 Other Regulatory Assets Pending Final Regulatory Approval 1.4 26.0 Regulatory Assets Currently Not Earning a Return Storm-Related Costs - Louisiana, Texas 51.4 56.0 NOLC Costs 35.4 — Other Regulatory Assets Pending Final Regulatory Approval 13.9 13.7 Total Regulatory Assets Pending Final Regulatory Approval $ 461.6 $ 444.9 (a) Includes $37 million and $37 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of March 31, 2024 and December 31, 2023, respectively. See the “February 2021 Severe Winter Weather Impacts in SPP” section below for additional information. (b) Amounts include the FERC jurisdiction.
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 March 31, 2024 December 31, 2023 Approved Recovery Period Approved Carrying Charge (in millions) Arkansas $ 48.6 $ 54.2 6 years (a) Louisiana 90.8 97.2 (b) (b) Texas 94.5 101.9 5 years 1.65% Total $ 233.9 $ 253.3 (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. The APSC will conclude an audit of these costs in 2024. A hearing is scheduled for June 2024. (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)	3 Months Ended
Commitments, Guarantees and Contingencies (Tables)	Mar. 31, 2024
Maximum Future Payments for Letters of Credit Uncommitted Facilities	Company Amount Maturity (in millions) AEP $ 247.4 April 2024 to March 2025 AEP Texas 1.8 July 2024 APCo 6.3 September 2024 I&M 2.9 September 2024
Max Potential Loss on Master Lease Agreements	Company Maximum (in millions) AEP $ 44.6 AEP Texas 10.7 APCo 5.8 I&M 4.1 OPCo 7.1 PSO 4.5 SWEPCo 5.1

Benefit Plans (Tables)

Benefit Plans (Tables)	3 Months Ended
Benefit Plans (Tables)	Mar. 31, 2024
Components of Net Periodic Benefit Cost	Pension Plans Three Months Ended March 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 25.6 $ 2.2 $ 2.4 $ 3.3 $ 2.4 $ 1.5 $ 1.9 Interest Cost 51.9 4.3 6.2 6.0 4.7 2.5 3.1 Expected Return on Plan Assets (80.2) (6.4) (10.7) (10.8) (8.2) (4.3) (4.4) Amortization of Net Actuarial Loss 1.1 0.1 0.1 0.1 0.1 — 0.1 Net Periodic Benefit Cost (Credit) $ (1.6) $ 0.2 $ (2.0) $ (1.4) $ (1.0) $ (0.3) $ 0.7 Three Months Ended March 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 23.6 $ 2.0 $ 2.3 $ 3.0 $ 2.1 $ 1.4 $ 1.9 Interest Cost 54.8 4.6 6.6 6.2 4.9 2.7 3.5 Expected Return on Plan Assets (84.8) (7.0) (11.2) (11.0) (8.5) (4.6) (4.8) Amortization of Net Actuarial Loss 0.3 — — — — — — Net Periodic Benefit Cost (Credit) $ (6.1) $ (0.4) $ (2.3) $ (1.8) $ (1.5) $ (0.5) $ 0.6 OPEB Three Months Ended March 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 1.1 $ 0.1 $ 0.1 $ 0.1 $ 0.1 $ 0.1 $ 0.1 Interest Cost 10.5 0.8 1.7 1.2 1.1 0.5 0.7 Expected Return on Plan Assets (27.8) (2.3) (4.0) (3.4) (3.0) (1.4) (1.9) Amortization of Prior Service Credit (3.2) (0.3) (0.5) (0.4) (0.3) (0.2) (0.3) Amortization of Net Actuarial Loss 0.8 0.1 0.1 0.1 0.1 — 0.1 Net Periodic Benefit Credit $ (18.6) $ (1.6) $ (2.6) $ (2.4) $ (2.0) $ (1.0) $ (1.3) Three Months Ended March 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 1.1 $ 0.1 $ 0.1 $ 0.2 $ 0.1 $ 0.1 $ 0.1 Interest Cost 11.6 0.9 1.8 1.3 1.2 0.6 0.7 Expected Return on Plan Assets (27.4) (2.3) (4.0) (3.4) (2.9) (1.5) (1.8) Amortization of Prior Service Credit (15.8) (1.3) (2.3) (2.2) (1.6) (1.0) (1.2) Amortization of Net Actuarial Loss 3.7 0.3 0.6 0.5 0.4 0.2 0.2 Net Periodic Benefit Credit $ (26.8) $ (2.3) $ (3.8) $ (3.6) $ (2.8) $ (1.6) $ (2.0)

Business Segments (Tables)

Business Segments (Tables)	3 Months Ended
Business Segments (Tables)	Mar. 31, 2024
Segment Reporting Information [Line Items]
Reportable Segment Information	Three Months Ended March 31, 2024 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) Revenues from: External Customers $ 2,901.2 $ 1,483.2 $ 110.5 $ 515.9 $ 14.9 $ — $ 5,025.7 Other Operating Segments 46.7 7.0 386.8 47.6 37.9 (526.0) (b) — Total Revenues $ 2,947.9 $ 1,490.2 $ 497.3 $ 563.5 $ 52.8 $ (526.0) $ 5,025.7 Net Income (Loss) $ 562.3 $ 150.3 $ 209.8 $ 137.6 $ (54.3) $ — $ 1,005.7 Three Months Ended March 31, 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 $ 2,816.3 $ 1,455.3 $ 90.1 $ 326.9 $ 2.3 $ — $ 4,690.9 Other Operating Segments 41.5 8.9 365.4 0.1 27.8 (443.7) (b) — Total Revenues $ 2,857.8 $ 1,464.2 $ 455.5 $ 327.0 $ 30.1 $ (443.7) $ 4,690.9 Net Income (Loss) $ 262.2 $ 125.7 $ 182.4 $ (156.4) $ (13.5) $ — $ 400.4 March 31, 2024 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Consolidated (in millions) Total Assets $ 52,379.2 $ 25,283.4 $ 17,067.4 $ 2,257.5 $ 5,164.3 (c) $ (4,407.2) (d) $ 97,744.6 December 31, 2023 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Consolidated (in millions) Total Assets $ 51,802.1 $ 24,838.4 $ 16,575.6 $ 2,598.5 $ 5,194.0 (c) $ (4,324.6) (d) $ 96,684.0 (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) Represents inter-segment revenues. (c) Includes elimination of AEP Parent’s investments in wholly-owned subsidiary companies. (d) Reconciling Adjustments for Total Assets primarily include elimination of intercompany advances to affiliates and intercompany accounts receivable. Three Months Ended March 31, 2024 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo Consolidated (in millions) Revenues from: External Customers $ 97.0 $ — $ — $ 97.0 Sales to AEP Affiliates 383.4 — — 383.4 Other Revenues 2.4 — — 2.4 Total Revenues $ 482.8 $ — $ — $ 482.8 Net Income (Loss) $ 181.7 $ (0.5) (a) $ — $ 181.2 Three Months Ended March 31, 2023 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo Consolidated (in millions) Revenues from: External Customers $ 89.0 $ — $ — $ 89.0 Sales to AEP Affiliates 352.6 — — 352.6 Total Revenues $ 441.6 $ — $ — $ 441.6 Net Income $ 161.6 $ 1.1 (a) $ — $ 162.7 March 31, 2024 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Total Assets $ 15,609.4 $ 5,949.9 (b) $ (6,000.3) (c) $ 15,559.0 December 31, 2023 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Total Assets $ 15,120.6 $ 5,486.6 (b) $ (5,534.7) (c) $ 15,072.5 (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)	3 Months Ended
Derivatives and Hedging (Tables)	Mar. 31, 2024
Notional Volume of Derivative Instruments	Notional Volume of Derivative Instruments March 31, 2024 December 31, 2023 Primary Risk AEP AEP Texas APCo I&M OPCo PSO SWEPCo AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power (MWhs) 233.5 — 7.0 3.4 2.2 2.2 1.6 246.8 — 16.8 5.9 2.2 4.1 2.9 Natural Gas (MMBtus) 176.8 — 43.0 — — 49.0 19.7 151.6 — 37.3 — — 34.9 17.9 Heating Oil and Gasoline (Gallons) 7.7 2.0 1.1 1.2 1.3 0.8 1.0 6.5 1.8 1.0 0.6 1.2 0.7 0.9 Interest Rate (USD) $ 69.6 $ — $ — $ — $ — $ — $ — $ 80.1 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt (USD) $ 1,500.0 $ 150.0 $ — $ — $ — $ — $ — $ 1,300.0 $ 150.0 $ — $ — $ — $ — $ —
Fair Value of Derivative Instruments	March 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Assets: (in millions) Current Risk Management Assets Risk Management Contracts - Commodity $ 436.2 $ 0.2 $ 9.9 $ 15.5 $ 0.1 $ 8.5 $ 5.5 Hedging Contracts - Commodity 35.4 — — — — — — Hedging Contracts - Interest Rate 8.3 2.3 — — — — — Total Current Risk Management Assets 479.9 2.5 9.9 15.5 0.1 8.5 5.5 Long-term Risk Management Assets Risk Management Contracts - Commodity 525.0 — 1.2 — — — — Hedging Contracts - Commodity 81.0 — — — — — — Hedging Contracts - Interest Rate — — — — — — — Total Long-term Risk Management Assets 606.0 — 1.2 — — — — Total Assets $ 1,085.9 $ 2.5 $ 11.1 $ 15.5 $ 0.1 $ 8.5 $ 5.5 Liabilities: Current Risk Management Liabilities Risk Management Contracts - Commodity $ 456.9 $ — $ 21.0 $ 9.0 $ 6.0 $ 29.1 $ 9.5 Hedging Contracts - Commodity 5.1 — — — — — — Hedging Contracts - Interest Rate 46.1 0.1 — — — — — Total Current Risk Management Liabilities 508.1 0.1 21.0 9.0 6.0 29.1 9.5 Long-term Risk Management Liabilities Risk Management Contracts - Commodity 430.0 — 3.3 — 35.0 2.8 1.8 Hedging Contracts - Commodity 0.6 — — — — — — Hedging Contracts - Interest Rate 70.4 — — — — — — Total Long-term Risk Management Liabilities 501.0 — 3.3 — 35.0 2.8 1.8 Total Liabilities $ 1,009.1 $ 0.1 $ 24.3 $ 9.0 $ 41.0 $ 31.9 $ 11.3 Total MTM Derivative Contract Net Assets (Liabilities) Recognized $ 76.8 $ 2.4 $ (13.2) $ 6.5 $ (40.9) $ (23.4) $ (5.8) December 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Assets: (in millions) Current Risk Management Assets Risk Management Contracts - Commodity $ 555.1 $ — $ 24.6 $ 30.1 $ — $ 19.7 $ 12.0 Hedging Contracts - Commodity 56.7 — — — — — — Hedging Contracts - Interest Rate — — — — — — — Total Current Risk Management Assets 611.8 — 24.6 30.1 — 19.7 12.0 Long-term Risk Management Assets Risk Management Contracts - Commodity 468.8 — 0.3 12.0 — — 0.5 Hedging Contracts - Commodity 86.8 — — — — — — Hedging Contracts - Interest Rate — — — — — — — Total Long-term Risk Management Assets 555.6 — 0.3 12.0 — — 0.5 Total Assets $ 1,167.4 $ — $ 24.9 $ 42.1 $ — $ 19.7 $ 12.5 Liabilities: Current Risk Management Liabilities Risk Management Contracts - Commodity $ 588.0 $ 0.2 $ 18.5 $ 5.4 $ 6.9 $ 29.7 $ 14.9 Hedging Contracts - Commodity 8.2 — — — — — — Hedging Contracts - Interest Rate 50.5 2.7 — — — — — Total Current Risk Management Liabilities 646.7 2.9 18.5 5.4 6.9 29.7 14.9 Long-term Risk Management Liabilities Risk Management Contracts - Commodity 377.6 — 6.9 0.2 43.9 1.0 1.7 Hedging Contracts - Commodity 2.2 — — — — — — Hedging Contracts - Interest Rate 56.9 — — — — — — Total Long-term Risk Management Liabilities 436.7 — 6.9 0.2 43.9 1.0 1.7 Total Liabilities $ 1,083.4 $ 2.9 $ 25.4 $ 5.6 $ 50.8 $ 30.7 $ 16.6 Total MTM Derivative Contract Net Assets (Liabilities) Recognized $ 84.0 $ (2.9) $ (0.5) $ 36.5 $ (50.8) $ (11.0) $ (4.1) March 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Assets: (in millions) Current Risk Management Assets Gross Amounts Recognized $ 479.9 $ 2.5 $ 9.9 $ 15.5 $ 0.1 $ 8.5 $ 5.5 Gross Amounts Offset (327.2) — (1.2) (4.3) — (0.6) (0.2) Net Amounts Presented 152.7 2.5 8.7 11.2 0.1 7.9 5.3 Long-term Risk Management Assets Gross Amounts Recognized 606.0 — 1.2 — — — — Gross Amounts Offset (291.6) — (1.2) — — — — Net Amounts Presented 314.4 — — — — — — Total Assets $ 467.1 $ 2.5 $ 8.7 $ 11.2 $ 0.1 $ 7.9 $ 5.3 Liabilities: Current Risk Management Liabilities Gross Amounts Recognized $ 508.1 $ 0.1 $ 21.0 $ 9.0 $ 6.0 $ 29.1 $ 9.5 Gross Amounts Offset (323.7) — (2.6) (8.3) — (0.6) (0.2) Net Amounts Presented 184.4 0.1 18.4 0.7 6.0 28.5 9.3 Long-term Risk Management Liabilities Gross Amounts Recognized 501.0 — 3.3 — 35.0 2.8 1.8 Gross Amounts Offset (221.5) — (1.2) — — — — Net Amounts Presented 279.5 — 2.1 — 35.0 2.8 1.8 Total Liabilities $ 463.9 $ 0.1 $ 20.5 $ 0.7 $ 41.0 $ 31.3 $ 11.1 Total MTM Derivative Contract Net Assets (Liabilities) $ 3.2 $ 2.4 $ (11.8) $ 10.5 $ (40.9) $ (23.4) $ (5.8) December 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Assets: (in millions) Current Risk Management Assets Gross Amounts Recognized $ 611.8 $ — $ 24.6 $ 30.1 $ — $ 19.7 $ 12.0 Gross Amounts Offset (394.3) — (2.2) (2.3) — (0.7) (0.4) Net Amounts Presented 217.5 — 22.4 27.8 — 19.0 11.6 Long-term Risk Management Assets Gross Amounts Recognized 555.6 — 0.3 12.0 — — 0.5 Gross Amounts Offset (234.4) — (0.3) (0.2) — — (0.5) Net Amounts Presented 321.2 — — 11.8 — — — Total Assets $ 538.7 $ — $ 22.4 $ 39.6 $ — $ 19.0 $ 11.6 Liabilities: Current Risk Management Liabilities Gross Amounts Recognized $ 646.7 $ 2.9 $ 18.5 $ 5.4 $ 6.9 $ 29.7 $ 14.9 Gross Amounts Offset (417.1) (0.2) (2.6) (3.4) (0.1) (0.8) (0.5) Net Amounts Presented 229.6 2.7 15.9 2.0 6.8 28.9 14.4 Long-term Risk Management Liabilities Gross Amounts Recognized 436.7 — 6.9 0.2 43.9 1.0 1.7 Gross Amounts Offset (194.9) — (0.3) (0.2) — — (0.5) Net Amounts Presented 241.8 — 6.6 — 43.9 1.0 1.2 Total Liabilities $ 471.4 $ 2.7 $ 22.5 $ 2.0 $ 50.7 $ 29.9 $ 15.6 Total MTM Derivative Contract Net Assets (Liabilities) $ 67.3 $ (2.7) $ (0.1) $ 37.6 $ (50.7) $ (10.9) $ (4.0)
Amount of Gain (Loss) Recognized on Risk Management Contracts	Amount of Gain (Loss) Recognized on Risk Management Contracts Three Months Ended March 31, 2024 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ (25.7) $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues (44.7) — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.1 (25.8) — — — Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 1.0 — 0.9 — — — — Maintenance 0.1 — — — — — — Regulatory Assets (a) 13.5 0.2 (0.1) (1.6) 8.6 (1.2) 4.9 Regulatory Liabilities (a) 52.7 0.2 13.1 2.2 — 18.3 15.0 Total Gain (Loss) on Risk Management Contracts $ (3.1) $ 0.4 $ 14.0 $ (25.2) $ 8.6 $ 17.1 $ 19.9 Three Months Ended March 31, 2023 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ (5.3) $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues (147.4) — — — — — — Electric Generation, Transmission and Distribution Revenues — — — (5.3) — — — Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 0.7 — 0.6 — — — — Maintenance 0.1 — — — — — — Regulatory Assets (a) (24.8) (0.4) (7.1) (0.5) (12.3) (1.2) (1.5) Regulatory Liabilities (a) (1.5) — (26.2) 1.2 — 18.0 11.9 Total Gain (Loss) on Risk Management Contracts $ (178.2) $ (0.4) $ (32.7) $ (4.6) $ (12.3) $ 16.8 $ 10.4 (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 March 31, 2024 December 31, 2023 March 31, 2024 December 31, 2023 (in millions) Long-term Debt (a) (b) $ (860.2) $ (878.2) $ 86.7 $ 68.4 (a) Amounts included within Noncurrent Liabilities line item Long-term Debt on the Balance Sheet. (b)
Gain (Loss) on Hedging Instruments	Three Months Ended March 31, 2024 2023 (in millions) Gain (Loss) on Interest Rate Contracts: Fair Value Hedging Instruments (a) $ (16.4) $ 6.9 Fair Value Portion of Long-term Debt (a) 16.4 (6.9) (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 the Registrants’ Balance Sheets March 31, 2024 December 31, 2023 Portion Expected to Portion Expected to AOCI be Reclassed to AOCI be Reclassed to Gain (Loss) Net Income During Gain (Loss) Net Income During Net of Tax the Next Twelve Months Net of Tax the Next Twelve Months Commodity Interest Rate Commodity Interest Rate Commodity Interest Rate Commodity Interest Rate (in millions) AEP $ 87.2 $ 3.4 $ 24.0 $ 3.6 $ 104.9 $ (8.1) $ 38.3 $ 3.2 AEP Texas — 4.4 — 0.5 — 0.5 — 0.2 APCo — 5.7 — 0.8 — 5.9 — 0.8 I&M — (5.4) — (0.4) — (5.5) — (0.4) PSO — (0.2) — — — (0.2) — — SWEPCo — 1.2 — 0.3 — 1.3 — 0.3

