American Electric Power (AEP) 10-Q 4 May 23 2023 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2023	May 04, 2023
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2023
Document Transition Report	false
Entity File Number	1-3525
Entity Registrant Name	AMERICAN ELECTRIC POWER CO INC.
Entity Incorporation, State or Country Code	NY
Entity Tax Identification Number	13-4922640
Entity Address, Address Line One	1 Riverside Plaza,
Entity Address, City or Town	Columbus,
Entity Address, State or Province	OH
Entity Address, Postal Zip Code	43215-2373
City Area Code	(614)
Local Phone Number	716-1000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		514,790,910
Entity Central Index Key	0000004904
Amendment Flag	false
Document Fiscal Year Focus	2023
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
The NASDAQ Stock Market LLC | Preferred Stock 2
Entity Information [Line Items]
Title of 12(b) Security	6.125% Corporate Units
Trading Symbol	AEPPZ
Security Exchange Name	NASDAQ

Consolidated Statements of Inco

Consolidated Statements of Income - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2023		Mar. 31, 2022
Revenues
Revenue from Contracts with Customers		$ 4,690.9		$ 4,592.6
Sales to AEP Affiliates		0		0
TOTAL REVENUES		4,690.9		4,592.6
Expenses
Other Operation		680		662.2
Maintenance		317.3		285
Depreciation and Amortization		775.5		792.4
Taxes Other Than Income Taxes		394.9		364.2
TOTAL EXPENSES		3,986.1		3,604.5
OPERATING INCOME (LOSS)		704.8		988.1
Other Income (Expense):
Other Income		14.7		2.3
Allowance for Equity Funds Used During Construction		31.3		31
Non-Service Cost Components of Net Periodic Benefit Cost		55.5		47.2
Interest Expense		(415.7)		(313.4)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		390.6		755.2
Income Tax Expense (Benefit)		10.4		52.8
Equity Earnings (Loss) of Unconsolidated Subsidiaries		20.2		15.7
Net Income (Loss)		400.4		718.1
Net Income (Loss) Attributable to Noncontrolling Interests		3.4		3.4
Earnings Attributable to Common Shareholders		$ 397		$ 714.7
Earnings Per Share
Weighted Average Number of Basic AEP Common Shares Outstanding		514,176,648		506,050,147
Total Basic Earnings Per Share Attributable to AEP Common Shareholders		$ 0.77		$ 1.41
Weighted Average Number of Diluted AEP Common Shares Outstanding		515,598,090		507,658,522
Total Diluted Earnings Per Share Attributable to AEP Common Shareholders		$ 0.77		$ 1.41
Common Stock, Dividends Per Share, Declared		$ 0.83		$ 0.78
Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers		$ 2,816.3		$ 2,646.8
Transmission and Distribution Utilities [Member]
Revenues
Revenue from Contracts with Customers		1,455.3		1,242.2
Generation and Marketing [Member]
Revenues
Revenue from Contracts with Customers		326.9		609.5
Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		92.4		94.1
TOTAL REVENUES		(129.9)	[1]	165.4	[2],[3]
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold		1,706.4		1,500.7
AEP Texas Inc. [Member]
Revenues
Sales to AEP Affiliates		1.2		0.9
TOTAL REVENUES		429.5		416.7
Expenses
Other Operation		146.9		125.8
Maintenance		24.4		22.6
Depreciation and Amortization		111		108.8
Taxes Other Than Income Taxes		43.5		37.3
TOTAL EXPENSES		325.8		294.5
OPERATING INCOME (LOSS)		103.7		122.2
Other Income (Expense):
Interest Income		0.4		0.1
Allowance for Equity Funds Used During Construction		6.3		4.3
Non-Service Cost Components of Net Periodic Benefit Cost		4.8		4.2
Interest Expense		(56.9)		(45.5)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		58.3		85.3