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	3 Months Ended
Fair Value Measurements (Tables)	Mar. 31, 2024
Book Values and Fair Values of Long-term Debt	March 31, 2024 December 31, 2023 Company Book Value Fair Value Book Value Fair Value (in millions) AEP $ 39,835.9 $ 36,392.2 $ 40,143.2 $ 37,325.7 AEP Texas 5,878.7 5,289.7 5,889.8 5,400.7 AEPTCo 5,860.7 5,066.3 5,414.4 4,796.9 APCo 5,670.9 5,370.8 5,588.3 5,390.1 I&M 3,478.5 3,182.3 3,499.4 3,291.6 OPCo 3,367.4 2,912.1 3,366.8 2,992.1 PSO 2,384.9 2,130.2 2,384.6 2,154.3 SWEPCo 3,647.6 3,170.6 3,646.9 3,209.7
Other Temporary Investments	March 31, 2024 Gross Gross Unrealized Unrealized Fair Other Temporary Investments and Restricted Cash Cost Gains Losses Value (in millions) Restricted Cash (a) $ 51.1 $ — $ — $ 51.1 Other Cash Deposits 15.4 — — 15.4 Fixed Income Securities – Mutual Funds (b) 164.7 — (6.8) 157.9 Equity Securities – Mutual Funds 14.7 29.0 — 43.7 Total Other Temporary Investments and Restricted Cash $ 245.9 $ 29.0 $ (6.8) $ 268.1 December 31, 2023 Gross Gross Unrealized Unrealized Fair Other Temporary Investments and Restricted Cash Cost Gains Losses Value (in millions) Restricted Cash (a) $ 48.9 $ — $ — $ 48.9 Other Cash Deposits 13.9 — — 13.9 Fixed Income Securities – Mutual Funds (b) 165.9 — (6.2) 159.7 Equity Securities – Mutual Funds 14.8 25.9 — 40.7 Total Other Temporary Investments and Restricted Cash $ 243.5 $ 25.9 $ (6.2) $ 263.2 (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 March 31, 2024 2023 (in millions) Proceeds from Investment Sales $ 3.0 $ — Purchases of Investments 1.5 1.0 Gross Realized Gains on Investment Sales 0.3 — Gross Realized Losses on Investment Sales 0.2 —
Nuclear Trust Fund Investments	March 31, 2024 December 31, 2023 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 $ 25.2 $ — $ — $ — $ 16.8 $ — $ — $ — Fixed Income Securities: United States Government 1,267.0 16.5 (4.2) (25.7) 1,273.0 28.6 (3.9) (33.2) Corporate Debt 123.3 2.5 (6.0) (5.1) 132.1 4.8 (5.2) (8.6) State and Local Government 1.7 — — — 1.7 — — — Subtotal Fixed Income Securities 1,392.0 19.0 (10.2) (30.8) 1,406.8 33.4 (9.1) (41.8) Equity Securities - Domestic 2,695.4 2,119.1 (1.1) — 2,436.6 1,869.5 (0.9) — Spent Nuclear Fuel and Decommissioning Trusts $ 4,112.6 $ 2,138.1 $ (11.3) $ (30.8) $ 3,860.2 $ 1,902.9 $ (10.0) $ (41.8)
Securities Activity Within the Decommissioning and SNF Trusts	Three Months Ended March 31, 2024 2023 (in millions) Proceeds from Investment Sales $ 569.5 $ 517.6 Purchases of Investments 588.5 536.3 Gross Realized Gains on Investment Sales 5.4 48.5 Gross Realized Losses on Investment Sales 1.2 8.6
Contractual Maturities, Fair Value of Debt Securities in Nuclear Trusts	Fair Value of Fixed Income Securities (in millions) Within 1 year $ 338.8 After 1 year through 5 years 598.0 After 5 years through 10 years 186.6 After 10 years 268.6 Total $ 1,392.0
Fair Value, Assets and Liabilities Measured on Recurring Basis	AEP Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments and Restricted Cash Restricted Cash $ 51.1 $ — $ — $ — $ 51.1 Other Cash Deposits (a) — — — 15.4 15.4 Fixed Income Securities – Mutual Funds 157.9 — — — 157.9 Equity Securities – Mutual Funds (b) 43.7 — — — 43.7 Total Other Temporary Investments and Restricted Cash 252.7 — — 15.4 268.1 Risk Management Assets Risk Management Commodity Contracts (c) (d) 3.6 679.7 257.5 (593.9) 346.9 Cash Flow Hedges: Commodity Hedges (c) — 94.5 18.7 (1.3) 111.9 Interest Rate Hedges — 8.3 — — 8.3 Total Risk Management Assets 3.6 782.5 276.2 (595.2) 467.1 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 13.3 — — 11.9 25.2 Fixed Income Securities: United States Government — 1,267.0 — — 1,267.0 Corporate Debt — 123.3 — — 123.3 State and Local Government — 1.7 — — 1.7 Subtotal Fixed Income Securities — 1,392.0 — — 1,392.0 Equity Securities – Domestic (b) 2,695.4 — — — 2,695.4 Total Spent Nuclear Fuel and Decommissioning Trusts 2,708.7 1,392.0 — 11.9 4,112.6 Total Assets $ 2,965.0 $ 2,174.5 $ 276.2 $ (567.9) $ 4,847.8 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (d) $ 21.0 $ 688.4 $ 157.1 $ (520.3) $ 346.2 Cash Flow Hedges: Commodity Hedges (c) — 2.5 — (1.3) 1.2 Interest Rate Hedges — 1.7 — — 1.7 Fair Value Hedges — 114.8 — — 114.8 Total Risk Management Liabilities $ 21.0 $ 807.4 $ 157.1 $ (521.6) $ 463.9 AEP Assets and Liabilities Measured at Fair Value on a Recurring Basis December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments and Restricted Cash Restricted Cash $ 48.9 $ — $ — $ — $ 48.9 Other Cash Deposits (a) — — — 13.9 13.9 Fixed Income Securities – Mutual Funds 159.7 — — — 159.7 Equity Securities – Mutual Funds (b) 40.7 — — — 40.7 Total Other Temporary Investments and Restricted Cash 249.3 — — 13.9 263.2 Risk Management Assets Risk Management Commodity Contracts (c) (f) 9.7 736.9 274.3 (617.0) 403.9 Cash Flow Hedges: Commodity Hedges (c) — 123.5 19.8 (8.5) 134.8 Total Risk Management Assets 9.7 860.4 294.1 (625.5) 538.7 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 7.8 — — 9.0 16.8 Fixed Income Securities: United States Government — 1,273.0 — — 1,273.0 Corporate Debt — 132.1 — — 132.1 State and Local Government — 1.7 — — 1.7 Subtotal Fixed Income Securities — 1,406.8 — — 1,406.8 Equity Securities – Domestic (b) 2,436.6 — — — 2,436.6 Total Spent Nuclear Fuel and Decommissioning Trusts 2,444.4 1,406.8 — 9.0 3,860.2 Total Assets $ 2,703.4 $ 2,267.2 $ 294.1 $ (602.6) $ 4,662.1 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (f) $ 24.7 $ 783.8 $ 154.1 $ (600.3) $ 362.3 Cash Flow Hedges: Commodity Hedges (c) — 9.6 0.6 (8.5) 1.7 Interest Rate Hedges — 9.0 — — 9.0 Fair Value Hedges — 98.4 — — 98.4 Total Risk Management Liabilities $ 24.7 $ 900.8 $ 154.7 $ (608.8) $ 471.4 AEP Texas Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 42.7 $ — $ — $ — $ 42.7 Risk Management Assets Risk Management Commodity Contracts (c) — 0.2 — 2.3 2.5 Cash Flow Hedges: Interest Rate Hedges — 2.3 — (2.3) — Total Risk Management Assets — 2.5 — — 2.5 Total Assets $ 42.7 $ 2.5 $ — $ — $ 45.2 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ — $ — $ 0.1 $ 0.1 Cash Flow Hedges: Interest Rate Hedges — 0.1 — (0.1) — Total Liabilities $ — $ 0.1 $ — $ — $ 0.1 December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 34.0 $ — $ — $ — $ 34.0 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 0.2 $ — $ (0.2) $ — Cash Flow Hedges: Interest Rate Hedges — 2.7 — — 2.7 Total Risk Management Liabilities $ — $ 2.9 $ — $ (0.2) $ 2.7 APCo Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 8.4 $ — $ — $ — $ 8.4 Risk Management Assets Risk Management Commodity Contracts (c) — 2.1 8.6 (2.0) 8.7 Total Assets $ 8.4 $ 2.1 $ 8.6 $ (2.0) $ 17.1 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 19.3 $ 4.6 $ (3.4) $ 20.5 December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 14.9 $ — $ — $ — $ 14.9 Risk Management Assets Risk Management Commodity Contracts (c) — 1.1 23.5 (2.2) 22.4 Total Assets $ 14.9 $ 1.1 $ 23.5 $ (2.2) $ 37.3 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 24.0 $ 1.1 $ (2.6) $ 22.5 I&M Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ 13.1 $ 1.8 $ (3.7) $ 11.2 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 13.3 — — 11.9 25.2 Fixed Income Securities: United States Government — 1,267.0 — — 1,267.0 Corporate Debt — 123.3 — — 123.3 State and Local Government — 1.7 — — 1.7 Subtotal Fixed Income Securities — 1,392.0 — — 1,392.0 Equity Securities - Domestic (b) 2,695.4 — — — 2,695.4 Total Spent Nuclear Fuel and Decommissioning Trusts 2,708.7 1,392.0 — 11.9 4,112.6 Total Assets $ 2,708.7 $ 1,405.1 $ 1.8 $ 8.2 $ 4,123.8 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 7.6 $ 0.8 $ (7.7) $ 0.7 December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ 37.4 $ 4.5 $ (2.3) $ 39.6 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 7.8 — — 9.0 16.8 Fixed Income Securities: United States Government — 1,273.0 — — 1,273.0 Corporate Debt — 132.1 — — 132.1 State and Local Government — 1.7 — — 1.7 Subtotal Fixed Income Securities — 1,406.8 — — 1,406.8 Equity Securities - Domestic (b) 2,436.6 — — — 2,436.6 Total Spent Nuclear Fuel and Decommissioning Trusts 2,444.4 1,406.8 — 9.0 3,860.2 Total Assets $ 2,444.4 $ 1,444.2 $ 4.5 $ 6.7 $ 3,899.8 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 3.7 $ 1.7 $ (3.4) $ 2.0 OPCo Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ 0.1 $ — $ — $ 0.1 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ — $ 41.0 $ — $ 41.0 December 31, 2023 Level 1 Level 2 Level 3 Other Total Liabilities: (in millions) Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 0.2 $ 50.6 $ (0.1) $ 50.7 PSO Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ 0.1 $ 8.4 $ (0.6) $ 7.9 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 31.2 $ 0.7 $ (0.6) $ 31.3 December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ — $ 19.7 $ (0.7) $ 19.0 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 29.6 $ 1.1 $ (0.8) $ 29.9 SWEPCo Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ 0.1 $ 5.5 $ (0.3) $ 5.3 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 11.1 $ 0.2 $ (0.2) $ 11.1 December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ 0.5 $ 12.0 $ (0.9) $ 11.6 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 15.7 $ 0.9 $ (1.0) $ 15.6 (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 March 31, 2024 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $(14) million in 2024 and $(3) million in periods 2025-2027; Level 2 matures $(65) million in 2024, $51 million in periods 2025-2027 and $5 million in periods 2028-2029; Level 3 matures $34 million in 2024, $55 million in periods 2025-2027, $23 million in periods 2028-2029 and $(12) million in periods 2030-2032. 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, 2023 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $(11) million in 2024 and $(4) million in 2025-2027; Level 2 matures $(99) million in 2024, $(44) million in periods 2025-2027, $7 million in periods 2028-2029 and $2 million in periods 2030-2033; Level 3 matures $74 million in 2024, $43 million in periods 2025-2027, $18 million in periods 2028-2029 and $(16) million in periods 2030-2033. Risk management commodity contracts are substantially comprised of power contracts.
Changes in Fair Value of Net Trading Derivatives and Other Investments	Three Months Ended March 31, 2024 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of December 31, 2023 $ 139.4 $ 22.4 $ 2.8 $ (50.6) $ 18.6 $ 11.1 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 46.9 9.2 3.2 (0.4) 18.5 14.7 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) 11.3 — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 0.6 — — — — — Settlements (96.6) (26.8) (4.8) 2.6 (31.3) (23.6) Transfers into Level 3 (d) (e) 4.6 — — — — — Transfers out of Level 3 (e) 2.1 — — — — 0.5 Changes in Fair Value Allocated to Regulated Jurisdictions (f) 10.8 (0.8) (0.2) 7.4 1.9 2.6 Balance as of March 31, 2024 $ 119.1 $ 4.0 $ 1.0 $ (41.0) $ 7.7 $ 5.3 Three Months Ended March 31, 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) (7.1) (31.9) 1.2 (1.3) 16.6 12.9 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) 14.8 — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) (13.9) — — — — — Settlements (96.6) (27.3) (4.2) 1.0 (34.3) (23.0) Transfers into Level 3 (d) (e) (6.1) — — — — — Transfers out of Level 3 (e) 1.0 — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) (7.4) (4.2) (0.5) (6.6) 3.3 1.7 Balance as of March 31, 2023 $ 45.1 $ 5.7 $ 1.1 $ (46.9) $ 9.3 $ 5.8 (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 March 31, 2024 Significant Input/Range Type of Fair Value Valuation Unobservable Weighted Company Input Assets Liabilities Technique Input Low High Average (a) (in millions) AEP Energy Contracts $ 246.5 $ 146.1 Discounted Cash Flow Forward Market Price (b) $ 10.31 $ 169.47 $ 49.39 AEP FTRs 29.7 11.0 Discounted Cash Flow Forward Market Price (b) (79.90) 23.79 (0.35) APCo FTRs 8.6 4.6 Discounted Cash Flow Forward Market Price (b) (0.38) 5.05 0.61 I&M FTRs 1.8 0.8 Discounted Cash Flow Forward Market Price (b) 0.03 6.82 0.84 OPCo Energy Contracts — 41.0 Discounted Cash Flow Forward Market Price (b) 19.72 75.88 47.20 PSO FTRs 8.4 0.7 Discounted Cash Flow Forward Market Price (b) (79.90) 3.13 (3.48) SWEPCo FTRs 5.5 0.2 Discounted Cash Flow Forward Market Price (b) (79.90) 3.13 (3.48) December 31, 2023 Significant Input/Range Type of Fair Value Valuation Unobservable Weighted Company Input Assets Liabilities Technique Input Low High Average (a) (in millions) AEP Energy Contracts $ 225.5 $ 144.9 Discounted Cash Flow Forward Market Price (b) $ 5.21 $ 153.77 $ 45.05 AEP Natural Gas Contracts — 0.5 Discounted Cash Flow Forward Market Price (c) 3.11 3.11 3.11 AEP FTRs 68.6 9.3 Discounted Cash Flow Forward Market Price (b) (25.45) 17.07 — APCo FTRs 23.5 1.1 Discounted Cash Flow Forward Market Price (b) (1.04) 6.45 1.36 I&M FTRs 4.5 1.7 Discounted Cash Flow Forward Market Price (b) (1.48) 8.40 (0.85) OPCo Energy Contracts — 50.6 Discounted Cash Flow Forward Market Price (b) 22.92 67.53 42.85 PSO FTRs 19.7 1.1 Discounted Cash Flow Forward Market Price (b) (25.45) 4.80 (4.33) SWEPCo Natural Gas Contracts — 0.5 Discounted Cash Flow Forward Market Price (c) 3.11 3.11 3.11 SWEPCo FTRs 12.0 0.4 Discounted Cash Flow Forward Market Price (b) (25.45) 4.80 (4.33) (a) The weighted average is the product of the forward market price of the underlying commodity and volume weighted by term. (b) Represents market prices in dollars per MWh. (c) Represents market prices in dollars per MMBtu.
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)	3 Months Ended
Income Taxes (Tables)	Mar. 31, 2024
Schedule of Effective Income Tax Rate Reconciliation	Three Months Ended March 31, 2024 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 % 0.2 % 2.6 % 2.4 % 3.9 % 1.0 % 3.7 % 1.7 % Tax Reform Excess ADIT Reversal (2.3) % (1.3) % 0.2 % (13.4) % (0.5) % (6.0) % (2.0) % 4.6 % Remeasurement of Excess ADIT (29.7) % — % — % — % (58.2) % — % (263.3) % (224.7) % Production and Investment Tax Credits (6.8) % (0.2) % — % (0.1) % (1.1) % — % (49.6) % (23.8) % Flow Through — % 0.1 % 0.3 % (0.3) % (2.8) % 0.6 % 0.2 % 0.6 % AFUDC Equity (1.2) % (1.5) % (1.8) % (0.4) % (0.7) % (1.0) % (1.3) % (1.3) % Discrete Tax Adjustments 0.2 % — % — % — % — % — % 0.9 % 1.3 % Other 0.2 % 0.5 % — % 0.1 % — % 0.2 % 1.2 % (0.8) % Effective Income Tax Rate (16.5) % 18.8 % 22.3 % 9.3 % (38.4) % 15.8 % (289.2) % (221.4) % Three Months Ended March 31, 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 1.9 % 0.3 % 2.6 % 2.4 % 3.6 % 1.0 % 3.2 % (0.4) % Tax Reform Excess ADIT Reversal (6.2) % (1.5) % 0.3 % (4.6) % (7.9) % (6.8) % (18.7) % (3.8) % Production and Investment Tax Credits (9.7) % (0.2) % — % — % (1.1) % — % (55.7) % (26.4) % Flow Through 0.1 % 0.2 % 0.3 % 0.6 % (1.8) % 0.5 % 0.3 % 0.5 % AFUDC Equity (1.4) % (1.5) % (1.6) % (0.7) % (0.5) % (0.8) % (1.4) % (0.8) % Discrete Tax Adjustments (3.2) % — % — % 3.2 % 1.8 % — % — % — % Other 0.1 % 0.1 % 0.1 % — % — % — % (2.0) % (0.8) % Effective Income Tax Rate 2.6 % 18.4 % 22.7 % 21.9 % 15.1 % 14.9 % (53.3) % (10.7) %

Financing Activities (Tables)

Financing Activities (Tables)	3 Months Ended
Financing Activities (Tables)	Mar. 31, 2024
Long-term Debt	Type of Debt March 31, 2024 December 31, 2023 (in millions) Senior Unsecured Notes $ 34,606.1 $ 33,779.4 Pollution Control Bonds 1,771.0 1,771.6 Notes Payable 163.5 193.3 Securitization Bonds 343.8 368.9 Spent Nuclear Fuel Obligation (a) 304.4 300.4 Junior Subordinated Notes 1,588.2 2,388.1 Other Long-term Debt 1,058.9 1,341.5 Total Long-term Debt Outstanding 39,835.9 40,143.2 Long-term Debt Due Within One Year 1,198.6 2,490.5 Long-term Debt $ 38,637.3 $ 37,652.7 (a) Pursuant to the Nuclear Waste Policy Act of 1982, I&M, a nuclear licensee, has an obligation to the United States Department of Energy for SNF disposal. The obligation includes a one-time fee for nuclear fuel consumed prior to April 7, 1983. Trust fund assets related to this obligation were $355 million and $348 million as of March 31, 2024 and December 31, 2023, respectively, and are included in Spent Nuclear Fuel and Decommissioning Trusts on the balance sheets.
Long-term Debt Issuances	Principal Interest Company Type of Debt Amount (a) Rate Due Date Issuances: (in millions) (%) AEPTCo Senior Unsecured Notes $ 450.0 5.15 2034 APCo Senior Unsecured Notes 400.0 5.65 2034 Non-Registrant: Transource Energy Other Long-term Debt 18.0 Variable 2025 Total Issuances $ 868.0 (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 Junior Subordinated Notes $ 805.0 2.03 2024 AEP Texas Securitization Bonds 11.9 2.06 2025 APCo Other Long-term Debt 300.0 Variable 2024 APCo Securitization Bonds 13.4 3.77 2028 I&M Notes Payable 1.2 Variable 2024 I&M Notes Payable 0.9 Variable 2025 I&M Notes Payable 4.0 0.93 2025 I&M Notes Payable 5.0 3.44 2026 I&M Notes Payable 6.8 5.93 2027 I&M Notes Payable 6.8 6.01 2028 I&M Other Long-term Debt 0.7 6.00 2025 PSO Other Long-term Debt 0.1 3.00 2027 Non-Registrant: AEGCo Notes Payable 5.0 2.43 2028 Transource Energy Senior Unsecured Notes 1.4 2.75 2050 Total Retirements and Principal Payments $ 1,162.2
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 March 31, 2024 Limit (in millions) AEP Texas $ 267.9 $ — $ 191.2 $ — $ (267.9) $ 600.0 AEPTCo 313.3 298.0 178.5 75.3 272.9 820.0 (a) APCo 399.5 51.1 205.5 20.3 37.4 750.0 I&M 125.5 — 60.2 — (73.2) 500.0 OPCo 295.2 — 143.4 — (295.2) 500.0 PSO 264.6 — 128.8 — (264.6) 750.0 SWEPCo 254.5 — 161.1 — (254.5) 750.0 (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 March 31, 2024 (in millions) AEP Texas $ 7.1 $ 7.0 $ 7.0 SWEPCo 2.3 2.2 2.3
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 March 31, 2024 March 31, 2024 Borrowing Limit (in millions) $ 44.4 $ 148.5 $ 4.4 $ 72.9 $ 3.7 $ — $ 50.0 (a) (a) Amount represents the authorized short-term borrowing limit from FERC or state regulatory agencies not otherwise included in the utility money pool above.
Maximum and Minimum Interest Rates for Funds Either Borrowed from or Loaned to Utility Money Pool	Three Months Ended March 31, 2024 2023 Maximum Interest Rate 5.79 % 5.42 % Minimum Interest Rate 5.66 % 4.66 %
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 Three Months Ended March 31, for Three Months Ended March 31, Company 2024 2023 2024 2023 AEP Texas 5.71 % 5.18 % — % — % AEPTCo 5.72 % 5.09 % 5.70 % 5.29 % APCo 5.74 % 5.14 % 5.72 % 5.12 % I&M 5.73 % 5.12 % — % 5.16 % OPCo 5.71 % 5.17 % — % — % PSO 5.71 % 4.84 % — % 5.11 % SWEPCo 5.71 % 5.12 % — % — %
Maximum Minimum Average Interest Rates for Funds Borrowed from Loaned to Nonutility Money Pool	Three Months Ended March 31, 2024 Three Months Ended March 31, 2023 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 5.79 % 5.66 % 5.72 % 5.42 % 4.66 % 5.12 % SWEPCo 5.79 % 5.66 % 5.72 % 5.42 % 4.66 % 5.13 %
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 Three Months for Funds for Funds for Funds for Funds for Funds for Funds Ended Borrowed Borrowed Loaned Loaned Borrowed Loaned March 31, from AEP from AEP to AEP to AEP from AEP to AEP 2024 5.79 % 5.66 % 5.79 % 5.66 % 5.74 % 5.71 % 2023 5.38 % 4.53 % 5.38 % 4.53 % 5.03 % 5.15 %
Short Term Debt	March 31, 2024 December 31, 2023 Outstanding Interest Outstanding Interest Company Type of Debt Amount Rate (a) Amount Rate (a) (dollars in millions) AEP Securitized Debt for Receivables (b) $ 900.0 5.54 % $ 888.0 5.65 % AEP Commercial Paper 2,832.2 5.61 % 1,937.9 5.69 % SWEPCo Notes Payable 5.4 7.68 % 4.3 7.71 % Total Short-term Debt $ 3,737.6 $ 2,830.2 (a) Weighted-average rate as of March 31, 2024 and December 31, 2023, 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 March 31, 2024 2023 (dollars in millions) Effective Interest Rates on Securitization of Accounts Receivable 5.61 % 4.86 % Net Uncollectible Accounts Receivable Written-Off $ 8.1 $ 6.9
Customer Accounts Receivable Managed Portfolio	March 31, 2024 December 31, 2023 (in millions) Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts $ 1,164.2 $ 1,207.4 Short-term – Securitized Debt of Receivables 900.0 888.0 Delinquent Securitized Accounts Receivable 58.2 52.2 Bad Debt Reserves Related to Securitization 42.6 42.0 Unbilled Receivables Related to Securitization 336.9 409.8
Accounts Receivable and Accrued Unbilled Revenues	Company March 31, 2024 December 31, 2023 (in millions) APCo $ 196.5 $ 184.6 I&M 167.0 156.4 OPCo 536.0 541.7 PSO 96.3 134.6 SWEPCo 144.2 168.3
Fees Paid to AEP Credit for Customer Accounts Receivable Sold	Three Months Ended March 31, Company 2024 2023 (in millions) APCo $ 4.2 $ 4.9 I&M 4.1 3.9 OPCo 7.4 7.3 PSO 3.4 3.2 SWEPCo 4.8 4.3
Proceeds on Sale of Receivables to AEP Credit	Three Months Ended March 31, Company 2024 2023 (in millions) APCo $ 536.0 $ 506.2 I&M 529.7 525.4 OPCo 845.7 884.4 PSO 361.6 416.3 SWEPCo 425.4 437.6

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	3 Months Ended	12 Months Ended
Variable Interest Entities (Tables)	Mar. 31, 2024	Dec. 31, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Consolidated Assets And Liabilities Of Variable Interest Entities	March 31, 2024 Consolidated VIEs SWEPCo I&M AEP Texas Transition Funding AEP Texas Restoration Funding APCo Appalachian Consumer Rate Relief Funding AEP Credit Protected Transource Energy (in millions) ASSETS Current Assets $ 5.1 $ 75.3 $ 40.1 $ 20.4 $ 6.3 $ 1,165.3 $ 211.6 $ 31.7 Net Property, Plant and Equipment — 129.5 — — — — — 536.9 Other Noncurrent Assets 140.1 63.5 55.3 (a) 139.7 (b) 130.3 (c) 10.2 — 9.3 Total Assets $ 145.2 $ 268.3 $ 95.4 $ 160.1 $ 136.6 $ 1,175.5 $ 211.6 $ 577.9 LIABILITIES AND EQUITY Current Liabilities $ 22.8 $ 75.1 $ 76.3 $ 36.4 $ 29.0 $ 1,113.7 $ 52.3 $ 22.5 Noncurrent Liabilities 122.1 193.2 14.7 122.4 105.7 1.0 90.8 258.8 Equity 0.3 — 4.4 1.3 1.9 60.8 68.5 296.6 Total Liabilities and Equity $ 145.2 $ 268.3 $ 95.4 $ 160.1 $ 136.6 $ 1,175.5 $ 211.6 $ 577.9 (a) Includes an intercompany item eliminated in consolidation of $6 million. (b) Includes an intercompany item eliminated in consolidation of $6 million. (c) Includes an intercompany item eliminated in consolidation of $2 million .	December 31, 2023 Consolidated VIEs SWEPCo I&M AEP Texas Transition Funding AEP Texas Restoration Funding APCo AEP Credit Protected Transource Energy (in millions) ASSETS Current Assets $ 4.2 $ 81.9 $ 25.5 $ 27.5 $ 13.3 $ 1,208.8 $ 205.3 $ 36.9 Net Property, Plant and Equipment — 153.8 — — — — — 533.4 Other Noncurrent Assets 150.7 81.7 71.4 (a) 145.6 (b) 138.2 (c) 9.6 — 5.1 Total Assets $ 154.9 $ 317.4 $ 96.9 $ 173.1 $ 151.5 $ 1,218.4 $ 205.3 $ 575.4 LIABILITIES AND EQUITY Current Liabilities $ 19.9 $ 81.7 $ 75.5 $ 36.8 $ 29.9 $ 1,155.0 $ 49.2 $ 45.3 Noncurrent Liabilities 134.8 235.7 17.0 135.1 119.7 0.9 91.7 241.5 Equity 0.2 — 4.4 1.2 1.9 62.5 64.4 288.6 Total Liabilities and Equity $ 154.9 $ 317.4 $ 96.9 $ 173.1 $ 151.5 $ 1,218.4 $ 205.3 $ 575.4 (a) Includes an intercompany item eliminated in consolidation of $8 million . (b) Includes an intercompany item eliminated in consolidation of $6 million . (c) Includes an intercompany item eliminated in consolidation of $2 million .

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	3 Months Ended
Revenue from Contracts with Customers (Tables)	Mar. 31, 2024
Disaggregated Revenues from Contracts with Customers	Three Months Ended March 31, 2024 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation & Marketing Corporate and Other Reconciling Adjustments AEP Consolidated (in millions) Retail Revenues: Residential Revenues $ 1,212.3 $ 703.8 $ — $ — $ — $ — $ 1,916.1 Commercial Revenues 645.1 397.0 — — — — 1,042.1 Industrial Revenues (a) 647.1 136.1 — — — (0.2) 783.0 Other Retail Revenues 55.3 13.9 — — — — 69.2 Total Retail Revenues 2,559.8 1,250.8 — — — (0.2) 3,810.4 Wholesale and Competitive Retail Revenues: Generation Revenues 235.9 — — 27.4 — 0.1 263.4 Transmission Revenues (b) 118.9 179.8 488.7 — — (418.6) 368.8 Renewable Generation Revenues (a) — — — 6.3 — (1.4) 4.9 Retail, Trading and Marketing Revenues (c) — — — 571.4 0.5 (46.2) 525.7 Total Wholesale and Competitive Retail Revenues 354.8 179.8 488.7 605.1 0.5 (466.1) 1,162.8 Other Revenues from Contracts with Customers (d) 59.7 51.0 8.1 1.3 60.4 (68.7) 111.8 Total Revenues from Contracts with Customers 2,974.3 1,481.6 496.8 606.4 60.9 (535.0) 5,085.0 Other Revenues: Alternative Revenue Programs (e) (0.7) 0.7 0.5 — — 1.0 1.5 Other Revenues (a) (f) (25.7) 7.9 — (42.9) (8.1) 8.0 (60.8) Total Other Revenues (26.4) 8.6 0.5 (42.9) (8.1) 9.0 (59.3) Total Revenues $ 2,947.9 $ 1,490.2 $ 497.3 $ 563.5 $ 52.8 $ (526.0) $ 5,025.7 (a) Amounts include affiliated and nonaffiliated revenues. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $387 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $46 million. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $48 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. Three Months Ended March 31, 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 $ 1,170.4 $ 656.8 $ — $ — $ — $ — $ 1,827.2 Commercial Revenues 633.4 375.9 — — — — 1,009.3 Industrial Revenues 670.3 212.9 — — — (0.2) 883.0 Other Retail Revenues 56.8 12.1 — — — — 68.9 Total Retail Revenues 2,530.9 1,257.7 — — — (0.2) 3,788.4 Wholesale and Competitive Retail Revenues: Generation Revenues 182.8 — — 32.4 — — 215.2 Transmission Revenues (a) 114.7 164.2 450.1 — — (401.8) 327.2 Renewable Generation Revenues (b) — — — 21.3 — (0.1) 21.2 Retail, Trading and Marketing Revenues (b) — — — 413.7 (0.3) 0.1 413.5 Total Wholesale and Competitive Retail Revenues 297.5 164.2 450.1 467.4 (0.3) (401.8) 977.1 Other Revenues from Contracts with Customers (c) 32.6 42.8 3.6 0.6 29.4 (43.7) 65.3 Total Revenues from Contracts with Customers 2,861.0 1,464.7 453.7 468.0 29.1 (445.7) 4,830.8 Other Revenues: Alternative Revenue Programs (d) (3.1) (11.6) 1.8 — — 2.9 (10.0) Other Revenues (b) (e) (0.1) 11.1 — (141.0) 1.0 (0.9) (129.9) Total Other Revenues (3.2) (0.5) 1.8 (141.0) 1.0 2.0 (139.9) Total Revenues $ 2,857.8 $ 1,464.2 $ 455.5 $ 327.0 $ 30.1 $ (443.7) $ 4,690.9 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $357 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 $29 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 March 31, 2024 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 147.3 $ — $ 526.3 $ 224.8 $ 556.5 $ 158.2 $ 182.4 Commercial Revenues 110.9 — 188.3 144.8 286.1 103.0 140.0 Industrial Revenues (a) 35.6 — 196.4 147.9 100.5 80.3 95.0 Other Retail Revenues 9.7 — 28.1 1.3 4.2 21.5 2.6 Total Retail Revenues 303.5 — 939.1 518.8 947.3 363.0 420.0 Wholesale Revenues: Generation Revenues (b) — — 85.1 137.3 — 2.2 47.1 Transmission Revenues (c) 155.9 475.4 47.1 10.1 23.8 10.8 39.6 Total Wholesale Revenues 155.9 475.4 132.2 147.4 23.8 13.0 86.7 Other Revenues from Contracts with Customers (d) 8.8 8.1 21.7 27.6 42.2 12.0 9.6 Total Revenues from Contracts with Customers 468.2 483.5 1,093.0 693.8 1,013.3 388.0 516.3 Other Revenues: Alternative Revenue Programs (e) (1.8) (0.7) (0.1) (0.5) 2.6 (0.2) (0.1) Other Revenues (a) — — 0.1 (25.9) 7.9 — — Total Other Revenues (1.8) (0.7) — (26.4) 10.5 (0.2) (0.1) Total Revenues $ 466.4 $ 482.8 $ 1,093.0 $ 667.4 $ 1,023.8 $ 387.8 $ 516.2 (a) Amounts include affiliated and nonaffiliated revenues. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $41 million primarily related to the PPA with KGPCo. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $384 million, APCo was $21 million and SWEPCo was $14 million. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $18 million primarily related 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. Three Months Ended March 31, 2023 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 130.7 $ — $ 470.5 $ 239.6 $ 526.0 $ 170.9 $ 175.9 Commercial Revenues 97.3 — 171.3 138.9 278.5 109.1 143.5 Industrial Revenues 39.3 — 185.8 152.6 173.6 98.3 104.2 Other Retail Revenues 8.3 — 26.2 1.3 3.8 24.2 2.6 Total Retail Revenues 275.6 — 853.8 532.4 981.9 402.5 426.2 Wholesale Revenues: Generation Revenues (a) — — 80.2 104.0 — 0.9 39.6 Transmission Revenues (b) 146.3 438.7 41.4 8.1 17.9 11.3 42.9 Total Wholesale Revenues 146.3 438.7 121.6 112.1 17.9 12.2 82.5 Other Revenues from Contracts with Customers (c) 9.7 3.7 13.0 21.4 33.2 2.3 7.9 Total Revenues from Contracts with Customers 431.6 442.4 988.4 665.9 1,033.0 417.0 516.6 Other Revenues: Alternative Revenue Programs (d) (2.1) (0.8) (0.7) (2.9) (9.5) — (0.7) Other Revenues (e) — — — — 11.1 — — Total Other Revenues (2.1) (0.8) (0.7) (2.9) 1.6 — (0.7) Total Revenues $ 429.5 $ 441.6 $ 987.7 $ 663.0 $ 1,034.6 $ 417.0 $ 515.9 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $47 million primarily related to the PPA with KGPCo. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $349 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $18 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.
Fixed Performance Obligations	Company 2024 2025-2026 2027-2028 After 2028 Total (in millions) AEP $ 62.3 $ 166.8 $ 84.1 $ 24.7 $ 337.9 APCo 12.1 32.2 24.3 11.7 80.3 I&M 3.3 8.8 8.8 4.5 25.4
Affiliated Accounts Receivable Contracts with Customers	AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) March 31, 2024 $ — $ 129.2 $ 77.8 $ 55.8 $ 72.3 $ 10.8 $ 16.1 December 31, 2023 — 123.2 71.7 44.0 70.1 12.4 27.4

Significant Accounting Matter_3

Significant Accounting Matters (Details) - USD ($) $ / shares in Units, $ in Thousands		3 Months Ended
		Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022
Amounts Attributable to AEP Common Shareholders
Earnings Attributable to Common Shareholders		$ 1,003,100	$ 397,000
Weighted Average Number of Basic AEP Common Shares Outstanding		526,552,036	514,176,648
Total Basic Earnings Per Share Attributable to AEP Common Shareholders		$ 1.91	$ 0.77
Weighted Average Dilutive Effect of:
Weighted Average Number of Diluted AEP Common Shares Outstanding		527,596,395	515,598,090
Total Diluted Earnings Per Share Attributable to AEP Common Shareholders		$ 1.90	$ 0.77
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		$ 230,700		$ 330,100
Restricted Cash		51,100		48,900
Total Cash, Cash Equivalents and Restricted Cash		281,800	$ 393,500	379,000	$ 556,500
Proceeds from Issuance of Debt	[1]	868,000
Securities Received as Collateral		86,000		46,000
Cash Paid for Interest, Net of Capitalized Amounts		368,300	311,900
Net Cash Paid (Received) for Income Taxes		16,100	15,800
AEP Texas Inc. [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		100		100
Restricted Cash		42,700		34,000
Total Cash, Cash Equivalents and Restricted Cash		42,800	42,600	34,100	32,800
Cash Paid for Interest, Net of Capitalized Amounts		26,900	31,600
AEP Transmission Co [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		0	0	0	0
Cash Paid for Interest, Net of Capitalized Amounts		33,300	16,200
Appalachian Power Co [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		7,600		5,000
Restricted Cash		8,400		14,900
Total Cash, Cash Equivalents and Restricted Cash		16,000	14,600	19,900	21,900
Cash Paid for Interest, Net of Capitalized Amounts		41,500	37,900
Indiana Michigan Power Co [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		5,500	8,500	2,100	4,200
Cash Paid for Interest, Net of Capitalized Amounts		38,700	44,400
Net Cash Paid (Received) for Income Taxes		0	2,400
Ohio Power Co [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		12,500		6,400
Total Cash, Cash Equivalents and Restricted Cash		12,500	9,100	6,400	9,600
Cash Paid for Interest, Net of Capitalized Amounts		19,100	20,900
Public Service Co Of Oklahoma [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		3,500	3,800	2,500	4,000
Cash Paid for Interest, Net of Capitalized Amounts		30,300	22,300
Southwestern Electric Power Co [Member]
Amounts Attributable to AEP Common Shareholders
Earnings Attributable to Common Shareholders		208,100	40,600
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		3,800	8,200	$ 2,400	$ 88,400
Cash Paid for Interest, Net of Capitalized Amounts		$ 41,200	$ 45,300
Restricted Stock Units and Performance Share Units [Member]
Weighted Average Dilutive Effect of:
Weighted Average Dilutive Effect of Shares		1,000,000	1,400,000
Dilutive Securities, Effect on Basic Earnings Per Share		$ (0.01)	$ 0

[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
Comprehensive Income (Details) - USD ($) $ in Millions		Mar. 31, 2024	Mar. 31, 2023
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		$ (55.5)	$ 83.7
Change in Fair Value Recognized in AOCI		17.9	(203)
Commodity
Generation & Marketing Revenues		5,025.7	4,690.9
Interest Rate
Interest Expense		435.6	415.7
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(31.3)	43.6
Income Tax (Expense) Benefit		(141.9)	10.4
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(24.7)	34.5
Reclassifications of KPCo Pension and OPEB Regulatory Assets, Net of Tax		0	16.7
Net Current Period Other Comprehensive Income (Loss)		(6.8)	(151.8)
Ending Balance in AOCI		(62.3)	(68.1)
Reclassification of KPCo Pension and OPEB Regulatory Assets from AOCI
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit			4.4
Reclassifications of KPCo Pension and OPEB Regulatory Assets from AOCI, before Income Tax (Expense) Benefit			21.1
Reclassifications of KPCo Pension and OPEB Regulatory Assets, Net of Tax			16.7
Cash Flow Hedges [Member] \| Commodity [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		104.9	223.5
Change in Fair Value Recognized in AOCI		5.5	(195.3)
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(29.3)	47
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(23.2)	37.1
Net Current Period Other Comprehensive Income (Loss)		(17.7)	(158.2)
Ending Balance in AOCI		87.2	65.3
Cash Flow Hedges [Member] \| Commodity [Member] \| Reclassification of KPCo Pension and OPEB Regulatory Assets from AOCI
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit			0
Reclassifications of KPCo Pension and OPEB Regulatory Assets from AOCI, before Income Tax (Expense) Benefit			0
Reclassifications of KPCo Pension and OPEB Regulatory Assets, Net of Tax			0
Cash Flow Hedges [Member] \| Interest Rate [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(8.1)	0.3
Change in Fair Value Recognized in AOCI		12.4	5.2
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(1.2)	0.7
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(0.9)	0.6
Net Current Period Other Comprehensive Income (Loss)		11.5	5.8
Ending Balance in AOCI		3.4	6.1
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
Income Tax (Expense) Benefit			0
Reclassifications of KPCo Pension and OPEB Regulatory Assets from AOCI, before Income Tax (Expense) Benefit			0
Reclassifications of KPCo Pension and OPEB Regulatory Assets, Net of Tax			0
Pension and OPEB [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(152.3)	(140.1)
Change in Fair Value Recognized in AOCI		0	(12.9)
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(0.8)	(4.1)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(0.6)	(3.2)
Net Current Period Other Comprehensive Income (Loss)		(0.6)	0.6
Ending Balance in AOCI		(152.9)	(139.5)
Pension and OPEB [Member] \| Reclassification of KPCo Pension and OPEB Regulatory Assets from AOCI \| Pension Costs
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit			4.4
Reclassifications of KPCo Pension and OPEB Regulatory Assets from AOCI, before Income Tax (Expense) Benefit			21.1
Reclassifications of KPCo Pension and OPEB Regulatory Assets, Net of Tax			16.7
Generation and Marketing [Member]
Commodity
Generation & Marketing Revenues		515.9	326.9
Reclassifications from Accumulated Other Comprehensive Income [Member]
Interest Rate
Interest Expense	[1]	(1.2)	0.7
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(1.3)	(5.3)
Amortization of Actuarial (Gains) Losses		0.5	1.2
Income Tax (Expense) Benefit		(6.6)	9.1
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Cash Flow Hedges [Member] \| Commodity [Member]
Interest Rate
Interest Expense	[1]	0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		0	0
Amortization of Actuarial (Gains) Losses		0	0
Income Tax (Expense) Benefit		(6.1)	9.9
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Cash Flow Hedges [Member] \| Interest Rate [Member]
Interest Rate
Interest Expense	[1]	(1.2)	0.7
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		0	0
Amortization of Actuarial (Gains) Losses		0	0
Income Tax (Expense) Benefit		(0.3)	0.1
Reclassifications from Accumulated Other Comprehensive Income [Member] \| Pension and OPEB [Member]
Interest Rate
Interest Expense	[1]	0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(1.3)	(5.3)
Amortization of Actuarial (Gains) Losses		0.5	1.2
Income Tax (Expense) Benefit		(0.2)	(0.9)
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]	(29.3)	47
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]	(29.3)	47
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
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

[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			3 Months Ended
		Apr. 30, 2024	Mar. 31, 2024	Dec. 31, 2023
Public Utilities, General Disclosures [Line Items]
Net Investment			$ 77,796	$ 76,693.4
Regulatory Assets, Noncurrent			5,034.1	5,092.4
Regulatory Assets, Current			550.3	514
AEP Texas Inc. [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment			13,079.4	12,774
Regulatory Assets, Noncurrent			317.4	315.3
AEP Transmission Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment			14,778.2	14,497.7
Regulatory Assets, Noncurrent			2.4	3.1
Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment			13,052.9	12,931.5
Regulatory Assets, Noncurrent			1,107.4	1,155.1
Regulatory Assets, Current			148.4	155.4
Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment			7,651.2	7,629
Regulatory Assets, Noncurrent			498.2	406.3
Regulatory Assets, Current			3.8	14.8
Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment			9,467.4	9,299.9
Regulatory Assets, Noncurrent			416.6	455
Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment			6,189.6	6,112.3
Regulatory Assets, Noncurrent			533.1	522.7
Regulatory Assets, Current			155.8	118.3
Public Service Co Of Oklahoma [Member] \| Northeastern Plant, Unit 3 \| Generating Units Probable of Abandonment [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment			96.7
Accelerated Depreciation Regulatory Asset			168.9
Cost of Removal Regulatory Liability	[1]		$ 20.7
Expected Retirement Date	[2]		2026
Depreciation	[3]		$ 15.1
Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment			8,666.7	8,558.4
Regulatory Assets, Noncurrent			1,138.2	1,131.8
Net Under-Recovered Fuel Costs			72
Regulatory Assets, Current			166.3	170.8
Southwestern Electric Power Co [Member] \| Dolet Hills Power Station [Member] \| Louisiana Jurisdiction [Member] \| Subsequent Event [Member]
Public Utilities, General Disclosures [Line Items]
Dolet Hills Prudency Disallowance		$ 14
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			86
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			35
Recommended Disallowance from Staff or Intervenors			55
ALJ Recommended Customer Refund			55
ALJ Recommended Denial of Recovery for Fuel Costs Deferral			35
Southwestern Electric Power Co [Member] \| Dolet Hills Power Station and Related Fuel Operations \| Louisiana Jurisdiction [Member] \| Subsequent Event [Member]
Public Utilities, General Disclosures [Line Items]
Dolet Hills Fuel Disallowance		11
Remaining Dolet Fuel Reg Asset Recovered Over Three Years		$ 24
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			185
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] \| Pirkey Generating Station (Unit No. 1) \| Texas
Public Utilities, General Disclosures [Line Items]
Net Investment			68
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			335.6
Accelerated Depreciation Regulatory Asset			135.7
Cost of Removal Regulatory Liability	[4]		$ 58.1
Expected Retirement Date	[5],[6]		2028
Depreciation	[3]		$ 39.2
Southwestern Electric Power Co [Member] \| Dolet Hills Power Station \| Arkansas
Public Utilities, General Disclosures [Line Items]
Asset Impairments and Other Related Charges			2
Southwestern Electric Power Co [Member] \| Dolet Hills Power Station \| Texas
Public Utilities, General Disclosures [Line Items]
Asset Impairments and Other Related Charges			12
Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			923.8	874.4
Regulatory Assets Pending Final Regulatory Approval [Member] \| AEP Texas Inc. [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			67.2	64.3
Regulatory Assets Pending Final Regulatory Approval [Member] \| Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			128.9	125.5
Regulatory Assets Pending Final Regulatory Approval [Member] \| Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			54.7	33.2
Regulatory Assets Pending Final Regulatory Approval [Member] \| Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			23.6	23.6
Regulatory Assets Pending Final Regulatory Approval [Member] \| Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			103.8	88.7
Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			461.6	444.9
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			14.3	49.8
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]		90.8	97.2
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			121	114.4
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			135.7	125.6
Regulatory Assets Currently 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			0.7	0.6
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			0.2	0.2
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	[8]		12	12
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			1.4	26
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	[9]		90.8	97.2
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			121	114.4
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			135.7	125.6
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			404.9	408.9
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			89.4	78.5
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| NOLC Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			67.7	0
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			38.4	37.7
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			12.1	11.7
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
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] \| AEP Texas Inc. [Member] \| Line Inspection Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			7.4	5.7
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			91.2	91.5
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			11.1	7.5
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			29.7	29.7
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Indiana Michigan Power Co [Member] \| Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			4.6	3.3
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Indiana Michigan Power Co [Member] \| NOLC Costs [Member] \| Indiana [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			20.2	0
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			23.6	23.6
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			88.8	88.5
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			2.9	0.2
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Public Service Co Of Oklahoma [Member] \| NOLC Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			12.1	0
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			51.4	56
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			13.9	13.7
Regulatory Assets Currently Not Earning Return [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member] \| Southwestern Electric Power Co [Member] \| NOLC Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			$ 35.4	$ 0

[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. Northeastern Plant, Unit 3 is currently being recovered through 2040. Represents the amount of annual depreciation that has been collected from customers over the prior 12-month period. 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. Represents projected retirement date of coal assets, units are being evaluated for conversion to natural gas after 2028. Includes $37 million and $37 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of March 31, 2024 and December 31, 2023, respectively. See the “February 2021 Severe Winter Weather Impacts in SPP” section below for additional information. Includes $37 million and $37 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of March 31, 2024 and December 31, 2023, respectively. See the “February 2021 Severe Winter Weather Impacts in SPP” section below for additional information.

Rate Matters East Companies (De

Rate Matters East Companies (Details) - USD ($) $ in Thousands		3 Months Ended
	Apr. 30, 2024	Mar. 31, 2024	Dec. 31, 2023
Public Utilities, General Disclosures [Line Items]
Net Property, Plant and Equipment		$ 77,796,000	$ 76,693,400
AEP Transmission Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Property, Plant and Equipment		14,778,200	14,497,700
Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Property, Plant and Equipment		13,052,900	12,931,500
Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Property, Plant and Equipment		7,651,200	7,629,000
Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Property, Plant and Equipment		9,467,400	$ 9,299,900
ENEC Filing \| Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Under-Recovered Costs Disallowance		232,000
Approved Recovery Under-Recovered Costs		$ 321,000
Approved Carrying Charge		4%
Michigan Power Supply Cost Recovery Reconciliation \| Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Recommended Disallowance		$ 18,000
Potential Disallowed Costs		14,000
OVEC ICPA Recommended Disallowance		1,000
2022 Recommended Disallowance		2,000
2022 Potential Disallowed Costs		$ 6,000
Michigan Power Supply Cost Recovery Reconciliation \| Indiana Michigan Power Co [Member] \| Subsequent Event [Member]
Public Utilities, General Disclosures [Line Items]
2021 Disallowed OVEC Purchased Power Costs	$ 1,000
2021 Disallowed Rockport Purchased Power Costs	10,000
Disallowed PSCR Shortfall	$ 497
Ohio ESP Filings [Member] \| Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Approved Return on Common Equity		9.70%
Proprosed ESP Return on Common Equity		10.65%
2023 Kentucky Base Rate and Securitization Case [Member] \| Kentucky Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Return on Equity		9.90%
Approved Return on Common Equity		9.75%
Requested Annual Base Rate Increase		$ 94,000
Requested Securitization Bonds Regulatory Assets Recovery		$ 471,000
KPCo Interest in Mitchell Plant		50%
Settlement Agreement Return on Common Equity		9.75%
Settlement Agreement Annual Increase		$ 75,000
Settlement Agreement Securitization Bonds Regulatory Assets Recovery		471,000
Approved Net Increase in Kentucky Annual Revenues		60,000
Reduction In Revenue Requirement For Recovery of Actual Test Year PJM Transmission Costs		14,000
Regulatory Assets Expected to be Recovered Through Securitization		476,000
Securitized Plant Retirement Costs		288,000
Securitized Deferred Storm Costs		79,000
Securitized Purchased Power Expenses		46,000
Securitized Under-Recovered Rider Costs		62,000
Securitized Deferred Issuance Related Expenses		1,000
2023 Kentucky Base Rate and Securitization Case [Member] \| Kentucky Power Co [Member] \| Mitchell Power Plant
Public Utilities, General Disclosures [Line Items]
Net Property, Plant and Equipment		543,000
2023 Indiana Base Rate Case [Member] \| Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Annual Increase		$ 116,000
Requested Return on Equity		10.50%
Amount of Increase Related to Annual Depreciation Expense		$ 41,000
Requested Deferred Storm Costs		$ 15,000
Requested Debt Capital Structure		48.80%
Requested Equity Capital Structure		51.20%
Settlement Agreement Annual Increase Step One		$ 28,000
Settlement Agreement Annual Increase Step Two		$ 34,000
Settlement Agreement Return on Common Equity		9.85%
Settlement Agreement Debt Capital Structure		50%
Settlement Agreement Equity Capital Structure		50%
Settlement Agreement Adjusted Equity Capital Structure		51.20%
Settlement Agreement Increase Related to Depreciation Expense		$ 25,000
Settlement Agreement Increase Related to Storm Expense		11,000
2023 Michigan Base Rate Case [Member] \| Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Annual Increase		$ 34,000
Requested Return on Equity		10.50%
Amount of Increase Related to Annual Depreciation Expense		$ 11,000
Requested Debt Capital Structure		49.40%
Requested Equity Capital Structure		50.60%
2023 Virginia Base Rate Case [Member] \| Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Annual Increase		$ 95,000
Requested Return on Equity		10.80%
Requested Debt Capital Structure		51%
Requested Equity Capital Structure		49%
Fuel Adjustment Clause [Member] \| Kentucky Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Purchased Power Cost Recoveries		$ 432,000
Rockport Offset Recovery [Member] \| Kentucky Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Recovery of Allowed Costs		41,000
Estimated Allowed Costs Recovered Through Rider		23,000
Approved Recovery of Allowed Costs Through Interim Rates		18,000
APCo Portion [Member] \| ENEC Filing \| Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Under-Recovered Costs Disallowance		136,000
Approved Recovery Under-Recovered Costs		174,000
Minimum [Member] \| 2023 Michigan Base Rate Case [Member] \| Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Recommended Annual Base Rate Decrease		$ 6,000
Recommended Return on Common Equity		9.70%
Recommended Debt Capital Structure		49.40%
Recommended Equity Capital Structure		48%
Minimum [Member] \| Fuel Adjustment Clause [Member] \| Kentucky Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Recommended Disallowance from Staff or Intervenors		$ 44,000
Maximum [Member] \| 2023 Michigan Base Rate Case [Member] \| Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Recommended Annual Base Rate Increase		$ 19,000
Recommended Return on Common Equity		9.90%
Recommended Debt Capital Structure		52%
Recommended Equity Capital Structure		50.60%
Maximum [Member] \| Fuel Adjustment Clause [Member] \| Kentucky Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Recommended Disallowance from Staff or Intervenors		$ 60,000

Rate Matters West Companies (De

Rate Matters West Companies (Details) $ in Millions		3 Months Ended
Rate Matters West Companies (Details) $ in Millions	Apr. 30, 2024 USD ($)	Mar. 31, 2024 USD ($) MW	Dec. 31, 2023 USD ($)
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		$ 5,034.1	$ 5,092.4
Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		923.8	874.4
Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		533.1	522.7
Public Service Co Of Oklahoma [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		103.8	88.7
Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		1,138.2	1,131.8
Southwestern Electric Power Co [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		461.6	444.9
AEP Texas Inc. [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		317.4	315.3
AEP Texas Inc. [Member] \| Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		$ 67.2	64.3
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		$ 1,700
February 2021 Severe Storm Fuel Costs \| Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		233.9	253.3
February 2021 Severe Storm Fuel Costs \| Southwestern Electric Power Co [Member] \| Arkansas
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		$ 48.6	54.2
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		$ 90.8	97.2
February 2021 Severe Storm Fuel Costs \| Southwestern Electric Power Co [Member] \| Texas
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		$ 94.5	$ 101.9
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
Turk AFUDC Disallowance		86
2012 Texas Base Rate Case [Member] \| Southwestern Electric Power Co [Member] \| Minimum [Member]
Public Utilities, General Disclosures [Line Items]
Estimated Turk AFUDC Refunds		0
2012 Texas Base Rate Case [Member] \| Southwestern Electric Power Co [Member] \| Minimum [Member] \| Subsequent Event [Member]
Public Utilities, General Disclosures [Line Items]
Recommended Customer Refunds	$ 149
Recommended Refund Period	18 months
2012 Texas Base Rate Case [Member] \| Southwestern Electric Power Co [Member] \| Maximum [Member]
Public Utilities, General Disclosures [Line Items]
Estimated Turk AFUDC Refunds		200
2012 Texas Base Rate Case [Member] \| Southwestern Electric Power Co [Member] \| Maximum [Member] \| Subsequent Event [Member]
Public Utilities, General Disclosures [Line Items]
Recommended Customer Refunds	$ 197
Recommended Refund Period	48 months
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
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		$ 1,100
2024 AEP Texas Base Rate Case [Member] \| AEP Texas Inc. [Member]
Public Utilities, General Disclosures [Line Items]
Requested Return on Equity		10.60%
Requested Debt Capital Structure		55%
Requested Equity Capital Structure		45%
Requested Annual Base Rate Increase		$ 164
2024 Oklahoma Base Rate Case [Member] \| Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Requested Return on Equity		10.80%
Requested Debt Capital Structure		48.90%
Requested Equity Capital Structure		51.10%
Requested Net Increase in Oklahoma Annual Revenues		$ 218
Wind Generation MWs \| MW		155

Rate Matters FERC (Details)

Rate Matters FERC (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
Rate Matters FERC (Details) - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Independence Energy Connection Project [Member]
Public Utilities, General Disclosures [Line Items]
AEP Share of Independence Energy Connection Capital Costs	$ 94
Request to Update SWEPCo Generation Depreciation Rates [Member]
Public Utilities, General Disclosures [Line Items]
Requested Annual Revenue Requirement	5
FERC 2021 PJM and SPP Transmission Formula Rate Challenge [Member]
Public Utilities, General Disclosures [Line Items]
Stand Alone Treatment of NOLCs Annual Revenue Increase	$ 52	$ 60	$ 69	$ 78

Commitments, Guarantees and C_3

Commitments, Guarantees and Contingencies (Details) $ in Millions	Mar. 31, 2024 USD ($)
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	$ 44.6
AEP Texas Inc. [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	10.7
Appalachian Power Co [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	5.8
Indiana Michigan Power Co [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	4.1
Ohio Power Co [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	7.1
Public Service Co Of Oklahoma [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	4.5
Southwestern Electric Power Co [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	5.1
Letters of Credit [Member]
Maximum Future Payments for Letters of Credit [Abstract]
Maximum Future Payments for Letters of Credit Issued Under the Uncommitted Facility	247.4
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Letters of Credit Limit	1,200
Uncommitted Facility	450
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	1.8
Letters of Credit [Member] \| Appalachian Power Co [Member]
Maximum Future Payments for Letters of Credit [Abstract]
Maximum Future Payments for Letters of Credit Issued Under the Uncommitted Facility	6.3
Letters of Credit [Member] \| Indiana Michigan Power Co [Member]
Maximum Future Payments for Letters of Credit [Abstract]
Maximum Future Payments for Letters of Credit Issued Under the Uncommitted Facility	2.9
March 2029 [Member] \| Letters of Credit [Member]
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Revolving Credit Facilities	5,000
March 2027 [Member] \| Letters of Credit [Member]
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Prior Revolving Credit Facilities	4,000
Revolving Credit Facilities	$ 1,000

Acquisitions and Dispositions (

Acquisitions and Dispositions (Details) - USD ($)	3 Months Ended		9 Months Ended
Acquisitions and Dispositions (Details) - USD ($)	Mar. 31, 2024	Mar. 31, 2023	Sep. 30, 2023	Dec. 31, 2023
Customers	$ 1,000,000,000			$ 1,029,900,000
Net Property, Plant and Equipment	77,796,000,000			76,693,400,000
Accounts Payable, Current	1,990,900,000			2,032,500,000
Proceeds from Sale of Equity Method Investments	114,000,000	$ 0
Generation And Marketing [Member] \| New Mexico Renewable Development
Proceeds from Sale of Equity Method Investments	107,000,000
Generation And Marketing [Member] \| Competitive Contracted Renewables
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
Public Service Co Of Oklahoma [Member]
Customers	74,100,000			107,600,000
Net Property, Plant and Equipment	6,189,600,000			6,112,300,000
Accounts Payable, Current	138,500,000			159,300,000
Public Service Co Of Oklahoma [Member] \| Vertically Integrated Utilities [Member] \| Rock Falls Wind Facility
Payments to Acquire Property, Plant, and Equipment		$ 146,000,000
Southwestern Electric Power Co [Member]
Customers	32,700,000			39,000,000
Net Property, Plant and Equipment	8,666,700,000			8,558,400,000
Accounts Payable, Current	185,300,000			198,900,000
AEP Transmission Co [Member]
Customers	80,600,000			82,200,000
Net Property, Plant and Equipment	14,778,200,000			14,497,700,000
Accounts Payable, Current	$ 289,600,000			$ 274,700,000

Benefit Plans (Details)