Income Tax Expense (Benefit)		10.7		15.7
Net Income (Loss)		47.6		69.6
AEP Texas Inc. [Member] | Transmission and Distribution Utilities [Member]
Revenues
Revenue from Contracts with Customers		427.7		414.7
AEP Texas Inc. [Member] | Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		0.6		1.1
TOTAL REVENUES		0	[4]	0	[5]
AEP Transmission Co [Member]
Revenues
Sales to AEP Affiliates		357.4		325
Provision for Refund Affiliated		(4.8)		(0.3)
Provision for Refund-Nonaffiliated		(1)		(11.3)
TOTAL REVENUES		441.6		400.4
Expenses
Other Operation		29		25.5
Maintenance		4.9		3.3
Depreciation and Amortization		95.2		83.1
Taxes Other Than Income Taxes		74.8		65.6
TOTAL EXPENSES		203.9		177.5
OPERATING INCOME (LOSS)		237.7		222.9
Other Income (Expense):
Interest Income		1.5		0.1
Allowance for Equity Funds Used During Construction		16.4		15.6
Interest Expense		(45.2)		(37.7)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		210.4		200.9
Income Tax Expense (Benefit)		47.7		45.5
Net Income (Loss)		162.7		155.4
Earnings Per Share
Revenues from Related Parties, Net of Provisions for Refund		352.6		324.7
AEP Transmission Co [Member] | AEPTCo Parent [Member]
Revenues
Revenue from Contracts with Customers		0		0
Sales to AEP Affiliates		0		0
TOTAL REVENUES		0		0
Other Income (Expense):
Net Income (Loss)	[6]	1.1		0
AEP Transmission Co [Member] | State Transcos [Member]
Revenues
Sales to AEP Affiliates		352.6		324.7
TOTAL REVENUES		441.6		400.4
Other Income (Expense):
Net Income (Loss)		161.6		155.4
AEP Transmission Co [Member] | Transmission [Member]
Revenues
Revenue from Contracts with Customers		90		87
Earnings Per Share
Revenue from Contract with Customers, Net of Provisions for Refund, Including Assessed Tax		89		75.7
AEP Transmission Co [Member] | Transmission [Member] | State Transcos [Member]
Revenues
Revenue from Contracts with Customers		89		75.7
AEP Transmission Co [Member] | Other Revenues [Member]
Revenues
TOTAL REVENUES		0	[4]	0	[5]
Appalachian Power Co [Member]
Revenues
Sales to AEP Affiliates		69.6		56.9
TOTAL REVENUES		987.7		907.3
Expenses
Other Operation		191.8		184.9
Maintenance		73.1		74.1
Depreciation and Amortization		143		145.2
Taxes Other Than Income Taxes		41.8		40.2
TOTAL EXPENSES		789.4		714.9
OPERATING INCOME (LOSS)		198.3		192.4
Other Income (Expense):
Interest Income		0.6		0.1
Allowance for Equity Funds Used During Construction		2.4		2
Non-Service Cost Components of Net Periodic Benefit Cost		8.1		7.3
Interest Expense		(65.3)		(54.3)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		144.1		147.5
Income Tax Expense (Benefit)		31.6		27.3
Net Income (Loss)		112.5		120.2
Appalachian Power Co [Member] | Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers		914.5		847.1
Appalachian Power Co [Member] | Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		3.6		3.3
TOTAL REVENUES		0	[4]	0.1	[5]
Appalachian Power Co [Member] | Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold		339.7		270.5
Indiana Michigan Power Co [Member]
Revenues
Sales to AEP Affiliates		1.2		2
Other Revenues - Affiliated		15.9		8.4
TOTAL REVENUES		663		625.2
Expenses
Purchased Electricity from AEP Affiliates		45.1		57.1
Other Operation		169.7		139.3
Maintenance		58.6		51
Depreciation and Amortization		125.2		134.9
Taxes Other Than Income Taxes		19.5		25.2
TOTAL EXPENSES		517.3		513.2
OPERATING INCOME (LOSS)		145.7		112
Other Income (Expense):
Other Income		0.6		2.6
Allowance for Equity Funds Used During Construction		0.5		2.9