Benefit Plans (Details) - USD ($) $ in Millions	3 Months Ended
Benefit Plans (Details) - USD ($) $ in Millions	Mar. 31, 2024	Mar. 31, 2023
Pension Plans [Member]
Components of Net Periodic Benefit Cost
Service Cost	$ 25.6	$ 23.6
Interest Cost	51.9	54.8
Expected Return on Plan Assets	(80.2)	(84.8)
Amortization of Net Actuarial Loss	1.1	0.3
Net Periodic Benefit Cost (Credit)	(1.6)	(6.1)
Pension Plans [Member] \| AEP Texas Inc. [Member]
Components of Net Periodic Benefit Cost
Service Cost	2.2	2
Interest Cost	4.3	4.6
Expected Return on Plan Assets	(6.4)	(7)
Amortization of Net Actuarial Loss	0.1	0
Net Periodic Benefit Cost (Credit)	0.2	(0.4)
Pension Plans [Member] \| Appalachian Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	2.4	2.3
Interest Cost	6.2	6.6
Expected Return on Plan Assets	(10.7)	(11.2)
Amortization of Net Actuarial Loss	0.1	0
Net Periodic Benefit Cost (Credit)	(2)	(2.3)
Pension Plans [Member] \| Indiana Michigan Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	3.3	3
Interest Cost	6	6.2
Expected Return on Plan Assets	(10.8)	(11)
Amortization of Net Actuarial Loss	0.1	0
Net Periodic Benefit Cost (Credit)	(1.4)	(1.8)
Pension Plans [Member] \| Ohio Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	2.4	2.1
Interest Cost	4.7	4.9
Expected Return on Plan Assets	(8.2)	(8.5)
Amortization of Net Actuarial Loss	0.1	0
Net Periodic Benefit Cost (Credit)	(1)	(1.5)
Pension Plans [Member] \| Public Service Co Of Oklahoma [Member]
Components of Net Periodic Benefit Cost
Service Cost	1.5	1.4
Interest Cost	2.5	2.7
Expected Return on Plan Assets	(4.3)	(4.6)
Amortization of Net Actuarial Loss	0	0
Net Periodic Benefit Cost (Credit)	(0.3)	(0.5)
Pension Plans [Member] \| Southwestern Electric Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	1.9	1.9
Interest Cost	3.1	3.5
Expected Return on Plan Assets	(4.4)	(4.8)
Amortization of Net Actuarial Loss	0.1	0
Net Periodic Benefit Cost (Credit)	0.7	0.6
Other Postretirement Benefit Plans [Member]
Components of Net Periodic Benefit Cost
Service Cost	1.1	1.1
Interest Cost	10.5	11.6
Expected Return on Plan Assets	(27.8)	(27.4)
Amortization of Prior Service Cost (Credit)	(3.2)	(15.8)
Amortization of Net Actuarial Loss	0.8	3.7
Net Periodic Benefit Cost (Credit)	(18.6)	(26.8)
Other Postretirement Benefit Plans [Member] \| AEP Texas Inc. [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.1	0.1
Interest Cost	0.8	0.9
Expected Return on Plan Assets	(2.3)	(2.3)
Amortization of Prior Service Cost (Credit)	(0.3)	(1.3)
Amortization of Net Actuarial Loss	0.1	0.3
Net Periodic Benefit Cost (Credit)	(1.6)	(2.3)
Other Postretirement Benefit Plans [Member] \| Appalachian Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.1	0.1
Interest Cost	1.7	1.8
Expected Return on Plan Assets	(4)	(4)
Amortization of Prior Service Cost (Credit)	(0.5)	(2.3)
Amortization of Net Actuarial Loss	0.1	0.6
Net Periodic Benefit Cost (Credit)	(2.6)	(3.8)
Other Postretirement Benefit Plans [Member] \| Indiana Michigan Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.1	0.2
Interest Cost	1.2	1.3
Expected Return on Plan Assets	(3.4)	(3.4)
Amortization of Prior Service Cost (Credit)	(0.4)	(2.2)
Amortization of Net Actuarial Loss	0.1	0.5
Net Periodic Benefit Cost (Credit)	(2.4)	(3.6)
Other Postretirement Benefit Plans [Member] \| Ohio Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.1	0.1
Interest Cost	1.1	1.2
Expected Return on Plan Assets	(3)	(2.9)
Amortization of Prior Service Cost (Credit)	(0.3)	(1.6)
Amortization of Net Actuarial Loss	0.1	0.4
Net Periodic Benefit Cost (Credit)	(2)	(2.8)
Other Postretirement Benefit Plans [Member] \| Public Service Co Of Oklahoma [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.1	0.1
Interest Cost	0.5	0.6
Expected Return on Plan Assets	(1.4)	(1.5)
Amortization of Prior Service Cost (Credit)	(0.2)	(1)
Amortization of Net Actuarial Loss	0	0.2
Net Periodic Benefit Cost (Credit)	(1)	(1.6)
Other Postretirement Benefit Plans [Member] \| Southwestern Electric Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.1	0.1
Interest Cost	0.7	0.7
Expected Return on Plan Assets	(1.9)	(1.8)
Amortization of Prior Service Cost (Credit)	(0.3)	(1.2)
Amortization of Net Actuarial Loss	0.1	0.2
Net Periodic Benefit Cost (Credit)	$ (1.3)	$ (2)

Business Segments (Details)

Business Segments (Details) - USD ($) $ in Millions		3 Months Ended
Business Segments (Details) - USD ($) $ in Millions		Mar. 31, 2024		Mar. 31, 2023		Dec. 31, 2023
Reportable Segment Information
Interest Expense		$ 435.6		$ 415.7
Revenue from Contracts with Customers		5,025.7		4,690.9
Revenues		5,025.7		4,690.9
Net Income (Loss)		1,005.7		400.4
Income Tax (Expense) Benefit		(141.9)		10.4
Balance Sheet Information
Total Property, Plant and Equipment		102,832.8				$ 101,246.4
Accumulated Depreciation and Amortization		25,036.8				24,553
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		77,796				76,693.4
Total Assets		97,744.6				96,684
Long-term Debt Due Within One Year		1,198.6				2,490.5
Long-term Debt		38,637.3				37,652.7
Total Long-term Debt Outstanding		39,835.9				40,143.2
Related Party
Reportable Segment Information
Revenue from Contracts with Customers		0		0
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reportable Segment Information
Interest Expense	[1]	(1.2)		0.7
Income Tax (Expense) Benefit		(6.6)		9.1
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	[1]	(1.2)		0.7
Income Tax (Expense) Benefit		(0.3)		0.1
Vertically Integrated Utilities [Member]
Reportable Segment Information
Revenue from Contracts with Customers		2,901.2		2,816.3
Transmission and Distribution Utilities Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		1,483.2		1,455.3
Generation and Marketing Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		515.9		326.9
Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		125.4		92.4
Revenues		(60.8)	[2],[3]	(129.9)	[4],[5]
AEP Transmission Co [Member]
Reportable Segment Information
Interest Expense		54.8		45.2
Interest Income		1.9		1.5
Revenues from Related Parties, Net of Provisions for Refund		383.4		352.6
Revenues		482.8		441.6
Net Income (Loss)		181.2		162.7
Income Tax (Expense) Benefit		52.1		47.7
Balance Sheet Information
Total Property, Plant and Equipment		16,140.9				15,789
Accumulated Depreciation and Amortization		1,362.7				1,291.3
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		14,778.2				14,497.7
Total Assets		15,559				15,072.5
Long-term Debt Due Within One Year		145				95
Long-term Debt		5,715.7				5,319.4
Total Long-term Debt Outstanding		5,860.7				5,414.4
AEP Transmission Co [Member] \| Related Party
Reportable Segment Information
Revenue from Contracts with Customers		389.4		357.4
AEP Transmission Co [Member] \| Other Revenues [Member]
Reportable Segment Information
Revenue from Contract with Customers, Net of Provisions for Refund, Including Assessed Tax		2.4
Revenue from Contracts with Customers		2.4		0
Revenues		0	[6]	0	[7]
AEP Transmission Co [Member] \| Transmission [Member]
Reportable Segment Information
Revenue from Contract with Customers, Net of Provisions for Refund, Including Assessed Tax		97		89
Revenue from Contracts with Customers		98.4		90
Reconciling Adjustments [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0		0
Revenues		(526)		(443.7)
Net Income (Loss)		0		0
Balance Sheet Information
Total Assets	[8]	(4,407.2)				(4,324.6)
Reconciling Adjustments [Member] \| Related Party
Reportable Segment Information
Revenue from Contracts with Customers	[9]	(526)		(443.7)
Reconciling Adjustments [Member] \| Other Revenues [Member]
Reportable Segment Information
Revenues		8	[2],[3]	(0.9)	[4],[5]
Reconciling Adjustments [Member] \| AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0		0
Revenues		0		0
Net Income (Loss)		0		0
Balance Sheet Information
Total Assets	[10]	(6,000.3)				(5,534.7)
Reconciling Adjustments [Member] \| AEP Transmission Co [Member] \| Related Party
Reportable Segment Information
Revenue from Contracts with Customers		0		0
Reconciling Adjustments [Member] \| AEP Transmission Co [Member] \| Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0
Vertically Integrated Utilities [Member]
Reportable Segment Information
Revenues		2,947.9		2,857.8
Net Income (Loss)		562.3		262.2
Balance Sheet Information
Total Assets		52,379.2				51,802.1
Vertically Integrated Utilities [Member] \| Related Party
Reportable Segment Information
Revenue from Contracts with Customers		46.7		41.5
Vertically Integrated Utilities [Member] \| Vertically Integrated Utilities [Member]
Reportable Segment Information
Revenue from Contracts with Customers		2,901.2		2,816.3
Vertically Integrated Utilities [Member] \| Other Revenues [Member]
Reportable Segment Information
Revenues		(25.7)	[2],[3]	(0.1)	[4],[5]
Transmission And Distribution Utilities [Member]
Reportable Segment Information
Revenues		1,490.2		1,464.2
Net Income (Loss)		150.3		125.7
Balance Sheet Information
Total Assets		25,283.4				24,838.4
Transmission And Distribution Utilities [Member] \| Related Party
Reportable Segment Information
Revenue from Contracts with Customers		7		8.9
Transmission And Distribution Utilities [Member] \| Transmission and Distribution Utilities Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		1,483.2		1,455.3
Transmission And Distribution Utilities [Member] \| Other Revenues [Member]
Reportable Segment Information
Revenues		7.9	[2],[3]	11.1	[4],[5]
AEP Transmission Holdco [Member]
Reportable Segment Information
Revenues		497.3		455.5
Net Income (Loss)		209.8		182.4
Balance Sheet Information
Total Assets		17,067.4				16,575.6
AEP Transmission Holdco [Member] \| Related Party
Reportable Segment Information
Revenue from Contracts with Customers		386.8		365.4
AEP Transmission Holdco [Member] \| Transmission [Member]
Reportable Segment Information
Revenue from Contracts with Customers		110.5		90.1
Generation And Marketing [Member]
Reportable Segment Information
Revenues		563.5		327
Net Income (Loss)		137.6		(156.4)
Balance Sheet Information
Total Assets		2,257.5				2,598.5
Generation And Marketing [Member] \| Related Party
Reportable Segment Information
Revenue from Contracts with Customers		47.6		0.1
Generation And Marketing [Member] \| Generation and Marketing Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		515.9		326.9
Generation And Marketing [Member] \| Other Revenues [Member]
Reportable Segment Information
Revenues		(42.9)	[2],[3]	(141)	[4],[5]
All Other [Member]
Reportable Segment Information
Revenues	[11]	52.8		30.1
Net Income (Loss)	[11]	(54.3)		(13.5)
Balance Sheet Information
Total Assets	[11],[12]	5,164.3				5,194
All Other [Member] \| Related Party
Reportable Segment Information
Revenue from Contracts with Customers	[11]	37.9		27.8
All Other [Member] \| Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers	[11]	14.9		2.3
Revenues		(8.1)	[2],[3]	1	[4],[5]
State Transcos [Member] \| AEP Transmission Co [Member]
Reportable Segment Information
Revenues		482.8		441.6
Net Income (Loss)		181.7		161.6
Balance Sheet Information
Total Assets		15,609.4				15,120.6
State Transcos [Member] \| AEP Transmission Co [Member] \| Related Party
Reportable Segment Information
Revenue from Contracts with Customers		383.4		352.6
State Transcos [Member] \| AEP Transmission Co [Member] \| Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		2.4
State Transcos [Member] \| AEP Transmission Co [Member] \| Transmission [Member]
Reportable Segment Information
Revenue from Contracts with Customers		97		89
AEPTCo Parent [Member] \| AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0		0
Revenues		0		0
Net Income (Loss)	[13]	(0.5)		1.1
Balance Sheet Information
Total Assets	[14]	5,949.9				$ 5,486.6
AEPTCo Parent [Member] \| AEP Transmission Co [Member] \| Related Party
Reportable Segment Information
Revenue from Contracts with Customers		0		$ 0
AEPTCo Parent [Member] \| AEP Transmission Co [Member] \| Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		$ 0

[1] Amounts reclassified to the referenced line item on the statements of income. Amounts include affiliated and nonaffiliated revenues. Generation & Marketing includes economic hedge activity. Generation & Marketing includes economic hedge activity. Amounts include affiliated and nonaffiliated revenues. Amounts include affiliated and nonaffiliated revenues. Reconciling Adjustments for Total Assets primarily include elimination of intercompany advances to affiliates and intercompany accounts receivable. Represents inter-segment revenues. Primarily relates to the elimination of Notes Receivable from the State Transcos. 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. Includes elimination of AEP Parent’s investments in wholly-owned subsidiary companies. Includes the elimination of AEPTCo Parent’s equity earnings in the State Transcos. 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			12 Months Ended
		Mar. 31, 2024 USD ($) MMBTU MWh gal		Mar. 31, 2023 USD ($)	Dec. 31, 2023 USD ($) MMBTU MWh gal
Cash Collateral Netting
Cash Collateral Received Netted Against Risk Management Assets		$ 86,000,000			$ 46,000,000
Fair Value of Derivative Instruments
Current Risk Management Assets		152,700,000			217,500,000
Long-term Risk Management Assets		314,400,000			321,200,000
Total Assets		467,100,000			538,700,000
Current Risk Management Liabilities		184,400,000			229,600,000
Long-term Risk Management Liabilities		279,500,000			241,800,000
Total Liabilities		463,900,000			471,400,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(3,100,000)		$ (178,200,000)
Carrying Amount of Hedged Asset (Liability)	[1],[2]	(860,200,000)			(878,200,000)
Cumulative Fair Value Hedging Adjustment in the Carrying Amount of the Hedged Asset (Liability)	[1],[2]	86,700,000			68,400,000
Gain (Loss) on Hedging Instruments
Gain (Loss) on Fair Value Hedging Instruments	[3]	(16,400,000)		6,900,000
Gain (Loss) on Fair Value Portion of Long Term Debt	[3]	16,400,000		(6,900,000)
Collateral Triggering Events [Abstract]
Fair Value Of Derivative Liabilities Subject To Cross Acceleration Provisions		116,000,000			107,000,000
Fair Value Of Derivative Liabilities Subject To Cross Default Provisions		235,000,000			242,000,000
Derivatives and Hedging (Textuals) [Abstract]
Hedged Liability, Discontinued Fair Value Hedge, Cumulative Increase (Decrease)		(28,000,000)			(30,000,000)
AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Total Assets		2,500,000
Total Liabilities		100,000			2,700,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		400,000		(400,000)
Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		8,700,000			22,400,000
Current Risk Management Liabilities		18,400,000			15,900,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		14,000,000		(32,700,000)
Collateral Triggering Events [Abstract]
Fair Value Of Derivative Liabilities Subject To Cross Default Provisions		16,000,000			22,000,000
Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		11,200,000			27,800,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(25,200,000)		(4,600,000)
Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Liabilities		6,000,000			6,800,000
Long-term Risk Management Liabilities		35,000,000			43,900,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		8,600,000		(12,300,000)
Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		7,900,000			19,000,000
Current Risk Management Liabilities		28,500,000			28,900,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		17,100,000		16,800,000
Collateral Triggering Events [Abstract]
Fair Value Of Derivative Liabilities Subject To Cross Default Provisions		31,000,000			29,000,000
Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		19,900,000		10,400,000
Collateral Triggering Events [Abstract]
Fair Value Of Derivative Liabilities Subject To Cross Default Provisions		10,000,000			15,000,000
Risk Management Contracts [Member]
Fair Value of Derivative Instruments
Total Assets	[5]	346,900,000	[4]		403,900,000	[6]
Total Liabilities	[5]	346,200,000	[4]		362,300,000	[6]
Risk Management Contracts [Member] \| AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Total Assets	[5]	2,500,000
Total Liabilities	[5]	100,000			0
Risk Management Contracts [Member] \| Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[5]	8,700,000			22,400,000
Total Liabilities	[5]	20,500,000			22,500,000
Risk Management Contracts [Member] \| Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[5]	11,200,000			39,600,000
Total Liabilities	[5]	700,000			2,000,000
Risk Management Contracts [Member] \| Ohio Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[5]	100,000
Total Liabilities		41,000,000	[5]		50,700,000
Risk Management Contracts [Member] \| Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Total Assets	[5]	7,900,000			19,000,000
Total Liabilities	[5]	31,300,000			29,900,000
Risk Management Contracts [Member] \| Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[5]	5,300,000			11,600,000
Total Liabilities	[5]	11,100,000			15,600,000
Commodity [Member]
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		87,200,000			104,900,000
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		$ 24,000,000			38,300,000
Derivatives and Hedging (Textuals) [Abstract]
Maximum Term for Exposure to Variability of Future Cash Flows		84 months
Cross Acceleration Provisions Maximum Third Party Obligation Amount		$ 50,000,000
Cross Default Provisions Maximum Third Party Obligation Amount		50,000,000
Commodity [Member] \| AEP Texas Inc. [Member]
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		0			0
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		0			0
Commodity [Member] \| Appalachian Power Co [Member]
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		0			0
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		0			0
Commodity [Member] \| Indiana Michigan Power Co [Member]
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		0			0
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		0			0
Commodity [Member] \| Public Service Co Of Oklahoma [Member]
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		0			0
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		0			0
Commodity [Member] \| Southwestern Electric Power Co [Member]
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		0			0
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		0			0
Commodity [Member] \| Risk Management Contracts [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		436,200,000			555,100,000
Long-term Risk Management Assets		525,000,000			468,800,000
Current Risk Management Liabilities		456,900,000			588,000,000
Long-term Risk Management Liabilities		430,000,000			377,600,000
Commodity [Member] \| Risk Management Contracts [Member] \| AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		200,000			0
Long-term Risk Management Assets		0			0
Current Risk Management Liabilities		0			200,000
Long-term Risk Management Liabilities		0			0
Commodity [Member] \| Risk Management Contracts [Member] \| Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		9,900,000			24,600,000
Long-term Risk Management Assets		1,200,000			300,000
Current Risk Management Liabilities		21,000,000			18,500,000
Long-term Risk Management Liabilities		3,300,000			6,900,000
Commodity [Member] \| Risk Management Contracts [Member] \| Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		15,500,000			30,100,000
Long-term Risk Management Assets		0			12,000,000
Current Risk Management Liabilities		9,000,000			5,400,000
Long-term Risk Management Liabilities		0			200,000
Commodity [Member] \| Risk Management Contracts [Member] \| Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		100,000			0
Long-term Risk Management Assets		0			0
Current Risk Management Liabilities		6,000,000			6,900,000
Long-term Risk Management Liabilities		35,000,000			43,900,000
Commodity [Member] \| Risk Management Contracts [Member] \| Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		8,500,000			19,700,000
Long-term Risk Management Assets		0			0
Current Risk Management Liabilities		29,100,000			29,700,000
Long-term Risk Management Liabilities		2,800,000			1,000,000
Commodity [Member] \| Risk Management Contracts [Member] \| Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		5,500,000			12,000,000
Long-term Risk Management Assets		0			500,000
Current Risk Management Liabilities		9,500,000			14,900,000
Long-term Risk Management Liabilities		1,800,000			1,700,000
Commodity [Member] \| Hedging Contracts [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		35,400,000			56,700,000
Long-term Risk Management Assets		81,000,000			86,800,000
Current Risk Management Liabilities		5,100,000			8,200,000
Long-term Risk Management Liabilities		600,000			2,200,000
Commodity [Member] \| Hedging Contracts [Member] \| AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		0			0
Long-term Risk Management Assets		0			0
Current Risk Management Liabilities		0			0
Long-term Risk Management Liabilities		0			0
Commodity [Member] \| Hedging Contracts [Member] \| Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		0			0
Long-term Risk Management Assets		0			0
Current Risk Management Liabilities		0			0
Long-term Risk Management Liabilities		0			0
Commodity [Member] \| Hedging Contracts [Member] \| Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		0			0
Long-term Risk Management Assets		0			0
Current Risk Management Liabilities		0			0
Long-term Risk Management Liabilities		0			0
Commodity [Member] \| Hedging Contracts [Member] \| Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		0			0
Long-term Risk Management Assets		0			0
Current Risk Management Liabilities		0			0
Long-term Risk Management Liabilities		0			0
Commodity [Member] \| Hedging Contracts [Member] \| Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		0			0
Long-term Risk Management Assets		0			0
Current Risk Management Liabilities		0			0
Long-term Risk Management Liabilities		0			0
Commodity [Member] \| Hedging Contracts [Member] \| Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		0			0
Long-term Risk Management Assets		0			0
Current Risk Management Liabilities		0			0
Long-term Risk Management Liabilities		0			0
Interest Rate [Member]
Commodity:
Derivative, Notional Amount		1,500,000,000			1,300,000,000
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		3,400,000			(8,100,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		3,600,000			3,200,000
Interest Rate [Member] \| AEP Texas Inc. [Member]
Commodity:
Derivative, Notional Amount		150,000,000			150,000,000
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		4,400,000			500,000
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		500,000			200,000
Interest Rate [Member] \| Appalachian Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		5,700,000			5,900,000
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
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		(5,400,000)			(5,500,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		(400,000)			(400,000)
Interest Rate [Member] \| Ohio Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0
Interest Rate [Member] \| Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Notional Amount		0			0
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		(200,000)			(200,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		0			0
Interest Rate [Member] \| Southwestern Electric Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		1,200,000			1,300,000
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		300,000			300,000
Interest Rate [Member] \| Hedging Contracts [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		8,300,000			0
Long-term Risk Management Assets		0			0
Current Risk Management Liabilities		46,100,000			50,500,000
Long-term Risk Management Liabilities		70,400,000			56,900,000
Interest Rate [Member] \| Hedging Contracts [Member] \| AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		2,300,000			0
Long-term Risk Management Assets		0			0
Current Risk Management Liabilities		100,000			2,700,000
Long-term Risk Management Liabilities		0			0
Interest Rate [Member] \| Hedging Contracts [Member] \| Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		0			0
Long-term Risk Management Assets		0			0
Current Risk Management Liabilities		0			0
Long-term Risk Management Liabilities		0			0
Interest Rate [Member] \| Hedging Contracts [Member] \| Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		0			0
Long-term Risk Management Assets		0			0
Current Risk Management Liabilities		0			0
Long-term Risk Management Liabilities		0			0
Interest Rate [Member] \| Hedging Contracts [Member] \| Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		0			0
Long-term Risk Management Assets		0			0
Current Risk Management Liabilities		0			0
Long-term Risk Management Liabilities		0			0
Interest Rate [Member] \| Hedging Contracts [Member] \| Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		0			0
Long-term Risk Management Assets		0			0
Current Risk Management Liabilities		0			0
Long-term Risk Management Liabilities		0			0
Interest Rate [Member] \| Hedging Contracts [Member] \| Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		0			0
Long-term Risk Management Assets		0			0
Current Risk Management Liabilities		0			0
Long-term Risk Management Liabilities		0			0
Gross Amounts of Risk Management Assets/Liabilities Recognized [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		479,900,000			611,800,000
Long-term Risk Management Assets		606,000,000			555,600,000
Total Assets		1,085,900,000			1,167,400,000
Current Risk Management Liabilities		508,100,000			646,700,000
Long-term Risk Management Liabilities		501,000,000			436,700,000
Total Liabilities		1,009,100,000			1,083,400,000
Total MTM Derivative Contract Net Assets (Liabilities)		76,800,000			84,000,000
Gross Amounts of Risk Management Assets/Liabilities Recognized [Member] \| AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		2,500,000			0
Long-term Risk Management Assets		0			0
Total Assets		2,500,000			0
Current Risk Management Liabilities		100,000			2,900,000
Long-term Risk Management Liabilities		0			0
Total Liabilities		100,000			2,900,000
Total MTM Derivative Contract Net Assets (Liabilities)		2,400,000			(2,900,000)
Gross Amounts of Risk Management Assets/Liabilities Recognized [Member] \| Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		9,900,000			24,600,000
Long-term Risk Management Assets		1,200,000			300,000
Total Assets		11,100,000			24,900,000
Current Risk Management Liabilities		21,000,000			18,500,000
Long-term Risk Management Liabilities		3,300,000			6,900,000
Total Liabilities		24,300,000			25,400,000
Total MTM Derivative Contract Net Assets (Liabilities)		(13,200,000)			(500,000)
Gross Amounts of Risk Management Assets/Liabilities Recognized [Member] \| Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		15,500,000			30,100,000
Long-term Risk Management Assets		0			12,000,000
Total Assets		15,500,000			42,100,000
Current Risk Management Liabilities		9,000,000			5,400,000
Long-term Risk Management Liabilities		0			200,000
Total Liabilities		9,000,000			5,600,000
Total MTM Derivative Contract Net Assets (Liabilities)		6,500,000			36,500,000
Gross Amounts of Risk Management Assets/Liabilities Recognized [Member] \| Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		100,000			0
Long-term Risk Management Assets		0			0
Total Assets		100,000			0
Current Risk Management Liabilities		6,000,000			6,900,000
Long-term Risk Management Liabilities		35,000,000			43,900,000
Total Liabilities		41,000,000			50,800,000
Total MTM Derivative Contract Net Assets (Liabilities)		(40,900,000)			(50,800,000)
Gross Amounts of Risk Management Assets/Liabilities Recognized [Member] \| Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		8,500,000			19,700,000
Long-term Risk Management Assets		0			0
Total Assets		8,500,000			19,700,000
Current Risk Management Liabilities		29,100,000			29,700,000
Long-term Risk Management Liabilities		2,800,000			1,000,000
Total Liabilities		31,900,000			30,700,000
Total MTM Derivative Contract Net Assets (Liabilities)		(23,400,000)			(11,000,000)
Gross Amounts of Risk Management Assets/Liabilities Recognized [Member] \| Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		5,500,000			12,000,000
Long-term Risk Management Assets		0			500,000
Total Assets		5,500,000			12,500,000
Current Risk Management Liabilities		9,500,000			14,900,000
Long-term Risk Management Liabilities		1,800,000			1,700,000
Total Liabilities		11,300,000			16,600,000
Total MTM Derivative Contract Net Assets (Liabilities)		(5,800,000)			(4,100,000)
Gross Amounts Offset in the Statement of Financial Position [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		(327,200,000)			(394,300,000)
Long-term Risk Management Assets		(291,600,000)			(234,400,000)
Current Risk Management Liabilities		(323,700,000)			(417,100,000)
Long-term Risk Management Liabilities		(221,500,000)			(194,900,000)
Gross Amounts Offset in the Statement of Financial Position [Member] \| AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		0			0
Long-term Risk Management Assets		0			0
Current Risk Management Liabilities		0			(200,000)
Long-term Risk Management Liabilities		0			0
Gross Amounts Offset in the Statement of Financial Position [Member] \| Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		(1,200,000)			(2,200,000)
Long-term Risk Management Assets		(1,200,000)			(300,000)
Current Risk Management Liabilities		(2,600,000)			(2,600,000)
Long-term Risk Management Liabilities		(1,200,000)			(300,000)
Gross Amounts Offset in the Statement of Financial Position [Member] \| Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		(4,300,000)			(2,300,000)
Long-term Risk Management Assets		0			(200,000)
Current Risk Management Liabilities		(8,300,000)			(3,400,000)
Long-term Risk Management Liabilities		0			(200,000)
Gross Amounts Offset in the Statement of Financial Position [Member] \| Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		0			0
Long-term Risk Management Assets		0			0
Current Risk Management Liabilities		0			(100,000)
Long-term Risk Management Liabilities		0			0
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		(600,000)			(700,000)
Long-term Risk Management Assets		0			0
Current Risk Management Liabilities		(600,000)			(800,000)
Long-term Risk Management Liabilities		0			0
Gross Amounts Offset in the Statement of Financial Position [Member] \| Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		(200,000)			(400,000)
Long-term Risk Management Assets		0			(500,000)
Current Risk Management Liabilities		(200,000)			(500,000)
Long-term Risk Management Liabilities		0			(500,000)
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		152,700,000			217,500,000
Long-term Risk Management Assets		314,400,000			321,200,000
Total Assets		467,100,000			538,700,000
Current Risk Management Liabilities		184,400,000			229,600,000
Long-term Risk Management Liabilities		279,500,000			241,800,000
Total Liabilities		463,900,000			471,400,000
Total MTM Derivative Contract Net Assets (Liabilities)		3,200,000			67,300,000
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member] \| AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		2,500,000			0
Long-term Risk Management Assets		0			0
Total Assets		2,500,000			0
Current Risk Management Liabilities		100,000			2,700,000
Long-term Risk Management Liabilities		0			0
Total Liabilities		100,000			2,700,000
Total MTM Derivative Contract Net Assets (Liabilities)		2,400,000			(2,700,000)
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		8,700,000			22,400,000
Long-term Risk Management Assets		0			0
Total Assets		8,700,000			22,400,000
Current Risk Management Liabilities		18,400,000			15,900,000
Long-term Risk Management Liabilities		2,100,000			6,600,000
Total Liabilities		20,500,000			22,500,000
Total MTM Derivative Contract Net Assets (Liabilities)		(11,800,000)			(100,000)
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		11,200,000			27,800,000
Long-term Risk Management Assets		0			11,800,000
Total Assets		11,200,000			39,600,000
Current Risk Management Liabilities		700,000			2,000,000
Long-term Risk Management Liabilities		0			0
Total Liabilities		700,000			2,000,000
Total MTM Derivative Contract Net Assets (Liabilities)		10,500,000			37,600,000
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		100,000			0
Long-term Risk Management Assets		0			0
Total Assets		100,000			0
Current Risk Management Liabilities		6,000,000			6,800,000
Long-term Risk Management Liabilities		35,000,000			43,900,000
Total Liabilities		41,000,000			50,700,000
Total MTM Derivative Contract Net Assets (Liabilities)		(40,900,000)			(50,700,000)
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		7,900,000			19,000,000
Long-term Risk Management Assets		0			0
Total Assets		7,900,000			19,000,000
Current Risk Management Liabilities		28,500,000			28,900,000
Long-term Risk Management Liabilities		2,800,000			1,000,000
Total Liabilities		31,300,000			29,900,000
Total MTM Derivative Contract Net Assets (Liabilities)		(23,400,000)			(10,900,000)
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		5,300,000			11,600,000
Long-term Risk Management Assets		0			0
Total Assets		5,300,000			11,600,000
Current Risk Management Liabilities		9,300,000			14,400,000
Long-term Risk Management Liabilities		1,800,000			1,200,000
Total Liabilities		11,100,000			15,600,000
Total MTM Derivative Contract Net Assets (Liabilities)		$ (5,800,000)			$ (4,000,000)
Power [Member]
Commodity:
Derivative, Energy Notional Amount \| MWh		233.5			246.8
Power [Member] \| AEP Texas Inc. [Member]
Commodity:
Derivative, Energy Notional Amount \| MWh		0			0
Power [Member] \| Appalachian Power Co [Member]
Commodity:
Derivative, Energy Notional Amount \| MWh		7			16.8
Power [Member] \| Indiana Michigan Power Co [Member]
Commodity:
Derivative, Energy Notional Amount \| MWh		3.4			5.9
Power [Member] \| Ohio Power Co [Member]
Commodity:
Derivative, Energy Notional Amount \| MWh		2.2			2.2
Power [Member] \| Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Energy Notional Amount \| MWh		2.2			4.1
Power [Member] \| Southwestern Electric Power Co [Member]
Commodity:
Derivative, Energy Notional Amount \| MWh		1.6			2.9
Natural Gas [Member]
Commodity:
Derivative, Energy Notional Amount \| MMBTU		176.8			151.6
Natural Gas [Member] \| AEP Texas Inc. [Member]
Commodity:
Derivative, Energy Notional Amount \| MMBTU		0			0
Natural Gas [Member] \| Appalachian Power Co [Member]
Commodity:
Derivative, Energy Notional Amount \| MMBTU		43			37.3
Natural Gas [Member] \| Indiana Michigan Power Co [Member]
Commodity:
Derivative, Energy Notional Amount \| MMBTU		0			0
Natural Gas [Member] \| Ohio Power Co [Member]
Commodity:
Derivative, Energy Notional Amount \| MMBTU		0			0
Natural Gas [Member] \| Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Energy Notional Amount \| MMBTU		49			34.9
Natural Gas [Member] \| Southwestern Electric Power Co [Member]
Commodity:
Derivative, Energy Notional Amount \| MMBTU		19.7			17.9
Heating Oil and Gasoline [Member]
Commodity:
Derivative, Volume Notional Amount \| gal		7.7			6.5
Heating Oil and Gasoline [Member] \| AEP Texas Inc. [Member]
Commodity:
Derivative, Volume Notional Amount \| gal		2			1.8
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		1.2			0.6
Heating Oil and Gasoline [Member] \| Ohio Power Co [Member]
Commodity:
Derivative, Volume Notional Amount \| gal		1.3			1.2
Heating Oil and Gasoline [Member] \| Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Volume Notional Amount \| gal		0.8			0.7
Heating Oil and Gasoline [Member] \| Southwestern Electric Power Co [Member]
Commodity:
Derivative, Volume Notional Amount \| gal		1			0.9
Interest Rate Contract [Member]
Commodity:
Derivative, Notional Amount		$ 69,600,000			$ 80,100,000
Interest Rate Contract [Member] \| AEP Texas Inc. [Member]
Commodity:
Derivative, Notional Amount		0			0
Interest Rate Contract [Member] \| Appalachian Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0
Interest Rate Contract [Member] \| Indiana Michigan Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0
Interest Rate Contract [Member] \| Ohio Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0
Interest Rate Contract [Member] \| Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Notional Amount		0			0
Interest Rate Contract [Member] \| Southwestern Electric Power Co [Member]
Commodity:
Derivative, Notional Amount		0			$ 0
Vertically Integrated Utilities Revenues [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(25,700,000)		(5,300,000)
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
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
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
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
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
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
Generation and Marketing Revenues [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(44,700,000)		(147,400,000)
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
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
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
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
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
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
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
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
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		100,000		0
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		(25,800,000)		(5,300,000)
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
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
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
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		1,000,000		700,000
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
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		900,000		600,000
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		0		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
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		0
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
Maintenance Expense [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		100,000		100,000
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		0		0
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		0
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		0
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		0
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		0
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		0
Regulatory Assets [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[7]	13,500,000		(24,800,000)
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	[7]	200,000		(400,000)
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	[7]	(100,000)		(7,100,000)
Regulatory Assets [Member] \| Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[7]	(1,600,000)		(500,000)
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	[7]	8,600,000		(12,300,000)
Regulatory Assets [Member] \| Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[7]	(1,200,000)		(1,200,000)
Regulatory Assets [Member] \| Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[7]	4,900,000		(1,500,000)
Regulatory Liabilities [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[7]	52,700,000		(1,500,000)
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	[7]	200,000		0
Regulatory Liabilities [Member] \| Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[7]	13,100,000		(26,200,000)
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	[7]	2,200,000		1,200,000
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	[7]	0		0
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	[7]	18,300,000		18,000,000
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	[7]	$ 15,000,000		$ 11,900,000

[1] Amounts include $(28) million and $(30) million as of March 31, 2024 and December 31, 2023, respectively, for the fair value hedge adjustment of hedged debt obligations for which hedge accounting has been discontinued. Amounts included within Noncurrent Liabilities line item Long-term Debt on the Balance Sheet. Gain (Loss) is included in Interest Expense on the statements of income. The March 31, 2024 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $(14) million in 2024 and $(3) million in periods 2025-2027; Level 2 matures $(65) million in 2024, $51 million in periods 2025-2027 and $5 million in periods 2028-2029; Level 3 matures $34 million in 2024, $55 million in periods 2025-2027, $23 million in periods 2028-2029 and $(12) million in periods 2030-2032. Risk management commodity contracts are substantially comprised of power contracts. 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.’’ 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		12 Months Ended
		Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		$ 39,835,900,000		$ 40,143,200,000
Long Term Debt, Fair Value		36,392,200,000		37,325,700,000
Other Temporary Investments
Cost		245,900,000		243,500,000
Gross Unrealized Gains		29,000,000		25,900,000
Gross Unrealized Losses		(6,800,000)		(6,200,000)
Other Short-term Investments		268,100,000		263,200,000
Debt and Equity Securities Within Other Temporary Investments
Proceeds from Investment Sales		3,000,000	$ 0
Purchases of Investments		1,500,000	1,000,000
Gross Realized Gains on Investment Sales		300,000	0
Gross Realized Losses on Investment Sales		200,000	0
Nuclear Trust Fund Investments
Fair Value		4,112,600,000		3,860,200,000
Securities Activity Within Decommissioning and SNF Trusts
Payments to Acquire Investments		590,000,000	537,300,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		4,112,600,000		3,860,200,000
Spent Nuclear Fuel and Decommissioning Trusts [Member]
Securities Activity Within Decommissioning and SNF Trusts
Payments to Acquire Investments		588,500,000	536,300,000
Realized Investment Gains (Losses)		5,400,000	48,500,000
Gain (Loss) on Investments		1,200,000	8,600,000
Contractual Maturities, Fair Value of Debt Securities
Within 1 year		338,800,000
After 1 year through 5 years		598,000,000
After 5 years through 10 years		186,600,000
After 10 years		268,600,000
Fair Value Measurements (Textuals)
Adjusted Cost of Debt Securities		1,400,000,000		1,400,000,000
Adjusted Cost of Domestic Equity Securities		577,000,000		568,000,000
Other than Temporary Impairment Losses, Investments		(30,800,000)		(41,800,000)
Proceeds from Sale of Other Investments		569,500,000	517,600,000
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Loss, before Tax		(11,300,000)		(10,000,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		2,138,100,000		1,902,900,000
Cash [Member]
Other Temporary Investments
Cost	[1]	51,100,000		48,900,000
Gross Unrealized Gains	[1]	0		0
Gross Unrealized Losses	[1]	0		0
Other Short-term Investments	[1]	51,100,000		48,900,000
Fixed Income Funds [Member]
Nuclear Trust Fund Investments
Fair Value		1,392,000,000		1,406,800,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,392,000,000		1,406,800,000
Fixed Income Funds [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments		(30,800,000)		(41,800,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Loss, before Tax		(10,200,000)		(9,100,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		19,000,000		33,400,000
Mutual Funds Fixed Income [Member]
Other Temporary Investments
Cost	[2]	164,700,000		165,900,000
Gross Unrealized Gains	[2]	0		0
Gross Unrealized Losses	[2]	(6,800,000)		(6,200,000)
Other Short-term Investments	[2]	157,900,000		159,700,000
Domestic [Member]
Nuclear Trust Fund Investments
Fair Value	[3]	2,695,400,000		2,436,600,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[3]	2,695,400,000		2,436,600,000
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		(1,100,000)		(900,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		2,119,100,000		1,869,500,000
Mutual Funds Equity [Member]
Other Temporary Investments
Cost		14,700,000		14,800,000
Gross Unrealized Gains		29,000,000		25,900,000
Gross Unrealized Losses		0		0
Other Short-term Investments	[3]	43,700,000		40,700,000
Cash and Cash Equivalents [Member]
Nuclear Trust Fund Investments
Fair Value	[4]	25,200,000		16,800,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[4]	25,200,000		16,800,000
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
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		0		0
US Government Agencies Debt Securities [Member]
Nuclear Trust Fund Investments
Fair Value		1,267,000,000		1,273,000,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,267,000,000		1,273,000,000
US Government Agencies Debt Securities [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments		(25,700,000)		(33,200,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Loss, before Tax		(4,200,000)		(3,900,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		16,500,000		28,600,000
Corporate Debt [Member]
Nuclear Trust Fund Investments
Fair Value		123,300,000		132,100,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		123,300,000		132,100,000
Corporate Debt [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments		(5,100,000)		(8,600,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Loss, before Tax		(6,000,000)		(5,200,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		2,500,000		4,800,000
State and Local Jurisdiction [Member]
Nuclear Trust Fund Investments
Fair Value		1,700,000		1,700,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,700,000		1,700,000
State and Local Jurisdiction [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
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		0		0
Other Cash Deposits [Member]
Other Temporary Investments
Cost		15,400,000		13,900,000
Gross Unrealized Gains		0		0
Gross Unrealized Losses		0		0
Other Short-term Investments		15,400,000		13,900,000
AEP Texas Inc. [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		5,878,700,000		5,889,800,000
Long Term Debt, Fair Value		5,289,700,000		5,400,700,000
AEP Transmission Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		5,860,700,000		5,414,400,000
Long Term Debt, Fair Value		5,066,300,000		4,796,900,000
Appalachian Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		5,670,900,000		5,588,300,000
Long Term Debt, Fair Value		5,370,800,000		5,390,100,000
Indiana Michigan Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		3,478,500,000		3,499,400,000
Long Term Debt, Fair Value		3,182,300,000		3,291,600,000
Nuclear Trust Fund Investments
Fair Value		4,112,600,000		3,860,200,000
Securities Activity Within Decommissioning and SNF Trusts
Payments to Acquire Investments		588,500,000	536,300,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		4,112,600,000		3,860,200,000
Indiana Michigan Power Co [Member] \| Spent Nuclear Fuel and Decommissioning Trusts [Member]
Securities Activity Within Decommissioning and SNF Trusts
Payments to Acquire Investments		588,500,000	536,300,000
Realized Investment Gains (Losses)		5,400,000	48,500,000
Gain (Loss) on Investments		1,200,000	8,600,000
Contractual Maturities, Fair Value of Debt Securities
Within 1 year		338,800,000
After 1 year through 5 years		598,000,000
After 5 years through 10 years		186,600,000
After 10 years		268,600,000
Fair Value Measurements (Textuals)
Adjusted Cost of Debt Securities		1,400,000,000		1,400,000,000
Adjusted Cost of Domestic Equity Securities		577,000,000		568,000,000
Other than Temporary Impairment Losses, Investments		(30,800,000)		(41,800,000)
Proceeds from Sale of Other Investments		569,500,000	$ 517,600,000
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Loss, before Tax		(11,300,000)		(10,000,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		2,138,100,000		1,902,900,000
Indiana Michigan Power Co [Member] \| Fixed Income Funds [Member]
Nuclear Trust Fund Investments
Fair Value		1,392,000,000		1,406,800,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,392,000,000		1,406,800,000
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		(30,800,000)		(41,800,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Loss, before Tax		(10,200,000)		(9,100,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		19,000,000		33,400,000
Indiana Michigan Power Co [Member] \| Domestic [Member]
Nuclear Trust Fund Investments
Fair Value	[3]	2,695,400,000		2,436,600,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[3]	2,695,400,000		2,436,600,000
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		(1,100,000)		(900,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		2,119,100,000		1,869,500,000
Indiana Michigan Power Co [Member] \| Cash and Cash Equivalents [Member]
Nuclear Trust Fund Investments
Fair Value	[4]	25,200,000		16,800,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[4]	25,200,000		16,800,000
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
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		0		0
Indiana Michigan Power Co [Member] \| US Government Agencies Debt Securities [Member]
Nuclear Trust Fund Investments
Fair Value		1,267,000,000		1,273,000,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,267,000,000		1,273,000,000
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		(25,700,000)		(33,200,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Loss, before Tax		(4,200,000)		(3,900,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		16,500,000		28,600,000
Indiana Michigan Power Co [Member] \| Corporate Debt [Member]
Nuclear Trust Fund Investments
Fair Value		123,300,000		132,100,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		123,300,000		132,100,000
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		(5,100,000)		(8,600,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Loss, before Tax		(6,000,000)		(5,200,000)
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		2,500,000		4,800,000
Indiana Michigan Power Co [Member] \| State and Local Jurisdiction [Member]
Nuclear Trust Fund Investments
Fair Value		1,700,000		1,700,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,700,000		1,700,000
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		0
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Loss, before Tax		0		0
Debt Securities, Available-for-Sale, Accumulated Gross Unrealized Gain, before Tax		0		0
Ohio Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		3,367,400,000		3,366,800,000
Long Term Debt, Fair Value		2,912,100,000		2,992,100,000
Public Service Co Of Oklahoma [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		2,384,900,000		2,384,600,000
Long Term Debt, Fair Value		2,130,200,000		2,154,300,000
Southwestern Electric Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		3,647,600,000		3,646,900,000
Long Term Debt, Fair Value		$ 3,170,600,000		$ 3,209,700,000