Non-Service Cost Components of Net Periodic Benefit Cost		8		6.3
Interest Expense		(33.2)		(30.3)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		121.1		90.6
Income Tax Expense (Benefit)		18.3		1.1
Net Income (Loss)		102.8		89.5
Indiana Michigan Power Co [Member] | Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers		642.8		612
Indiana Michigan Power Co [Member] | Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		3.1		2.8
Sales to AEP Affiliates				10
TOTAL REVENUES		0	[4]	(0.1)	[5]
Indiana Michigan Power Co [Member] | Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold		99.2		105.7
Ohio Power Co [Member]
Revenues
Sales to AEP Affiliates		7.6		3.7
TOTAL REVENUES		1,034.6		830
Expenses
Purchased Electricity from AEP Affiliates		0		6.3
Other Operation		273.8		237.6
Maintenance		44.3		40.4
Depreciation and Amortization		75.2		74.9
Taxes Other Than Income Taxes		135.3		127
TOTAL EXPENSES		921.2		712.5
OPERATING INCOME (LOSS)		113.4		117.5
Other Income (Expense):
Interest Income		0.1		0.1
Carrying Costs Income		0		0.1
Allowance for Equity Funds Used During Construction		2.8		3
Non-Service Cost Components of Net Periodic Benefit Cost		6.5		5.5
Interest Expense		(31.1)		(29.2)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		91.7		97
Income Tax Expense (Benefit)		13.7		13.8
Net Income (Loss)		78		83.2
Ohio Power Co [Member] | Transmission and Distribution Utilities [Member]
Revenues
Revenue from Contracts with Customers		1,021.8		824.2
Ohio Power Co [Member] | Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		5.2		2.1
TOTAL REVENUES		11.1	[4]	6.3	[5]
Ohio Power Co [Member] | Purchased Electricity for Resale [Member]
Expenses
Cost of Goods and Services Sold		392.6		226.3
Public Service Co Of Oklahoma [Member]
Revenues
Sales to AEP Affiliates		0.7		0.6
TOTAL REVENUES		417		387.6
Expenses
Other Operation		92.1		88.8
Maintenance		28.8		25.4
Depreciation and Amortization		61.1		52.7
Taxes Other Than Income Taxes		17.3		14.2
TOTAL EXPENSES		399.4		369.8
OPERATING INCOME (LOSS)		17.6		17.8
Other Income (Expense):
Interest Income		1		1.7
Allowance for Equity Funds Used During Construction		1.5		1.1
Non-Service Cost Components of Net Periodic Benefit Cost		3.6		3.1
Interest Expense		(25.2)		(18.9)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		(1.5)		4.8
Income Tax Expense (Benefit)		0.8		(1)
Net Income (Loss)		(2.3)		5.8
Public Service Co Of Oklahoma [Member] | Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers		414.8		386.4
Public Service Co Of Oklahoma [Member] | Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		1.5		0.6
TOTAL REVENUES		0	[4]	0	[5]
Public Service Co Of Oklahoma [Member] | Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold		200.1		188.7
Southwestern Electric Power Co [Member]
Revenues
Sales to AEP Affiliates		11.7		10
TOTAL REVENUES		515.9		494.8
Expenses
Other Operation		99.2		91.5
Maintenance		37.7		30.1
Depreciation and Amortization		80.4		77.8
Taxes Other Than Income Taxes		36.1		29.8
TOTAL EXPENSES		462.7		427.4
OPERATING INCOME (LOSS)		53.2		67.4
Other Income (Expense):
Interest Income		5.4		3.6
Allowance for Equity Funds Used During Construction		0.5		1.6
Non-Service Cost Components of Net Periodic Benefit Cost		3.4		3.1
Interest Expense		(25)		(33.1)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS		37.5		42.6
Income Tax Expense (Benefit)		(4)		(2.2)
Equity Earnings (Loss) of Unconsolidated Subsidiaries		0.3		0.3
Net Income (Loss)		41.8		45.1
Net Income (Loss) Attributable to Noncontrolling Interests		1.2		1