[1] Primarily represents amounts held for the repayment of debt. Primarily short and intermediate maturities which may be sold and do not contain maturity dates. Amounts represent publicly traded equity securities and equity-based mutual funds. 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 ($)		3 Months Ended
Fair Value Assets and Liabilities (Details) - USD ($)		Mar. 31, 2024		Mar. 31, 2023	Dec. 31, 2023
Other [Member]
Risk Management Assets		$ (595,200,000)			$ (625,500,000)
Risk Management Liabilities		(521,600,000)			(608,800,000)
Assets, Fair Value Disclosure
Other Short-term Investments		15,400,000			13,900,000
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		11,900,000			9,000,000
Total Assets		(567,900,000)			(602,600,000)
Risk Management Assets
Risk Management Assets		(595,200,000)			(625,500,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities		(521,600,000)			(608,800,000)
Risk Management Assets		467,100,000			538,700,000
Risk Management Liabilities		463,900,000			471,400,000
Other Short-term Investments		268,100,000			263,200,000
Spent Nuclear Fuel and Decommissioning Trusts		4,112,600,000			3,860,200,000
Total Assets		4,847,800,000			4,662,100,000
Risk Management Assets		467,100,000			538,700,000
Risk Management Liabilities		463,900,000			471,400,000
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		139,400,000		$ 160,400,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	46,900,000		(7,100,000)
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[2]	11,300,000		14,800,000
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	600,000		(13,900,000)
Settlements		(96,600,000)		(96,600,000)
Transfers into Level 3	[4],[5]	4,600,000		(6,100,000)
Transfers out of Level 3	[5]	2,100,000		1,000,000
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	10,800,000		(7,400,000)
Ending Balance		119,100,000		45,100,000
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		39,835,900,000			40,143,200,000
Level 1 [Member]
Risk Management Assets		3,600,000			9,700,000
Risk Management Liabilities		21,000,000			24,700,000
Assets, Fair Value Disclosure
Other Short-term Investments		252,700,000			249,300,000
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		2,708,700,000			2,444,400,000
Total Assets		2,965,000,000			2,703,400,000
Risk Management Assets
Risk Management Assets		3,600,000			9,700,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		21,000,000			24,700,000
Level 2 [Member]
Risk Management Assets		782,500,000			860,400,000
Risk Management Liabilities		807,400,000			900,800,000
Assets, Fair Value Disclosure
Other Short-term Investments		0			0
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,392,000,000			1,406,800,000
Total Assets		2,174,500,000			2,267,200,000
Risk Management Assets
Risk Management Assets		782,500,000			860,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		807,400,000			900,800,000
Level 3 [Member]
Risk Management Assets		276,200,000			294,100,000
Risk Management Liabilities		157,100,000			154,700,000
Assets, Fair Value Disclosure
Other Short-term Investments		0			0
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Total Assets		276,200,000			294,100,000
Risk Management Assets
Risk Management Assets		276,200,000			294,100,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		157,100,000			154,700,000
2024 [Member] \| Level 1 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		(14,000,000)			(11,000,000)
2024 [Member] \| Level 2 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		(65,000,000)			(99,000,000)
2024 [Member] \| Level 3 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		34,000,000			74,000,000
2025 - 2027 [Member] \| Level 1 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		(3,000,000)			(4,000,000)
2025 - 2027 [Member] \| Level 2 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		51,000,000			(44,000,000)
2025 - 2027 [Member] \| Level 3 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		55,000,000			43,000,000
2028 - 2029 [Member] \| Level 2 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		5,000,000			7,000,000
2028 - 2029 [Member] \| Level 3 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		23,000,000			18,000,000
Maturity Period Four [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
Maturity Period Four [Member] \| Level 3 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		(12,000,000)			(16,000,000)
Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets	[8]	(593,900,000)	[7]		(617,000,000)	[9]
Risk Management Liabilities	[8]	(520,300,000)	[7]		(600,300,000)	[9]
Risk Management Assets
Risk Management Assets	[8]	(593,900,000)	[7]		(617,000,000)	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	(520,300,000)	[7]		(600,300,000)	[9]
Risk Management Commodity Contracts [Member]
Risk Management Assets	[8]	346,900,000	[7]		403,900,000	[9]
Risk Management Liabilities	[8]	346,200,000	[7]		362,300,000	[9]
Risk Management Assets
Risk Management Assets	[8]	346,900,000	[7]		403,900,000	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	346,200,000	[7]		362,300,000	[9]
Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets	[8]	3,600,000	[7]		9,700,000	[9]
Risk Management Liabilities	[8]	21,000,000	[7]		24,700,000	[9]
Risk Management Assets
Risk Management Assets	[8]	3,600,000	[7]		9,700,000	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	21,000,000	[7]		24,700,000	[9]
Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets	[8]	679,700,000	[7]		736,900,000	[9]
Risk Management Liabilities	[8]	688,400,000	[7]		783,800,000	[9]
Risk Management Assets
Risk Management Assets	[8]	679,700,000	[7]		736,900,000	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	688,400,000	[7]		783,800,000	[9]
Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets	[8]	257,500,000	[7]		274,300,000	[9]
Risk Management Liabilities	[8]	157,100,000	[7]		154,100,000	[9]
Risk Management Assets
Risk Management Assets	[8]	257,500,000	[7]		274,300,000	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	157,100,000	[7]		154,100,000	[9]
Energy Contracts [Member] \| Level 3 [Member]
Risk Management Assets		246,500,000			225,500,000
Risk Management Liabilities		146,100,000			144,900,000
Risk Management Assets
Risk Management Assets		246,500,000			225,500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		146,100,000			144,900,000
Energy Contracts [Member] \| Weighted Average [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	49.39			45.05
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	49.39			45.05
Energy Contracts [Member] \| Low [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	10.31			5.21
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	10.31			5.21
Energy Contracts [Member] \| High [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	169.47			153.77
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	169.47			153.77
Natural Gas Contracts [Member] \| Level 3 [Member]
Risk Management Assets					0
Risk Management Liabilities					500,000
Risk Management Assets
Risk Management Assets					0
Liabilities, Fair Value Disclosure
Risk Management Liabilities					500,000
Natural Gas Contracts [Member] \| Weighted Average [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[11],[12]				3.11
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[11],[12]				3.11
Natural Gas Contracts [Member] \| Low [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[12]				3.11
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[12]				3.11
Natural Gas Contracts [Member] \| High [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[12]				3.11
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[12]				3.11
FTRs [Member] \| Level 3 [Member]
Risk Management Assets		29,700,000			68,600,000
Risk Management Liabilities		11,000,000			9,300,000
Risk Management Assets
Risk Management Assets		29,700,000			68,600,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		11,000,000			9,300,000
FTRs [Member] \| Weighted Average [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	(0.35)			0
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	(0.35)			0
FTRs [Member] \| Low [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	(79.90)			(25.45)
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	(79.90)			(25.45)
FTRs [Member] \| High [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	23.79			17.07
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	23.79			17.07
Commodity Hedges [Member] \| Other [Member]
Risk Management Assets	[8]	(1,300,000)			(8,500,000)
Risk Management Liabilities	[8]	(1,300,000)			(8,500,000)
Risk Management Assets
Risk Management Assets	[8]	(1,300,000)			(8,500,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	(1,300,000)			(8,500,000)
Commodity Hedges [Member]
Risk Management Assets	[8]	111,900,000			134,800,000
Risk Management Liabilities	[8]	1,200,000			1,700,000
Risk Management Assets
Risk Management Assets	[8]	111,900,000			134,800,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	1,200,000			1,700,000
Commodity Hedges [Member] \| Level 1 [Member]
Risk Management Assets	[8]	0			0
Risk Management Liabilities	[8]	0			0
Risk Management Assets
Risk Management Assets	[8]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	0			0
Commodity Hedges [Member] \| Level 2 [Member]
Risk Management Assets	[8]	94,500,000			123,500,000
Risk Management Liabilities	[8]	2,500,000			9,600,000
Risk Management Assets
Risk Management Assets	[8]	94,500,000			123,500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	2,500,000			9,600,000
Commodity Hedges [Member] \| Level 3 [Member]
Risk Management Assets	[8]	18,700,000			19,800,000
Risk Management Liabilities	[8]	0			600,000
Risk Management Assets
Risk Management Assets	[8]	18,700,000			19,800,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	0			600,000
Interest Rate [Member] \| Other [Member]
Risk Management Assets		0
Risk Management Liabilities		0			0
Risk Management Assets
Risk Management Assets		0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0
Interest Rate [Member]
Risk Management Assets		8,300,000
Risk Management Liabilities		1,700,000			9,000,000
Risk Management Assets
Risk Management Assets		8,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		1,700,000			9,000,000
Interest Rate [Member] \| Level 1 [Member]
Risk Management Assets		0
Risk Management Liabilities		0			0
Risk Management Assets
Risk Management Assets		0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0
Interest Rate [Member] \| Level 2 [Member]
Risk Management Assets		8,300,000
Risk Management Liabilities		1,700,000			9,000,000
Risk Management Assets
Risk Management Assets		8,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		1,700,000			9,000,000
Interest Rate [Member] \| Level 3 [Member]
Risk Management Assets		0
Risk Management Liabilities		0			0
Risk Management Assets
Risk Management Assets		0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0
Fair Value Hedges [Member] \| Other [Member]
Risk Management Liabilities		0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0
Fair Value Hedges [Member]
Risk Management Liabilities		114,800,000			98,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		114,800,000			98,400,000
Fair Value Hedges [Member] \| Level 1 [Member]
Risk Management Liabilities		0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0
Fair Value Hedges [Member] \| Level 2 [Member]
Risk Management Liabilities		114,800,000			98,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		114,800,000			98,400,000
Fair Value Hedges [Member] \| Level 3 [Member]
Risk Management Liabilities		0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0
AEP Texas Inc. [Member] \| Other [Member]
Risk Management Assets		0
Risk Management Liabilities		0			(200,000)
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		0
Risk Management Assets
Risk Management Assets		0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			(200,000)
AEP Texas Inc. [Member]
Risk Management Assets		2,500,000
Risk Management Liabilities		100,000			2,700,000
Assets, Fair Value Disclosure
Cash and Cash Equivalents		42,700,000			34,000,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		45,200,000
Risk Management Assets
Risk Management Assets		2,500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		100,000			2,700,000
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		5,878,700,000			5,889,800,000
AEP Texas Inc. [Member] \| Level 1 [Member]
Risk Management Assets		0
Risk Management Liabilities		0			0
Assets, Fair Value Disclosure
Cash and Cash Equivalents		42,700,000			34,000,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		42,700,000
Risk Management Assets
Risk Management Assets		0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0
AEP Texas Inc. [Member] \| Level 2 [Member]
Risk Management Assets		2,500,000
Risk Management Liabilities		100,000			2,900,000
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		2,500,000
Risk Management Assets
Risk Management Assets		2,500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		100,000			2,900,000
AEP Texas Inc. [Member] \| Level 3 [Member]
Risk Management Assets		0
Risk Management Liabilities		0			0
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		0
Risk Management Assets
Risk Management Assets		0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0
AEP Texas Inc. [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets	[8]	2,300,000
Risk Management Liabilities	[8]	100,000			(200,000)
Risk Management Assets
Risk Management Assets	[8]	2,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	100,000			(200,000)
AEP Texas Inc. [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Assets	[8]	2,500,000
Risk Management Liabilities	[8]	100,000			0
Risk Management Assets
Risk Management Assets	[8]	2,500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	100,000			0
AEP Texas Inc. [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets	[8]	0
Risk Management Liabilities	[8]	0			0
Risk Management Assets
Risk Management Assets	[8]	0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	0			0
AEP Texas Inc. [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets	[8]	200,000
Risk Management Liabilities	[8]	0			200,000
Risk Management Assets
Risk Management Assets	[8]	200,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	0			200,000
AEP Texas Inc. [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets	[8]	0
Risk Management Liabilities	[8]	0			0
Risk Management Assets
Risk Management Assets	[8]	0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	0			0
AEP Texas Inc. [Member] \| Interest Rate [Member] \| Other [Member]
Risk Management Assets		(2,300,000)
Risk Management Liabilities		(100,000)			0
Risk Management Assets
Risk Management Assets		(2,300,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities		(100,000)			0
AEP Texas Inc. [Member] \| Interest Rate [Member]
Risk Management Assets		0
Risk Management Liabilities		0			2,700,000
Risk Management Assets
Risk Management Assets		0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			2,700,000
AEP Texas Inc. [Member] \| Interest Rate [Member] \| Level 1 [Member]
Risk Management Assets		0
Risk Management Liabilities		0			0
Risk Management Assets
Risk Management Assets		0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0
AEP Texas Inc. [Member] \| Interest Rate [Member] \| Level 2 [Member]
Risk Management Assets		2,300,000
Risk Management Liabilities		100,000			2,700,000
Risk Management Assets
Risk Management Assets		2,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		100,000			2,700,000
AEP Texas Inc. [Member] \| Interest Rate [Member] \| Level 3 [Member]
Risk Management Assets		0
Risk Management Liabilities		0			0
Risk Management Assets
Risk Management Assets		0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0
AEP Transmission Co [Member]
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		5,860,700,000			5,414,400,000
Appalachian Power Co [Member] \| Other [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		(2,000,000)			(2,200,000)
Appalachian Power Co [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		8,400,000			14,900,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		17,100,000			37,300,000
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		22,400,000		69,100,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	9,200,000		(31,900,000)
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[2]	0		0
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	0		0
Settlements		(26,800,000)		(27,300,000)
Transfers into Level 3	[4],[5]	0		0
Transfers out of Level 3	[5]	0		0
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	(800,000)		(4,200,000)
Ending Balance		4,000,000		5,700,000
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		5,670,900,000			5,588,300,000
Appalachian Power Co [Member] \| Level 1 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		8,400,000			14,900,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		8,400,000			14,900,000
Appalachian Power Co [Member] \| Level 2 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		2,100,000			1,100,000
Appalachian Power Co [Member] \| Level 3 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		8,600,000			23,500,000
Appalachian Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets	[8]	(2,000,000)			(2,200,000)
Risk Management Liabilities	[8]	(3,400,000)			(2,600,000)
Risk Management Assets
Risk Management Assets	[8]	(2,000,000)			(2,200,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	(3,400,000)			(2,600,000)
Appalachian Power Co [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Assets	[8]	8,700,000			22,400,000
Risk Management Liabilities	[8]	20,500,000			22,500,000
Risk Management Assets
Risk Management Assets	[8]	8,700,000			22,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	20,500,000			22,500,000
Appalachian Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets	[8]	0			0
Risk Management Liabilities	[8]	0			0
Risk Management Assets
Risk Management Assets	[8]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	0			0
Appalachian Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets	[8]	2,100,000			1,100,000
Risk Management Liabilities	[8]	19,300,000			24,000,000
Risk Management Assets
Risk Management Assets	[8]	2,100,000			1,100,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	19,300,000			24,000,000
Appalachian Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets	[8]	8,600,000			23,500,000
Risk Management Liabilities	[8]	4,600,000			1,100,000
Risk Management Assets
Risk Management Assets	[8]	8,600,000			23,500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	4,600,000			1,100,000
Appalachian Power Co [Member] \| FTRs [Member] \| Level 3 [Member]
Risk Management Assets		8,600,000			23,500,000
Risk Management Liabilities		4,600,000			1,100,000
Risk Management Assets
Risk Management Assets		8,600,000			23,500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		4,600,000			1,100,000
Appalachian Power Co [Member] \| FTRs [Member] \| Weighted Average [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	0.61			1.36
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	0.61			1.36
Appalachian Power Co [Member] \| FTRs [Member] \| Low [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	(0.38)			(1.04)
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	(0.38)			(1.04)
Appalachian Power Co [Member] \| FTRs [Member] \| High [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	5.05			6.45
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	5.05			6.45
Indiana Michigan Power Co [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		11,900,000			9,000,000
Total Assets		8,200,000			6,700,000
Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		4,112,600,000			3,860,200,000
Total Assets		4,123,800,000			3,899,800,000
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		2,800,000		4,600,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	3,200,000		1,200,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[2]	0		0
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	0		0
Settlements		(4,800,000)		(4,200,000)
Transfers into Level 3	[4],[5]	0		0
Transfers out of Level 3	[5]	0		0
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	(200,000)		(500,000)
Ending Balance		1,000,000		1,100,000
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		3,478,500,000			3,499,400,000
Indiana Michigan Power Co [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		2,708,700,000			2,444,400,000
Total Assets		2,708,700,000			2,444,400,000
Indiana Michigan Power Co [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,392,000,000			1,406,800,000
Total Assets		1,405,100,000			1,444,200,000
Indiana Michigan Power Co [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Total Assets		1,800,000			4,500,000
Indiana Michigan Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets	[8]	(3,700,000)			(2,300,000)
Risk Management Liabilities	[8]	(7,700,000)			(3,400,000)
Risk Management Assets
Risk Management Assets	[8]	(3,700,000)			(2,300,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	(7,700,000)			(3,400,000)
Indiana Michigan Power Co [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Assets	[8]	11,200,000			39,600,000
Risk Management Liabilities	[8]	700,000			2,000,000
Risk Management Assets
Risk Management Assets	[8]	11,200,000			39,600,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	700,000			2,000,000
Indiana Michigan Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets	[8]	0			0
Risk Management Liabilities	[8]	0			0
Risk Management Assets
Risk Management Assets	[8]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	0			0
Indiana Michigan Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets	[8]	13,100,000			37,400,000
Risk Management Liabilities	[8]	7,600,000			3,700,000
Risk Management Assets
Risk Management Assets	[8]	13,100,000			37,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	7,600,000			3,700,000
Indiana Michigan Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets	[8]	1,800,000			4,500,000
Risk Management Liabilities	[8]	800,000			1,700,000
Risk Management Assets
Risk Management Assets	[8]	1,800,000			4,500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	800,000			1,700,000
Indiana Michigan Power Co [Member] \| FTRs [Member] \| Level 3 [Member]
Risk Management Assets		1,800,000			4,500,000
Risk Management Liabilities		800,000			1,700,000
Risk Management Assets
Risk Management Assets		1,800,000			4,500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		800,000			1,700,000
Indiana Michigan Power Co [Member] \| FTRs [Member] \| Weighted Average [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	0.84			(0.85)
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	0.84			(0.85)
Indiana Michigan Power Co [Member] \| FTRs [Member] \| Low [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	0.03			(1.48)
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	0.03			(1.48)
Indiana Michigan Power Co [Member] \| FTRs [Member] \| High [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	6.82			8.40
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	6.82			8.40
Ohio Power Co [Member]
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		(50,600,000)		(40,000,000)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	(400,000)		(1,300,000)
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[2]	0		0
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	0		0
Settlements		2,600,000		1,000,000
Transfers into Level 3	[4],[5]	0		0
Transfers out of Level 3	[5]	0		0
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	7,400,000		(6,600,000)
Ending Balance		(41,000,000)		(46,900,000)
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		3,367,400,000			3,366,800,000
Ohio Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets	[8]	0
Risk Management Liabilities	[8]	0			(100,000)
Risk Management Assets
Risk Management Assets	[8]	0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	0			(100,000)
Ohio Power Co [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Assets	[8]	100,000
Risk Management Liabilities		41,000,000	[8]		50,700,000
Risk Management Assets
Risk Management Assets	[8]	100,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		41,000,000	[8]		50,700,000
Ohio Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets	[8]	0
Risk Management Liabilities		0	[8]		0
Risk Management Assets
Risk Management Assets	[8]	0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0	[8]		0
Ohio Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets	[8]	100,000
Risk Management Liabilities		0	[8]		200,000
Risk Management Assets
Risk Management Assets	[8]	100,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0	[8]		200,000
Ohio Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets	[8]	0
Risk Management Liabilities		41,000,000	[8]		50,600,000
Risk Management Assets
Risk Management Assets	[8]	0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		41,000,000	[8]		50,600,000
Ohio Power Co [Member] \| Energy Contracts [Member] \| Level 3 [Member]
Risk Management Assets		0			0
Risk Management Liabilities		41,000,000			50,600,000
Risk Management Assets
Risk Management Assets		0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		41,000,000			50,600,000
Ohio Power Co [Member] \| Energy Contracts [Member] \| Weighted Average [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	47.20			42.85
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	47.20			42.85
Ohio Power Co [Member] \| Energy Contracts [Member] \| Low [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	19.72			22.92
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	19.72			22.92
Ohio Power Co [Member] \| Energy Contracts [Member] \| High [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	75.88			67.53
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	75.88			67.53
Public Service Co Of Oklahoma [Member]
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		18,600,000		23,700,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	18,500,000		16,600,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[2]	0		0
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	0		0
Settlements		(31,300,000)		(34,300,000)
Transfers into Level 3	[4],[5]	0		0
Transfers out of Level 3	[5]	0		0
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	1,900,000		3,300,000
Ending Balance		7,700,000		9,300,000
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		2,384,900,000			2,384,600,000
Public Service Co Of Oklahoma [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets	[8]	(600,000)			(700,000)
Risk Management Liabilities	[8]	(600,000)			(800,000)
Risk Management Assets
Risk Management Assets	[8]	(600,000)			(700,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	(600,000)			(800,000)
Public Service Co Of Oklahoma [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Assets	[8]	7,900,000			19,000,000
Risk Management Liabilities	[8]	31,300,000			29,900,000
Risk Management Assets
Risk Management Assets	[8]	7,900,000			19,000,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	31,300,000			29,900,000
Public Service Co Of Oklahoma [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets	[8]	0			0
Risk Management Liabilities	[8]	0			0
Risk Management Assets
Risk Management Assets	[8]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	0			0
Public Service Co Of Oklahoma [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets	[8]	100,000			0
Risk Management Liabilities	[8]	31,200,000			29,600,000
Risk Management Assets
Risk Management Assets	[8]	100,000			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	31,200,000			29,600,000
Public Service Co Of Oklahoma [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets	[8]	8,400,000			19,700,000
Risk Management Liabilities	[8]	700,000			1,100,000
Risk Management Assets
Risk Management Assets	[8]	8,400,000			19,700,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	700,000			1,100,000
Public Service Co Of Oklahoma [Member] \| FTRs [Member] \| Level 3 [Member]
Risk Management Assets		8,400,000			19,700,000
Risk Management Liabilities		700,000			1,100,000
Risk Management Assets
Risk Management Assets		8,400,000			19,700,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		700,000			1,100,000
Public Service Co Of Oklahoma [Member] \| FTRs [Member] \| Weighted Average [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	(3.48)			(4.33)
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	(3.48)			(4.33)
Public Service Co Of Oklahoma [Member] \| FTRs [Member] \| Low [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	(79.90)			(25.45)
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	(79.90)			(25.45)
Public Service Co Of Oklahoma [Member] \| FTRs [Member] \| High [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	3.13			4.80
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	3.13			4.80
Southwestern Electric Power Co [Member]
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		11,100,000		14,200,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	14,700,000		12,900,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[2]	0		0
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	0		0
Settlements		(23,600,000)		(23,000,000)
Transfers into Level 3	[4],[5]	0		0
Transfers out of Level 3	[5]	500,000		0
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	2,600,000		1,700,000
Ending Balance		5,300,000		$ 5,800,000
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		3,647,600,000			3,646,900,000
Southwestern Electric Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Other [Member]
Risk Management Assets	[8]	(300,000)			(900,000)
Risk Management Liabilities	[8]	(200,000)			(1,000,000)
Risk Management Assets
Risk Management Assets	[8]	(300,000)			(900,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	(200,000)			(1,000,000)
Southwestern Electric Power Co [Member] \| Risk Management Commodity Contracts [Member]
Risk Management Assets	[8]	5,300,000			11,600,000
Risk Management Liabilities	[8]	11,100,000			15,600,000
Risk Management Assets
Risk Management Assets	[8]	5,300,000			11,600,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	11,100,000			15,600,000
Southwestern Electric Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 1 [Member]
Risk Management Assets	[8]	0			0
Risk Management Liabilities	[8]	0			0
Risk Management Assets
Risk Management Assets	[8]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	0			0
Southwestern Electric Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 2 [Member]
Risk Management Assets	[8]	100,000			500,000
Risk Management Liabilities	[8]	11,100,000			15,700,000
Risk Management Assets
Risk Management Assets	[8]	100,000			500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	11,100,000			15,700,000
Southwestern Electric Power Co [Member] \| Risk Management Commodity Contracts [Member] \| Level 3 [Member]
Risk Management Assets	[8]	5,500,000			12,000,000
Risk Management Liabilities	[8]	200,000			900,000
Risk Management Assets
Risk Management Assets	[8]	5,500,000			12,000,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[8]	200,000			900,000
Southwestern Electric Power Co [Member] \| Natural Gas Contracts [Member] \| Level 3 [Member]
Risk Management Assets					0
Risk Management Liabilities					500,000
Risk Management Assets
Risk Management Assets					0
Liabilities, Fair Value Disclosure
Risk Management Liabilities					500,000
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]				3.11
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[11],[12]				3.11
Southwestern Electric Power Co [Member] \| Natural Gas Contracts [Member] \| Low [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[12]				3.11
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[12]				3.11
Southwestern Electric Power Co [Member] \| Natural Gas Contracts [Member] \| High [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[12]				3.11
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[12]				3.11
Southwestern Electric Power Co [Member] \| FTRs [Member] \| Level 3 [Member]
Risk Management Assets		5,500,000			12,000,000
Risk Management Liabilities		200,000			400,000
Risk Management Assets
Risk Management Assets		5,500,000			12,000,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		200,000			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]	(3.48)			(4.33)
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	(3.48)			(4.33)
Southwestern Electric Power Co [Member] \| FTRs [Member] \| Low [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	(79.90)			(25.45)
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	(79.90)			(25.45)
Southwestern Electric Power Co [Member] \| FTRs [Member] \| High [Member] \| Level 3 [Member]
Fair Value Significant Unobservable Input Price Per Unit	[10]	3.13			4.80
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	3.13			4.80
Cash [Member] \| Other [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0
Cash [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		51,100,000			48,900,000
Other Short-term Investments	[13]	51,100,000			48,900,000
Cash [Member] \| Level 1 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		51,100,000			48,900,000
Cash [Member] \| Level 2 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0
Cash [Member] \| Level 3 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0
Other Cash Deposits [Member] \| Other [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[14]	15,400,000			13,900,000
Other Cash Deposits [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		15,400,000			13,900,000
Other Cash Deposits [Member] \| Level 1 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0
Other Cash Deposits [Member] \| Level 2 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0
Other Cash Deposits [Member] \| Level 3 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0
Mutual Funds Fixed Income [Member] \| Other [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0
Mutual Funds Fixed Income [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[15]	157,900,000			159,700,000
Mutual Funds Fixed Income [Member] \| Level 1 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		157,900,000			159,700,000
Mutual Funds Fixed Income [Member] \| Level 2 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0
Mutual Funds Fixed Income [Member] \| Level 3 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0
Mutual Funds Equity [Member] \| Other [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[16]	0			0
Mutual Funds Equity [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[16]	43,700,000			40,700,000
Mutual Funds Equity [Member] \| Level 1 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[16]	43,700,000			40,700,000
Mutual Funds Equity [Member] \| Level 2 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[16]	0			0
Mutual Funds Equity [Member] \| Level 3 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[16]	0			0
Cash and Cash Equivalents [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[17]	11,900,000			9,000,000
Cash and Cash Equivalents [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[17]	25,200,000			16,800,000
Cash and Cash Equivalents [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[17]	13,300,000			7,800,000
Cash and Cash Equivalents [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[17]	0			0
Cash and Cash Equivalents [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[17]	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	[17]	11,900,000			9,000,000
Cash and Cash Equivalents [Member] \| Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[17]	25,200,000			16,800,000
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	[17]	13,300,000			7,800,000
Cash and Cash Equivalents [Member] \| Indiana Michigan Power Co [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[17]	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	[17]	0			0
US Government Agencies Debt Securities [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
US Government Agencies Debt Securities [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,267,000,000			1,273,000,000
US Government Agencies Debt Securities [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
US Government Agencies Debt Securities [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,267,000,000			1,273,000,000
US Government Agencies Debt Securities [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
US Government Agencies Debt Securities [Member] \| Indiana Michigan Power Co [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
US Government Agencies Debt Securities [Member] \| Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,267,000,000			1,273,000,000
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
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		1,267,000,000			1,273,000,000
US Government Agencies Debt Securities [Member] \| Indiana Michigan Power Co [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Corporate Debt [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Corporate Debt [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		123,300,000			132,100,000
Corporate Debt [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Corporate Debt [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		123,300,000			132,100,000
Corporate Debt [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		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
Corporate Debt [Member] \| Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		123,300,000			132,100,000
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
Corporate Debt [Member] \| Indiana Michigan Power Co [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		123,300,000			132,100,000
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
State and Local Jurisdiction [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
State and Local Jurisdiction [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,700,000			1,700,000
State and Local Jurisdiction [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
State and Local Jurisdiction [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,700,000			1,700,000
State and Local Jurisdiction [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		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
State and Local Jurisdiction [Member] \| Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,700,000			1,700,000
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
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		1,700,000			1,700,000
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
Fixed Income Funds [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Fixed Income Funds [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,392,000,000			1,406,800,000
Fixed Income Funds [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Fixed Income Funds [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,392,000,000			1,406,800,000
Fixed Income Funds [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Fixed Income Funds [Member] \| Indiana Michigan Power Co [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Fixed Income Funds [Member] \| Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,392,000,000			1,406,800,000
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
Fixed Income Funds [Member] \| Indiana Michigan Power Co [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,392,000,000			1,406,800,000
Fixed Income Funds [Member] \| Indiana Michigan Power Co [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Domestic [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[16]	0			0
Domestic [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[16]	2,695,400,000			2,436,600,000
Domestic [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[16]	2,695,400,000			2,436,600,000
Domestic [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[16]	0			0
Domestic [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[16]	0			0
Domestic [Member] \| Indiana Michigan Power Co [Member] \| Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[16]	0			0
Domestic [Member] \| Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[16]	2,695,400,000			2,436,600,000
Domestic [Member] \| Indiana Michigan Power Co [Member] \| Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[16]	2,695,400,000			2,436,600,000
Domestic [Member] \| Indiana Michigan Power Co [Member] \| Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[16]	0			0
Domestic [Member] \| Indiana Michigan Power Co [Member] \| Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[16]	$ 0			$ 0

[1] Represents the change in fair value between the beginning of the reporting period and the settlement of the risk management commodity contract. Included in revenues on the statements of income. Included in cash flow hedges on the statements of comprehensive income. Represents existing assets or liabilities that were previously categorized as Level 2. Transfers are recognized based on their value at the beginning of the reporting period that the transfer occurred. 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 March 31, 2024 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $(14) million in 2024 and $(3) million in periods 2025-2027; Level 2 matures $(65) million in 2024, $51 million in periods 2025-2027 and $5 million in periods 2028-2029; Level 3 matures $34 million in 2024, $55 million in periods 2025-2027, $23 million in periods 2028-2029 and $(12) million in periods 2030-2032. Risk management commodity contracts are substantially comprised of power contracts. 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.’’ Represents market prices in dollars per MWh. The weighted average is the product of the forward market price of the underlying commodity and volume weighted by term. Represents market prices in dollars per MMBtu. Primarily represents amounts held for the repayment of debt. 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. Primarily short and intermediate maturities which may be sold and do not contain maturity dates. Amounts represent publicly traded equity securities and equity-based mutual funds. Amounts in “Other’’ column primarily represent accrued interest receivables from financial institutions. Level 1 amounts primarily represent investments in money market funds.

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions		3 Months Ended		12 Months Ended
Income Taxes (Details) - USD ($) $ in Millions	Apr. 30, 2024	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate		21%	21%
State Income Tax, net of Federal Benefit		2.10%	1.90%
Tax Reform Excess ADIT Reversal		(2.30%)	(6.20%)
Remeasurement of Excess ADIT		(29.70%)
Production and Investment Tax Credits		(6.80%)	(9.70%)
Flow Through		0%	0.10%
AFUDC Equity		(1.20%)	(1.40%)
Discrete Tax Adjustments		0.20%	(3.20%)
Other		0.20%	0.10%
Effective Income Tax Rate		(16.50%)	2.60%
Income Taxes (Textuals) [Abstract]
corporate alternative minimum tax		15%
Production Tax Credit Proceeds	$ 10	$ 62		$ 102
AEP Texas Inc. [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate		21%	21%
State Income Tax, net of Federal Benefit		0.20%	0.30%
Tax Reform Excess ADIT Reversal		(1.30%)	(1.50%)
Remeasurement of Excess ADIT		0%
Production and Investment Tax Credits		(0.20%)	(0.20%)
Flow Through		0.10%	0.20%
AFUDC Equity		(1.50%)	(1.50%)
Discrete Tax Adjustments		0%	0%
Other		0.50%	0.10%
Effective Income Tax Rate		18.80%	18.40%
AEP Transmission Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate		21%	21%
State Income Tax, net of Federal Benefit		2.60%	2.60%
Tax Reform Excess ADIT Reversal		0.20%	0.30%
Remeasurement of Excess ADIT		0%
Production and Investment Tax Credits		0%	0%
Flow Through		0.30%	0.30%
AFUDC Equity		(1.80%)	(1.60%)
Discrete Tax Adjustments		0%	0%
Other		0%	0.10%
Effective Income Tax Rate		22.30%	22.70%
Appalachian Power Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate		21%	21%
State Income Tax, net of Federal Benefit		2.40%	2.40%
Tax Reform Excess ADIT Reversal		(13.40%)	(4.60%)
Remeasurement of Excess ADIT		0%
Production and Investment Tax Credits		(0.10%)	0%
Flow Through		(0.30%)	0.60%
AFUDC Equity		(0.40%)	(0.70%)
Discrete Tax Adjustments		0%	3.20%
Other		0.10%	0%
Effective Income Tax Rate		9.30%	21.90%
Indiana Michigan Power Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate		21%	21%
State Income Tax, net of Federal Benefit		3.90%	3.60%
Tax Reform Excess ADIT Reversal		(0.50%)	(7.90%)
Remeasurement of Excess ADIT		(58.20%)
Production and Investment Tax Credits		(1.10%)	(1.10%)
Flow Through		(2.80%)	(1.80%)
AFUDC Equity		(0.70%)	(0.50%)
Discrete Tax Adjustments		0%	1.80%
Other		0%	0%
Effective Income Tax Rate		(38.40%)	15.10%
Income Taxes (Textuals) [Abstract]
Tax Benefit Recognized from the Reduction in Excess ADIT Resulting from IRS PLR Received		$ 61
Ohio Power Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate		21%	21%
State Income Tax, net of Federal Benefit		1%	1%
Tax Reform Excess ADIT Reversal		(6.00%)	(6.80%)
Remeasurement of Excess ADIT		0%
Production and Investment Tax Credits		0%	0%
Flow Through		0.60%	0.50%
AFUDC Equity		(1.00%)	(0.80%)
Discrete Tax Adjustments		0%	0%
Other		0.20%	0%
Effective Income Tax Rate		15.80%	14.90%
Public Service Co Of Oklahoma [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate		21%	21%
State Income Tax, net of Federal Benefit		3.70%	3.20%
Tax Reform Excess ADIT Reversal		(2.00%)	(18.70%)
Remeasurement of Excess ADIT		(263.30%)
Production and Investment Tax Credits		(49.60%)	(55.70%)
Flow Through		0.20%	0.30%
AFUDC Equity		(1.30%)	(1.40%)
Discrete Tax Adjustments		0.90%	0%
Other		1.20%	(2.00%)
Effective Income Tax Rate		(289.20%)	(53.30%)
Income Taxes (Textuals) [Abstract]
Tax Benefit Recognized from the Reduction in Excess ADIT Resulting from IRS PLR Received		$ 49
Southwestern Electric Power Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate		21%	21%
State Income Tax, net of Federal Benefit		1.70%	(0.40%)
Tax Reform Excess ADIT Reversal		4.60%	(3.80%)
Remeasurement of Excess ADIT		(224.70%)
Production and Investment Tax Credits		(23.80%)	(26.40%)
Flow Through		0.60%	0.50%
AFUDC Equity		(1.30%)	(0.80%)
Discrete Tax Adjustments		1.30%	0%
Other		(0.80%)	(0.80%)
Effective Income Tax Rate		(221.40%)	(10.70%)
Income Taxes (Textuals) [Abstract]
Tax Benefit Recognized from the Reduction in Excess ADIT Resulting from IRS PLR Received		$ 114

Financing Activities (Details)

Financing Activities (Details) - USD ($)			3 Months Ended
Financing Activities (Details) - USD ($)		Apr. 30, 2024	Mar. 31, 2024		Mar. 31, 2023		Dec. 31, 2023
Long-term Debt
Senior Unsecured Notes			$ 34,606,100,000				$ 33,779,400,000
Pollution Control Bonds			1,771,000,000				1,771,600,000
Notes Payable			163,500,000				193,300,000
Securitization Bonds			343,800,000				368,900,000
Spent Nuclear Fuel Obligation	[1]		304,400,000				300,400,000
Junior Subordinated Notes			1,588,200,000				2,388,100,000
Other Long-term Debt			1,058,900,000				1,341,500,000
Total Long-term Debt Outstanding			39,835,900,000				40,143,200,000
Long-term Debt Due Within One Year			1,198,600,000				2,490,500,000
Long-term Debt			38,637,300,000				37,652,700,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[2]		868,000,000
Repayments of Long-term Debt			1,162,200,000		$ 519,500,000
Short-term Debt:
Securitized Debt for Receivables	[3]		900,000,000				888,000,000
Commercial Paper			2,832,200,000				1,937,900,000
Total Short-term Debt			$ 3,737,600,000				$ 2,830,200,000
Securitized Debt for Receivables	[3],[4]		5.54%				5.65%
Comparative Accounts Receivable Information
Effective Interest Rates on Securitization of Accounts Receivable			5.61%		4.86%
Net Uncollectible Accounts Receivable Written Off			$ 8,100,000		$ 6,900,000
Customer Accounts Receivable Managed Portfolio
Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts			1,164,200,000				$ 1,207,400,000
Total Principal Outstanding			900,000,000				888,000,000
Delinquent Securitized Accounts Receivable			58,200,000				52,200,000
Bad Debt Reserves Related to Securitization, Sale of Accounts Receivable			42,600,000				42,000,000
Unbilled Receivables Related to Securitization, Sale of Accounts Receivable			336,900,000				$ 409,800,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			5,025,700,000		4,690,900,000
Financing Activities (Textuals)
Maximum Value of Shares to be Issued Under ATM Program			$ 1,700,000,000
Maximum Percentage Paid to Selling Agents			2%
Issuance of Common Stock			$ 40,600,000		41,100,000
Maximum Percentage Debt to Capitalization			67.50%
Total Commitment from Bank Conduits to Finance Receivables			$ 900,000,000
Forward Equity Purchase Contract Included in Current and Noncurrent Liabilities as of September 30,			14,800,000		12,500,000
Issuance of Long-term Debt			859,900,000		2,847,300,000
Related Party
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			0		0
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
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	[5]		(526,000,000)		(443,700,000)
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			46,700,000		41,500,000
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			7,000,000		8,900,000
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			47,600,000		100,000
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]		37,900,000		27,800,000
Wholesale Transmission [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			368,800,000	[7]	327,200,000	[8]
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			(418,600,000)	[7]	(401,800,000)	[8]
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			488,700,000	[7]	450,100,000	[8]
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			387,000,000		357,000,000
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			118,900,000	[7]	114,700,000	[8]
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			179,800,000	[7]	164,200,000	[8]
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]
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]
Other Revenues [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			111,800,000	[9]	65,300,000	[10]
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			(68,700,000)	[9]	(43,700,000)	[10]
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			8,100,000	[9]	3,600,000	[10]
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			48,000,000		29,000,000
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			59,700,000	[9]	32,600,000	[10]
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			51,000,000	[9]	42,800,000	[10]
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			1,300,000	[9]	600,000	[10]
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			60,400,000	[9]	29,400,000	[10]
Wholesale Generation [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			263,400,000		215,200,000
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		0
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
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			235,900,000		182,800,000
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
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			27,400,000		32,400,000
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
Residential [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			1,916,100,000		1,827,200,000
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
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
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			1,212,300,000		1,170,400,000
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			703,800,000		656,800,000
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
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
Commercial [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			1,042,100,000		1,009,300,000
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
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
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			645,100,000		633,400,000
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			397,000,000		375,900,000
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
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
Industrial [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			783,000,000	[11]	883,000,000
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			(200,000)	[11]	(200,000)
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	[11]	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			647,100,000	[11]	670,300,000
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			136,100,000	[11]	212,900,000
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	[11]	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	[11]	0
Other Retail [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			69,200,000		68,900,000
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
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
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			55,300,000		56,800,000
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			13,900,000		12,100,000
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
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
Retail [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			3,810,400,000		3,788,400,000
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			(200,000)		(200,000)
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
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			2,559,800,000		2,530,900,000
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			1,250,800,000		1,257,700,000
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
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
Renewable Generation [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			4,900,000	[11]	21,200,000	[12]
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			(1,400,000)	[11]	(100,000)	[12]
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	[11]	0	[12]
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	[11]	0	[12]
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	[11]	0	[12]
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			6,300,000	[11]	21,300,000	[12]
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	[11]	0	[12]
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			525,700,000	[13]	413,500,000	[12]
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			(46,200,000)	[13]	100,000	[12]
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	[13]	0	[12]
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	[13]	0	[12]
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	[13]	0	[12]
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			571,400,000	[13]	413,700,000	[12]
Retail, Trading and Marketing Revenues [Member] \| 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			46,000,000
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			500,000	[13]	(300,000)	[12]
Wholesale and Competitive [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			1,162,800,000		977,100,000
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			(466,100,000)		(401,800,000)
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			488,700,000		450,100,000
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			354,800,000		297,500,000
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			179,800,000		164,200,000
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			605,100,000		467,400,000
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			500,000		(300,000)
Affiliated and Nonaffiliated [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			5,085,000,000		4,830,800,000
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			(535,000,000)		(445,700,000)
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			496,800,000		453,700,000
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			2,974,300,000		2,861,000,000
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			1,481,600,000		1,464,700,000
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			606,400,000		468,000,000
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			60,900,000		29,100,000
Other Revenues [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			125,400,000		92,400,000
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]		14,900,000		2,300,000
Junior Subordinated Notes
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 805,000,000
Due Date			2024
Interest Rate (Percentage)			2.03%
Commercial Paper [Member]
Short-term Debt:
Weighted Average Interest Rate	[4]		5.61%				5.69%
AEP Texas Inc. [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 5,878,700,000				$ 5,889,800,000
Long-term Debt Due Within One Year			96,200,000				96,000,000
Long-term Debt			5,782,500,000				5,793,800,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 11,900,000		136,700,000
Financing Activities (Textuals)
Maximum Percentage Debt to Capitalization			67.50%
AEP Texas Inc. [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool			$ 267,900,000				103,700,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			1,300,000		1,200,000
Financing Activities (Textuals)
Net Loans To Money Pool			7,000,000				7,100,000
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			155,900,000	[14]	146,300,000	[15]
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			8,800,000	[16]	9,700,000	[17]
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	[18]	0	[19]
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			147,300,000		130,700,000
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			110,900,000		97,300,000
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			35,600,000	[20]	39,300,000
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			9,700,000		8,300,000
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			303,500,000		275,600,000
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			155,900,000		146,300,000
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			468,200,000		431,600,000
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			$ 2,100,000		$ 600,000
AEP Texas Inc. [Member] \| Utility [Member]
Maximum Interest Rate			5.79%		5.42%
Minimum Interest Rate			5.66%		4.66%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool			$ 267,900,000
Maximum Loans to Money Pool			0
Average Borrowings from Money Pool			191,200,000
Average Loans to Money Pool			0
Authorized Short Term Borrowing Limit			$ 600,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed			5.71%		5.18%
Average Interest Rate For Funds Loaned			0%		0%
AEP Texas Inc. [Member] \| Utility [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool			$ (267,900,000)
AEP Texas Inc. [Member] \| Nonutility [Member]
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Loans to Money Pool			7,100,000
Average Loans to Money Pool			$ 7,000,000
Maximum and Minimum Interest Rates
Maximum Interest Rate For Funds Loaned			5.79%		5.42%
Minimum Interest Rate for Funds Loaned			5.66%		4.66%
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Loaned			5.72%		5.12%
AEP Texas Inc. [Member] \| Nonutility [Member] \| Related Party
Financing Activities (Textuals)
Net Loans To Money Pool			$ 7,000,000
AEP Texas Inc. [Member] \| Securitization Bonds [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 11,900,000
Due Date			2025
Interest Rate (Percentage)			2.06%
AEP Transmission Co [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 5,860,700,000				5,414,400,000
Long-term Debt Due Within One Year			145,000,000				95,000,000
Long-term Debt			5,715,700,000				5,319,400,000
Financing Activities (Textuals)
Sub-Limit of Secured Debt			$ 50,000,000
Maximum Percentage of Consolidated Tangible Net Assets			10%
Tangible Capital to Tangible Assets			0.20%
Maximum Percentage Debt to Capitalization			67.50%
Issuance of Long-term Debt			$ 446,100,000		$ 689,200,000
AEP Transmission Co [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool			28,800,000				174,300,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			389,400,000		357,400,000
Financing Activities (Textuals)
Net Loans To Money Pool			298,000,000				67,100,000
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
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
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			475,400,000	[14]	438,700,000	[15]
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			384,000,000		349,000,000
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			8,100,000	[16]	3,700,000	[17]
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	[18]	0	[19]
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
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
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	[20]	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
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
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			475,400,000		438,700,000
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			483,500,000		442,400,000
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			2,400,000		$ 0
AEP Transmission Co [Member] \| 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			$ 0
AEP Transmission Co [Member] \| Utility [Member]
Maximum Interest Rate			5.79%		5.42%
Minimum Interest Rate			5.66%		4.66%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool			$ 313,300,000
Maximum Loans to Money Pool			298,000,000
Average Borrowings from Money Pool			178,500,000
Average Loans to Money Pool			75,300,000
Authorized Short Term Borrowing Limit	[21]		$ 820,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed			5.72%		5.09%
Average Interest Rate For Funds Loaned			5.70%		5.29%
AEP Transmission Co [Member] \| Utility [Member] \| Related Party
Financing Activities (Textuals)
Net Loans To Money Pool			$ 272,900,000
AEP Transmission Co [Member] \| Direct Borrowing [Member]
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool			44,400,000
Maximum Loans to Money Pool			148,500,000
Average Borrowings from Money Pool			4,400,000
Average Loans to Money Pool			72,900,000
Borrowings from Parent			3,700,000
Loans to Parent			0
Authorized Short Term Borrowing Limit	[22]		$ 50,000,000
Maximum and Minimum Interest Rates
Maximum Interest Rate for Funds Borrowed			5.79%		5.38%
Minimum Interest Rate For Funds Borrowed			5.66%		4.53%
Maximum Interest Rate For Funds Loaned			5.79%		5.38%
Minimum Interest Rate for Funds Loaned			5.66%		4.53%
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed			5.74%		5.03%
Average Interest Rate For Funds Loaned			5.71%		5.15%
AEP Transmission Co [Member] \| Senior Unsecured Notes [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[2]		$ 450,000,000
Due Date			2034
Interest Rate (Percentage)			5.15%
Appalachian Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 5,670,900,000				5,588,300,000
Long-term Debt Due Within One Year			153,300,000				538,800,000
Long-term Debt			5,517,600,000				5,049,500,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			313,400,000		$ 13,000,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues			196,500,000				184,600,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit			$ 536,000,000		506,200,000
Financing Activities (Textuals)
Maximum Percentage Debt to Capitalization			67.50%
Issuance of Long-term Debt			$ 395,800,000		0
Appalachian Power Co [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool			0				339,600,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			63,100,000		69,600,000
Financing Activities (Textuals)
Net Loans To Money Pool			37,400,000				18,900,000
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			47,100,000	[14]	41,400,000	[15]
Appalachian Power 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			21,000,000
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			21,700,000	[16]	13,000,000	[17]
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			85,100,000	[18]	80,200,000	[19]
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			41,000,000		47,000,000
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			526,300,000		470,500,000
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			188,300,000		171,300,000
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			196,400,000	[20]	185,800,000
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			28,100,000		26,200,000
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			939,100,000		853,800,000
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			132,200,000		121,600,000
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			1,093,000,000		988,400,000
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			5,600,000		3,600,000
Appalachian Power Co [Member] \| Other Long Term Debt Two [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 300,000,000
Due Date			2024
Interest Rate (Variable)			Variable
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			$ 4,200,000		$ 4,900,000
Appalachian Power Co [Member] \| Utility [Member]
Maximum Interest Rate			5.79%		5.42%
Minimum Interest Rate			5.66%		4.66%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool			$ 399,500,000
Maximum Loans to Money Pool			51,100,000
Average Borrowings from Money Pool			205,500,000
Average Loans to Money Pool			20,300,000
Authorized Short Term Borrowing Limit			$ 750,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed			5.74%		5.14%
Average Interest Rate For Funds Loaned			5.72%		5.12%
Appalachian Power Co [Member] \| Utility [Member] \| Related Party
Financing Activities (Textuals)
Net Loans To Money Pool			$ 37,400,000
Appalachian Power Co [Member] \| Pollution Control Bond [Member] \| Subsequent Event [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt		$ 86,000,000
Appalachian Power Co [Member] \| Securitization Bonds Two [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 13,400,000
Due Date			2028
Interest Rate (Percentage)			3.77%
Appalachian Power Co [Member] \| Senior Unsecured Notes Two [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[2]		$ 400,000,000
Due Date			2034
Interest Rate (Percentage)			5.65%
Indiana Michigan Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 3,478,500,000				3,499,400,000
Long-term Debt Due Within One Year			76,900,000				83,700,000
Long-term Debt			3,401,600,000				3,415,700,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			25,400,000		$ 274,300,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues			167,000,000				156,400,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit			529,700,000		525,400,000
Financing Activities (Textuals)
Trust Fund Assets One Time Fee Obligation for Nuclear Fuel Disposition			$ 355,000,000				348,000,000
Maximum Percentage Debt to Capitalization			67.50%
Issuance of Long-term Debt			$ 0		499,800,000
Indiana Michigan Power Co [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool			73,200,000				63,300,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			1,800,000		1,200,000
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			10,100,000	[14]	8,100,000	[15]
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			27,600,000	[16]	21,400,000	[17]
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			18,000,000		18,000,000
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			137,300,000	[18]	104,000,000	[19]
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			224,800,000		239,600,000
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			144,800,000		138,900,000
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			147,900,000	[20]	152,600,000
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			1,300,000		1,300,000
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			518,800,000		532,400,000
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			147,400,000		112,100,000
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			693,800,000		665,900,000
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			2,800,000		3,100,000
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			15,000,000		15,900,000
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			$ 4,100,000		$ 3,900,000
Indiana Michigan Power Co [Member] \| Utility [Member]
Maximum Interest Rate			5.79%		5.42%
Minimum Interest Rate			5.66%		4.66%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool			$ 125,500,000
Maximum Loans to Money Pool			0
Average Borrowings from Money Pool			60,200,000
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			5.73%		5.12%
Average Interest Rate For Funds Loaned			0%		5.16%
Indiana Michigan Power Co [Member] \| Utility [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool			$ (73,200,000)
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			$ 5,000,000
Due Date			2026
Interest Rate (Percentage)			3.44%
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			$ 6,800,000
Due Date			2027
Interest Rate (Percentage)			5.93%
Indiana Michigan Power Co [Member] \| Notes Payable, Other Payable Six [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 6,800,000
Due Date			2028
Interest Rate (Percentage)			6.01%
Indiana Michigan Power Co [Member] \| OtherLongTermDebtThree
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 700,000
Due Date			2025
Interest Rate (Percentage)			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
Proceeds from Issuance of Debt		80,000,000
Repayments of Long-term Debt		$ 8,000,000
Due Date		2028
Interest Rate (Percentage)		6.41%
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			2024
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			$ 900,000
Due Date			2025
Interest Rate (Variable)			Variable
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			$ 4,000,000
Due Date			2025
Interest Rate (Percentage)			0.93%
Ohio Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 3,367,400,000				3,366,800,000
Long-term Debt			3,367,400,000				3,366,800,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues			536,000,000				541,700,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit			845,700,000		$ 884,400,000
Ohio Power Co [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool			295,200,000				110,500,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			5,700,000		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			23,800,000	[14]	17,900,000	[15]
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			42,200,000	[16]	33,200,000	[17]
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	[18]	0	[19]
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			556,500,000		526,000,000
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			286,100,000		278,500,000
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			100,500,000	[20]	173,600,000
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			4,200,000		3,800,000
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			947,300,000		981,900,000
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			23,800,000		17,900,000
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			1,013,300,000		1,033,000,000
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			2,700,000		5,200,000
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			$ 7,400,000		$ 7,300,000
Ohio Power Co [Member] \| Utility [Member]
Maximum Interest Rate			5.79%		5.42%
Minimum Interest Rate			5.66%		4.66%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool			$ 295,200,000
Maximum Loans to Money Pool			0
Average Borrowings from Money Pool			143,400,000
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			5.71%		5.17%
Average Interest Rate For Funds Loaned			0%		0%
Ohio Power Co [Member] \| Utility [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool			$ (295,200,000)
Public Service Co Of Oklahoma [Member]
Long-term Debt
Total Long-term Debt Outstanding			2,384,900,000				2,384,600,000
Long-term Debt Due Within One Year			125,600,000				600,000
Long-term Debt			2,259,300,000				2,384,000,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			100,000		$ 100,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues			96,300,000				134,600,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit			$ 361,600,000		416,300,000
Financing Activities (Textuals)
Maximum Percentage Debt to Capitalization			67.50%
Issuance of Long-term Debt			$ 0		469,900,000
Public Service Co Of Oklahoma [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool			264,600,000				54,400,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			3,500,000		700,000
Public Service Co Of Oklahoma [Member] \| Wholesale Transmission [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			10,800,000	[14]	11,300,000	[15]
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			12,000,000	[16]	2,300,000	[17]
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			2,200,000	[18]	900,000	[19]
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			158,200,000		170,900,000
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			103,000,000		109,100,000
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			80,300,000	[20]	98,300,000
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			21,500,000		24,200,000
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			363,000,000		402,500,000
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			13,000,000		12,200,000
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			388,000,000		417,000,000
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			6,200,000		1,500,000
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			$ 3,400,000		$ 3,200,000
Public Service Co Of Oklahoma [Member] \| Utility [Member]
Maximum Interest Rate			5.79%		5.42%
Minimum Interest Rate			5.66%		4.66%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool			$ 264,600,000
Maximum Loans to Money Pool			0
Average Borrowings from Money Pool			128,800,000
Average Loans to Money Pool			0
Authorized Short Term Borrowing Limit			$ 750,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed			5.71%		4.84%
Average Interest Rate For Funds Loaned			0%		5.11%
Public Service Co Of Oklahoma [Member] \| Utility [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool			$ (264,600,000)
Public Service Co Of Oklahoma [Member] \| OtherLongTermDebtFour
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 100,000
Due Date			2027
Interest Rate (Percentage)			3%
Southwestern Electric Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 3,647,600,000				3,646,900,000
Long-term Debt			3,647,600,000				3,646,900,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			0		$ 94,100,000
Short-term Debt:
Notes Payable			5,400,000				4,300,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues			144,200,000				168,300,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit			$ 425,400,000		437,600,000
Financing Activities (Textuals)
Maximum Percentage Debt to Capitalization			67.50%
Issuance of Long-term Debt			$ 0		347,300,000
Southwestern Electric Power Co [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool			254,500,000				88,700,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			12,100,000		11,700,000
Financing Activities (Textuals)
Net Loans To Money Pool			2,300,000				$ 2,200,000
Southwestern Electric Power Co [Member] \| Wholesale Transmission [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			39,600,000	[14]	42,900,000	[15]
Southwestern Electric Power 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			14,000,000
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			9,600,000	[16]	7,900,000	[17]
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			47,100,000	[18]	39,600,000	[19]
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			182,400,000		175,900,000
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			140,000,000		143,500,000
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			95,000,000	[20]	104,200,000
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		2,600,000
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			420,000,000		426,200,000
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			86,700,000		82,500,000
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			516,300,000		516,600,000
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			3,900,000		500,000
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			$ 4,800,000		$ 4,300,000
Southwestern Electric Power Co [Member] \| Utility [Member]
Maximum Interest Rate			5.79%		5.42%
Minimum Interest Rate			5.66%		4.66%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool			$ 254,500,000
Maximum Loans to Money Pool			0
Average Borrowings from Money Pool			161,100,000
Average Loans to Money Pool			0
Authorized Short Term Borrowing Limit			$ 750,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed			5.71%		5.12%
Average Interest Rate For Funds Loaned			0%		0%
Southwestern Electric Power Co [Member] \| Utility [Member] \| Related Party
Short-term Debt:
Net Borrowings from Money Pool			$ (254,500,000)
Southwestern Electric Power Co [Member] \| Nonutility [Member]
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Loans to Money Pool			2,300,000
Average Loans to Money Pool			$ 2,200,000
Maximum and Minimum Interest Rates
Maximum Interest Rate For Funds Loaned			5.79%		5.42%
Minimum Interest Rate for Funds Loaned			5.66%		4.66%
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Loaned			5.72%		5.13%
Southwestern Electric Power Co [Member] \| Nonutility [Member] \| Related Party
Financing Activities (Textuals)
Net Loans To Money Pool			$ 2,300,000
Southwestern Electric Power Co [Member] \| Loans Payable [Member]
Short-term Debt:
Weighted Average Interest Rate	[4]		7.68%				7.71%
Transource Energy [Member] \| Other Long Term Debt [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[2]		$ 18,000,000
Due Date			2025
Interest Rate (Variable)			Variable
Transource Energy [Member] \| Senior Unsecured Notes Three
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 1,400,000
Due Date			2050
Interest Rate (Percentage)			2.75%
Wheeling Power Company \| Notes Payable, Other Payable Eight [Member] \| Subsequent Event [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt		$ 450,000,000
Due Date		2034
Interest Rate (Percentage)		6.89%
Wheeling Power Company \| Other Long Term Debt Five \| Subsequent Event [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt		$ 265,000,000
AEP Generating Company \| Notes Payable, Other Payable Seven [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 5,000,000
Due Date			2028
Interest Rate (Percentage)			2.43%
Additional Paid-in Capital [Member]
Financing Activities (Textuals)
Forward Equity Purchase Contract Included in Current and Noncurrent Liabilities as of September 30,			$ 14,800,000		$ 12,700,000

[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 $355 million and $348 million as of March 31, 2024 and December 31, 2023, respectively, and are included in Spent Nuclear Fuel and Decommissioning Trusts on the balance sheets. 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. Amount of securitized debt for receivables as accounted for under the “Transfers and Servicing” accounting guidance. Weighted-average rate as of March 31, 2024 and December 31, 2023, respectively. Represents inter-segment revenues. 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. Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $387 million. The remaining affiliated amounts were immaterial. Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $357 million. The remaining affiliated amounts were immaterial. Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $48 million. The remaining affiliated amounts were immaterial. Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $29 million. The remaining affiliated amounts were immaterial. Amounts include affiliated and nonaffiliated revenues. Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $46 million. The remaining affiliated amounts were immaterial. Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $384 million, APCo was $21 million and SWEPCo was $14 million. The remaining affiliated amounts were immaterial. Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $349 million. The remaining affiliated amounts were immaterial. Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $18 million primarily related to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $18 million primarily related to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $41 million primarily related to the PPA with KGPCo. Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $47 million primarily related to the PPA with KGPCo. Amounts include affiliated and nonaffiliated revenues. (a) Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions. (a) Amount represents the authorized short-term borrowing limit from FERC or state regulatory agencies not otherwise included in the utility money pool above.

Variable Interest Entities (Det

Variable Interest Entities (Details) - USD ($) $ in Millions	Mar. 31, 2024		Dec. 31, 2023		Mar. 31, 2023	Dec. 31, 2022
ASSETS
Current Assets	$ 5,849.6		$ 6,082.1
Net Property, Plant and Equipment	77,796		76,693.4
Other Noncurrent Assets	14,099		13,908.5
Total Assets	97,744.6		96,684
LIABILITIES AND EQUITY
Current Liabilities	10,906.6		11,583.6
Noncurrent Liabilities	60,942.7		59,772
Equity	25,843.7		25,285.9		$ 23,967.8	$ 24,122.4
Total Liabilities and Equity	97,744.6		96,684
Southwestern Electric Power Co [Member]
ASSETS
Current Assets	548.1		541.3
Net Property, Plant and Equipment	8,666.7		8,558.4
Other Noncurrent Assets	1,533.2		1,457.9
Total Assets	10,748		10,557.6
LIABILITIES AND EQUITY
Current Liabilities	851.3		686.9
Noncurrent Liabilities	5,968.3		6,100.3
Equity	3,928.4		3,770.4		3,765.2	3,674.8
Total Liabilities and Equity	10,748		10,557.6
Indiana Michigan Power Co [Member]
ASSETS
Current Assets	480		528
Net Property, Plant and Equipment	7,651.2		7,629
Other Noncurrent Assets	4,980.3		4,651
Total Assets	13,111.5		12,808
LIABILITIES AND EQUITY
Current Liabilities	783.3		830.2
Noncurrent Liabilities	9,080.4		8,837.6
Equity	3,247.8		3,140.2		3,077.3	3,008.3
Total Liabilities and Equity	13,111.5		12,808
AEP Texas Inc. [Member]
ASSETS
Current Assets	525.1		520.1
Net Property, Plant and Equipment	13,079.4		12,774
Other Noncurrent Assets	763		696.6
Total Assets	14,367.5		13,990.7
LIABILITIES AND EQUITY
Current Liabilities	1,041.9		749.4
Noncurrent Liabilities	8,445.9		8,445.2
Equity	4,879.7		4,796.1		4,051.3	3,904.3
Total Liabilities and Equity	14,367.5		13,990.7
Appalachian Power Co [Member]
ASSETS
Current Assets	1,019.8		1,059
Net Property, Plant and Equipment	13,052.9		12,931.5
Other Noncurrent Assets	1,679.7		1,721.4
Total Assets	15,752.4		15,711.9
LIABILITIES AND EQUITY
Current Liabilities	1,023.3		1,685.9
Noncurrent Liabilities	9,216.4		8,749.3
Equity	5,512.7		5,276.7		$ 5,086.9	$ 4,975.4
Total Liabilities and Equity	15,752.4		15,711.9
Sabine Mining Co [Member] \| Variable Interest Entities [Member] \| Southwestern Electric Power Co [Member]
ASSETS
Current Assets	5.1		4.2
Net Property, Plant and Equipment	0		0
Other Noncurrent Assets	140.1		150.7
Total Assets	145.2		154.9
LIABILITIES AND EQUITY
Current Liabilities	22.8		19.9
Noncurrent Liabilities	122.1		134.8
Equity	0.3		0.2
Total Liabilities and Equity	145.2		154.9
DCC Fuel [Member] \| Variable Interest Entities [Member] \| Indiana Michigan Power Co [Member]
ASSETS
Current Assets	75.3		81.9
Net Property, Plant and Equipment	129.5		153.8
Other Noncurrent Assets	63.5		81.7
Total Assets	268.3		317.4
LIABILITIES AND EQUITY
Current Liabilities	75.1		81.7
Noncurrent Liabilities	193.2		235.7
Equity	0		0
Total Liabilities and Equity	268.3		317.4
AEP Texas Central Transition Funding Co [Member] \| AEP Texas Inc. [Member] \| Other Noncurrent Assets [Member]
LIABILITIES AND EQUITY
Unearned Revenue	6		8
AEP Texas Central Transition Funding Co [Member] \| Variable Interest Entities [Member] \| AEP Texas Inc. [Member]
ASSETS
Current Assets	40.1		25.5
Net Property, Plant and Equipment	0		0
Other Noncurrent Assets	55.3	[1]	71.4	[2]
Total Assets	95.4		96.9
LIABILITIES AND EQUITY
Current Liabilities	76.3		75.5
Noncurrent Liabilities	14.7		17
Equity	4.4		4.4
Total Liabilities and Equity	95.4		96.9
Restoration Funding [Member] \| AEP Texas Inc. [Member] \| Other Noncurrent Assets [Member]
LIABILITIES AND EQUITY
Unearned Revenue	6		6
Restoration Funding [Member] \| Variable Interest Entities [Member] \| AEP Texas Inc. [Member]
ASSETS
Current Assets	20.4		27.5
Net Property, Plant and Equipment	0		0
Other Noncurrent Assets	139.7	[3]	145.6	[4]
Total Assets	160.1		173.1
LIABILITIES AND EQUITY
Current Liabilities	36.4		36.8
Noncurrent Liabilities	122.4		135.1
Equity	1.3		1.2
Total Liabilities and Equity	160.1		173.1
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	6.3		13.3
Net Property, Plant and Equipment	0		0
Other Noncurrent Assets	130.3	[5]	138.2	[6]
Total Assets	136.6		151.5
LIABILITIES AND EQUITY
Current Liabilities	29		29.9
Noncurrent Liabilities	105.7		119.7
Equity	1.9		1.9
Total Liabilities and Equity	136.6		151.5
AEP Credit, Inc. [Member] \| Variable Interest Entities [Member]
ASSETS
Current Assets	1,165.3		1,208.8
Net Property, Plant and Equipment	0		0
Other Noncurrent Assets	10.2		9.6
Total Assets	1,175.5		1,218.4
LIABILITIES AND EQUITY
Current Liabilities	1,113.7		1,155
Noncurrent Liabilities	1		0.9
Equity	60.8		62.5
Total Liabilities and Equity	1,175.5		1,218.4
Protected Cell Of Energy Insurance Services, Inc. [Member] \| Variable Interest Entities [Member]
ASSETS
Current Assets	211.6		205.3
Net Property, Plant and Equipment	0		0
Other Noncurrent Assets	0		0
Total Assets	211.6		205.3
LIABILITIES AND EQUITY
Current Liabilities	52.3		49.2
Noncurrent Liabilities	90.8		91.7
Equity	68.5		64.4
Total Liabilities and Equity	211.6		205.3
Transource Energy [Member] \| Variable Interest Entities [Member]
ASSETS
Current Assets	31.7		36.9
Net Property, Plant and Equipment	536.9		533.4
Other Noncurrent Assets	9.3		5.1
Total Assets	577.9		575.4
LIABILITIES AND EQUITY
Current Liabilities	22.5		45.3
Noncurrent Liabilities	258.8		241.5
Equity	296.6		288.6
Total Liabilities and Equity	$ 577.9		$ 575.4

[1]Includes an intercompany item eliminated in consolidation of $6 million.[2] Includes an intercompany item eliminated in consolidation of $8 million . Includes an intercompany item eliminated in consolidation of $6 million. Includes an intercompany item eliminated in consolidation of $6 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
		Mar. 31, 2024		Mar. 31, 2023		Dec. 31, 2023
Disaggregation of Revenue
Revenue from Contracts with Customers		$ 5,025.7		$ 4,690.9
Revenues		5,025.7		4,690.9
Revenue, Performance Obligation
Fixed Performance Obligations		337.9
Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		3,810.4		3,788.4
Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,916.1		1,827.2
Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,042.1		1,009.3
Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		783	[1]	883
Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		69.2		68.9
Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,162.8		977.1
Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		263.4		215.2
Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		368.8	[2]	327.2	[3]
Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		4.9	[1]	21.2	[4]
Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		525.7	[5]	413.5	[4]
Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		111.8	[6]	65.3	[7]
Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		5,085		4,830.8
Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(59.3)		(139.9)
Alternative [Member]
Disaggregation of Revenue
Revenues		1.5	[8]	(10)	[9]
Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		125.4		92.4
Revenues		(60.8)	[1],[10]	(129.9)	[4],[11]
2024 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		62.3
2025-2026[Member]
Revenue, Performance Obligation
Fixed Performance Obligations		166.8
2027-2028 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		84.1
After 2028
Revenue, Performance Obligation
Fixed Performance Obligations		24.7
AEP Texas Inc. [Member]
Disaggregation of Revenue
Revenues		466.4		429.5
AEP Texas Inc. [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		1.3		1.2
Revenue Textuals
Affiliated Companies - Contracts with Customers		21.2				$ 23.8
AEP Texas Inc. [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		303.5		275.6
AEP Texas Inc. [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		147.3		130.7
AEP Texas Inc. [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		110.9		97.3
AEP Texas Inc. [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		35.6	[12]	39.3
AEP Texas Inc. [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		9.7		8.3
AEP Texas Inc. [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		155.9		146.3
AEP Texas Inc. [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[13]	0	[14]
AEP Texas Inc. [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		155.9	[15]	146.3	[16]
AEP Texas Inc. [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		8.8	[17]	9.7	[18]
AEP Texas Inc. [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		468.2		431.6
AEP Texas Inc. [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(1.8)		(2.1)
AEP Texas Inc. [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		(1.8)	[19]	(2.1)	[20]
AEP Texas Inc. [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2.1		0.6
Revenues		0	[12]	0	[21]
AEP Texas Inc. [Member] \| Short-term Contract with Customer [Member] \| Related Party
Revenue Textuals
Affiliated Companies - Contracts with Customers		0				0
AEP Transmission Co [Member]
Disaggregation of Revenue
Revenues		482.8		441.6
AEP Transmission Co [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		389.4		357.4
Revenue Textuals
Affiliated Companies - Contracts with Customers		131.1				125.5
AEP Transmission Co [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
AEP Transmission Co [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
AEP Transmission Co [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
AEP Transmission Co [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[12]	0
AEP Transmission Co [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
AEP Transmission Co [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		475.4		438.7
AEP Transmission Co [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[13]	0	[14]
AEP Transmission Co [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		475.4	[15]	438.7	[16]
AEP Transmission Co [Member] \| Wholesale Transmission [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		384		349
AEP Transmission Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		8.1	[17]	3.7	[18]
AEP Transmission Co [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		483.5		442.4
AEP Transmission Co [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(0.7)		(0.8)
AEP Transmission Co [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		(0.7)	[19]	(0.8)	[20]
AEP Transmission Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2.4		0
Revenues		0	[12]	0	[21]
AEP Transmission Co [Member] \| Short-term Contract with Customer [Member] \| Related Party
Revenue Textuals
Affiliated Companies - Contracts with Customers		129.2				123.2
Appalachian Power Co [Member]
Disaggregation of Revenue
Revenues		1,093		987.7
Revenue, Performance Obligation
Fixed Performance Obligations		80.3
Appalachian Power Co [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		63.1		69.6
Revenue Textuals
Affiliated Companies - Contracts with Customers		100.9				98.8
Appalachian Power Co [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		939.1		853.8
Appalachian Power Co [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		526.3		470.5
Appalachian Power Co [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		188.3		171.3
Appalachian Power Co [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		196.4	[12]	185.8
Appalachian Power Co [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		28.1		26.2
Appalachian Power Co [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		132.2		121.6
Appalachian Power Co [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		85.1	[13]	80.2	[14]
Appalachian Power Co [Member] \| Wholesale Generation [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		41		47
Appalachian Power Co [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		47.1	[15]	41.4	[16]
Appalachian Power Co [Member] \| Wholesale Transmission [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		21
Appalachian Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		21.7	[17]	13	[18]
Appalachian Power Co [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,093		988.4
Appalachian Power Co [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		0		(0.7)
Appalachian Power Co [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		(0.1)	[19]	(0.7)	[20]
Appalachian Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		5.6		3.6
Revenues		0.1	[12]	0	[21]
Appalachian Power Co [Member] \| Short-term Contract with Customer [Member] \| Related Party
Revenue Textuals
Affiliated Companies - Contracts with Customers		77.8				71.7
Appalachian Power Co [Member] \| 2024 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		12.1
Appalachian Power Co [Member] \| 2025-2026[Member]
Revenue, Performance Obligation
Fixed Performance Obligations		32.2
Appalachian Power Co [Member] \| 2027-2028 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		24.3
Appalachian Power Co [Member] \| After 2028
Revenue, Performance Obligation
Fixed Performance Obligations		11.7
Indiana Michigan Power Co [Member]
Disaggregation of Revenue
Revenues		667.4		663
Revenue, Performance Obligation
Fixed Performance Obligations		25.4
Indiana Michigan Power Co [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		1.8		1.2
Revenue Textuals
Affiliated Companies - Contracts with Customers		87.4				65
Indiana Michigan Power Co [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		518.8		532.4
Indiana Michigan Power Co [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		224.8		239.6
Indiana Michigan Power Co [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		144.8		138.9
Indiana Michigan Power Co [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		147.9	[12]	152.6
Indiana Michigan Power Co [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1.3		1.3
Indiana Michigan Power Co [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		147.4		112.1
Indiana Michigan Power Co [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		137.3	[13]	104	[14]
Indiana Michigan Power Co [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		10.1	[15]	8.1	[16]
Indiana Michigan Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		27.6	[17]	21.4	[18]
Indiana Michigan Power Co [Member] \| Other Revenues [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		18		18
Indiana Michigan Power Co [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		693.8		665.9
Indiana Michigan Power Co [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(26.4)		(2.9)
Indiana Michigan Power Co [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		(0.5)	[19]	(2.9)	[20]
Indiana Michigan Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2.8		3.1
Revenues		(25.9)	[12]	0	[21]
Indiana Michigan Power Co [Member] \| Other Revenues [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		15		15.9
Indiana Michigan Power Co [Member] \| Short-term Contract with Customer [Member] \| Related Party
Revenue Textuals
Affiliated Companies - Contracts with Customers		55.8				44
Indiana Michigan Power Co [Member] \| 2024 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		3.3
Indiana Michigan Power Co [Member] \| 2025-2026[Member]
Revenue, Performance Obligation
Fixed Performance Obligations		8.8
Indiana Michigan Power Co [Member] \| 2027-2028 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		8.8
Indiana Michigan Power Co [Member] \| After 2028
Revenue, Performance Obligation
Fixed Performance Obligations		4.5
Ohio Power Co [Member]
Disaggregation of Revenue
Revenues		1,023.8		1,034.6
Ohio Power Co [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		5.7		7.6
Revenue Textuals
Affiliated Companies - Contracts with Customers		131.5				129.2
Ohio Power Co [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		947.3		981.9
Ohio Power Co [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		556.5		526
Ohio Power Co [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		286.1		278.5
Ohio Power Co [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		100.5	[12]	173.6
Ohio Power Co [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		4.2		3.8
Ohio Power Co [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		23.8		17.9
Ohio Power Co [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[13]	0	[14]
Ohio Power Co [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		23.8	[15]	17.9	[16]
Ohio Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		42.2	[17]	33.2	[18]
Ohio Power Co [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,013.3		1,033
Ohio Power Co [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		10.5		1.6
Ohio Power Co [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		2.6	[19]	(9.5)	[20]
Ohio Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2.7		5.2
Revenues		7.9	[12]	11.1	[21]
Ohio Power Co [Member] \| Short-term Contract with Customer [Member] \| Related Party
Revenue Textuals
Affiliated Companies - Contracts with Customers		72.3				70.1
Public Service Co Of Oklahoma [Member]
Disaggregation of Revenue
Revenues		387.8		417
Public Service Co Of Oklahoma [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		3.5		0.7
Revenue Textuals
Affiliated Companies - Contracts with Customers		69.1				31
Public Service Co Of Oklahoma [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		363		402.5
Public Service Co Of Oklahoma [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		158.2		170.9
Public Service Co Of Oklahoma [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		103		109.1
Public Service Co Of Oklahoma [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		80.3	[12]	98.3
Public Service Co Of Oklahoma [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		21.5		24.2
Public Service Co Of Oklahoma [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		13		12.2
Public Service Co Of Oklahoma [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2.2	[13]	0.9	[14]
Public Service Co Of Oklahoma [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		10.8	[15]	11.3	[16]
Public Service Co Of Oklahoma [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		12	[17]	2.3	[18]
Public Service Co Of Oklahoma [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		388		417
Public Service Co Of Oklahoma [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(0.2)		0
Public Service Co Of Oklahoma [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		(0.2)	[19]	0	[20]
Public Service Co Of Oklahoma [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		6.2		1.5
Revenues		0	[12]	0	[21]
Public Service Co Of Oklahoma [Member] \| Short-term Contract with Customer [Member] \| Related Party
Revenue Textuals
Affiliated Companies - Contracts with Customers		10.8				12.4
Southwestern Electric Power Co [Member]
Disaggregation of Revenue
Revenues		516.2		515.9
Southwestern Electric Power Co [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		12.1		11.7
Revenue Textuals
Affiliated Companies - Contracts with Customers		61.2				47.2
Southwestern Electric Power Co [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		420		426.2
Southwestern Electric Power Co [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		182.4		175.9
Southwestern Electric Power Co [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		140		143.5
Southwestern Electric Power Co [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		95	[12]	104.2
Southwestern Electric Power Co [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2.6		2.6
Southwestern Electric Power Co [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		86.7		82.5
Southwestern Electric Power Co [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		47.1	[13]	39.6	[14]
Southwestern Electric Power Co [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		39.6	[15]	42.9	[16]
Southwestern Electric Power Co [Member] \| Wholesale Transmission [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		14
Southwestern Electric Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		9.6	[17]	7.9	[18]
Southwestern Electric Power Co [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		516.3		516.6
Southwestern Electric Power Co [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(0.1)		(0.7)
Southwestern Electric Power Co [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		(0.1)	[19]	(0.7)	[20]
Southwestern Electric Power Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		3.9		0.5
Revenues		0	[12]	0	[21]
Southwestern Electric Power Co [Member] \| Short-term Contract with Customer [Member] \| Related Party
Revenue Textuals
Affiliated Companies - Contracts with Customers		16.1				$ 27.4
Consolidation Eliminations [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Revenues		(526)		(443.7)
Consolidation Eliminations [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers	[22]	(526)		(443.7)
Consolidation Eliminations [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(0.2)		(0.2)
Consolidation Eliminations [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Consolidation Eliminations [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Consolidation Eliminations [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(0.2)	[1]	(0.2)
Consolidation Eliminations [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Consolidation Eliminations [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(466.1)		(401.8)
Consolidation Eliminations [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0.1		0
Consolidation Eliminations [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(418.6)	[2]	(401.8)	[3]
Consolidation Eliminations [Member] \| Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(1.4)	[1]	(0.1)	[4]
Consolidation Eliminations [Member] \| Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(46.2)	[5]	0.1	[4]
Consolidation Eliminations [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(68.7)	[6]	(43.7)	[7]
Consolidation Eliminations [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(535)		(445.7)
Consolidation Eliminations [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		9		2
Consolidation Eliminations [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		1	[8]	2.9	[9]
Consolidation Eliminations [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenues		8	[1],[10]	(0.9)	[4],[11]
Consolidation Eliminations [Member] \| AEP Transmission Co [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Revenues		0		0
Consolidation Eliminations [Member] \| AEP Transmission Co [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Consolidation Eliminations [Member] \| AEP Transmission Co [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0
Vertically Integrated Utilities [Member]
Disaggregation of Revenue
Revenues		2,947.9		2,857.8
Vertically Integrated Utilities [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		46.7		41.5
Vertically Integrated Utilities [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,559.8		2,530.9
Vertically Integrated Utilities [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,212.3		1,170.4
Vertically Integrated Utilities [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		645.1		633.4
Vertically Integrated Utilities [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		647.1	[1]	670.3
Vertically Integrated Utilities [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		55.3		56.8
Vertically Integrated Utilities [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		354.8		297.5
Vertically Integrated Utilities [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		235.9		182.8
Vertically Integrated Utilities [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		118.9	[2]	114.7	[3]
Vertically Integrated Utilities [Member] \| Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[1]	0	[4]
Vertically Integrated Utilities [Member] \| Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[5]	0	[4]
Vertically Integrated Utilities [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		59.7	[6]	32.6	[7]
Vertically Integrated Utilities [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,974.3		2,861
Vertically Integrated Utilities [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(26.4)		(3.2)
Vertically Integrated Utilities [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		(0.7)	[8]	(3.1)	[9]
Vertically Integrated Utilities [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenues		(25.7)	[1],[10]	(0.1)	[4],[11]
Transmission And Distribution Utilities [Member]
Disaggregation of Revenue
Revenues		1,490.2		1,464.2
Transmission And Distribution Utilities [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		7		8.9
Transmission And Distribution Utilities [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,250.8		1,257.7
Transmission And Distribution Utilities [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		703.8		656.8
Transmission And Distribution Utilities [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		397		375.9
Transmission And Distribution Utilities [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		136.1	[1]	212.9
Transmission And Distribution Utilities [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		13.9		12.1
Transmission And Distribution Utilities [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		179.8		164.2
Transmission And Distribution Utilities [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Transmission And Distribution Utilities [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		179.8	[2]	164.2	[3]
Transmission And Distribution Utilities [Member] \| Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[1]	0	[4]
Transmission And Distribution Utilities [Member] \| Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[5]	0	[4]
Transmission And Distribution Utilities [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		51	[6]	42.8	[7]
Transmission And Distribution Utilities [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,481.6		1,464.7
Transmission And Distribution Utilities [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		8.6		(0.5)
Transmission And Distribution Utilities [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		0.7	[8]	(11.6)	[9]
Transmission And Distribution Utilities [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenues		7.9	[1],[10]	11.1	[4],[11]
AEP Transmission Holdco [Member]
Disaggregation of Revenue
Revenues		497.3		455.5
AEP Transmission Holdco [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
AEP Transmission Holdco [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
AEP Transmission Holdco [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
AEP Transmission Holdco [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[1]	0
AEP Transmission Holdco [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
AEP Transmission Holdco [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		488.7		450.1
AEP Transmission Holdco [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
AEP Transmission Holdco [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		488.7	[2]	450.1	[3]
AEP Transmission Holdco [Member] \| Wholesale Transmission [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		387		357
AEP Transmission Holdco [Member] \| Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[1]	0	[4]
AEP Transmission Holdco [Member] \| Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[5]	0	[4]
AEP Transmission Holdco [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		8.1	[6]	3.6	[7]
AEP Transmission Holdco [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		496.8		453.7
AEP Transmission Holdco [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		0.5		1.8
AEP Transmission Holdco [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		0.5	[8]	1.8	[9]
AEP Transmission Holdco [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenues		0	[1],[10]	0	[4],[11]
Generation And Marketing [Member]
Disaggregation of Revenue
Revenues		563.5		327
Generation And Marketing [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		47.6		0.1
Generation And Marketing [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Generation And Marketing [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Generation And Marketing [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Generation And Marketing [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[1]	0
Generation And Marketing [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Generation And Marketing [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		605.1		467.4
Generation And Marketing [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		27.4		32.4
Generation And Marketing [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[2]	0	[3]
Generation And Marketing [Member] \| Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		6.3	[1]	21.3	[4]
Generation And Marketing [Member] \| Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		571.4	[5]	413.7	[4]
Generation And Marketing [Member] \| Retail, Trading and Marketing Revenues [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		46
Generation And Marketing [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1.3	[6]	0.6	[7]
Generation And Marketing [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		606.4		468
Generation And Marketing [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(42.9)		(141)
Generation And Marketing [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		0	[8]	0	[9]
Generation And Marketing [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenues		(42.9)	[1],[10]	(141)	[4],[11]
Other Segments [Member]
Disaggregation of Revenue
Revenues	[23]	52.8		30.1
Other Segments [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers	[23]	37.9		27.8
Other Segments [Member] \| Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Other Segments [Member] \| Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Other Segments [Member] \| Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Other Segments [Member] \| Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[1]	0
Other Segments [Member] \| Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Other Segments [Member] \| Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0.5		(0.3)
Other Segments [Member] \| Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Other Segments [Member] \| Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[2]	0	[3]
Other Segments [Member] \| Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[1]	0	[4]
Other Segments [Member] \| Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0.5	[5]	(0.3)	[4]
Other Segments [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		60.4	[6]	29.4	[7]
Other Segments [Member] \| Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		60.9		29.1
Other Segments [Member] \| Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(8.1)		1
Other Segments [Member] \| Alternative [Member]
Disaggregation of Revenue
Revenues		0	[8]	0	[9]
Other Segments [Member] \| Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers	[23]	14.9		2.3
Revenues		(8.1)	[1],[10]	1	[4],[11]
Corporate and Other \| Other Revenues [Member] \| Related Party
Disaggregation of Revenue
Revenue from Contracts with Customers		$ 48		$ 29

[1] Amounts include affiliated and nonaffiliated revenues. Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $387 million. The remaining affiliated amounts were immaterial. Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $357 million. The remaining affiliated amounts were immaterial. Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $46 million. The remaining affiliated amounts were immaterial. Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $48 million. The remaining affiliated amounts were immaterial. Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $29 million. The remaining affiliated amounts were immaterial. Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. Generation & Marketing includes economic hedge activity. Generation & Marketing includes economic hedge activity. Amounts include affiliated and nonaffiliated revenues. Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $41 million primarily related to the PPA with KGPCo. Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $47 million primarily related to the PPA with KGPCo. Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $384 million, APCo was $21 million and SWEPCo was $14 million. The remaining affiliated amounts were immaterial. Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $349 million. The remaining affiliated amounts were immaterial. Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $18 million primarily related to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $18 million primarily related to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. Amounts include affiliated and nonaffiliated revenues. Represents inter-segment revenues. 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.