Earnings Attributable to Common Shareholders		40.6		44.1
Southwestern Electric Power Co [Member] | Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers		503.7		484.2
Southwestern Electric Power Co [Member] | Other Revenues [Member]
Revenues
Revenue from Contracts with Customers		0.5		0.6
TOTAL REVENUES		0	[4]	0	[5]
Southwestern Electric Power Co [Member] | Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold		209.3		198.2
Reconciling Adjustments [Member]
Revenues
Revenue from Contracts with Customers		0		0
Sales to AEP Affiliates		(443.7)		(392.2)
TOTAL REVENUES		(443.7)		(392.2)
Other Income (Expense):
Net Income (Loss)		0		0
Reconciling Adjustments [Member] | Other Revenues [Member]
Revenues
TOTAL REVENUES		(0.9)	[1]	(2.9)	[2],[3]
Reconciling Adjustments [Member] | AEP Transmission Co [Member]
Revenues
Revenue from Contracts with Customers		0		0
Sales to AEP Affiliates		0		0
TOTAL REVENUES		0		0
Other Income (Expense):
Net Income (Loss)		0		0
Competitive Contracted Renewable Portfolio
Expenses
Asset Impairments and Other Related Charges		$ 112		$ 0
[1]Amounts include affiliated and nonaffiliated revenues.[2]Amounts include affiliated and nonaffiliated revenues[3]Generation & Marketing includes economic hedge activity.[4]Amounts include affiliated and nonaffiliated revenues.[5]Amounts include affiliated and nonaffiliated revenues.[6]Includes the elimination of AEPTCo Parent’s equity earnings in the State Transcos.

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income (Loss) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Net Income (Loss)	$ 400.4	$ 718.1
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	(152.4)	248
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(16.1)	(2.2)
Reclassifications of KPCo Pension and OPEB Regulatory Assets, Net of Tax	16.7	0
Other Comprehensive Income (Loss), Net of Tax, Total	(151.8)	245.8
TOTAL COMPREHENSIVE INCOME (LOSS)	248.6	963.9
Total Comprehensive Income (Loss) Attributable to Noncontrolling Interest	3.4	3.4
TOTAL COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	245.2	960.5
Cash Flow Hedges, Tax	(40.5)	65.9
Amortization of Pension and OPEB Deferred Costs, Tax	(4.3)	(0.6)
Reclassifications of KPCo Pension and OPEB Regulatory Assets, Tax	4.4	0
Appalachian Power Co [Member]
Net Income (Loss)	112.5	120.2
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	(0.2)	(0.2)
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(0.8)	(1.1)
Other Comprehensive Income (Loss), Net of Tax, Total	(1)	(1.3)
TOTAL COMPREHENSIVE INCOME (LOSS)	111.5	118.9
Cash Flow Hedges, Tax	(0.1)	(0.1)
Amortization of Pension and OPEB Deferred Costs, Tax	(0.2)	(0.3)
AEP Texas Inc. [Member]
Net Income (Loss)	47.6	69.6
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	0	0.3
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(0.6)	0
Other Comprehensive Income (Loss), Net of Tax, Total	(0.6)	0.3
TOTAL COMPREHENSIVE INCOME (LOSS)	47	69.9
Cash Flow Hedges, Tax	0	0.1
Amortization of Pension and OPEB Deferred Costs, Tax	(0.1)	0
Indiana Michigan Power Co [Member]
Net Income (Loss)	102.8	89.5
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	(0.7)	0.4
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(1.9)	(0.1)
Other Comprehensive Income (Loss), Net of Tax, Total	(2.6)	0.3
TOTAL COMPREHENSIVE INCOME (LOSS)	100.2	89.8
Cash Flow Hedges, Tax	(0.2)	0.1
Amortization of Pension and OPEB Deferred Costs, Tax	(0.5)	0
Ohio Power Co [Member]
Net Income (Loss)	78	83.2
Public Service Co Of Oklahoma [Member]
Net Income (Loss)	(2.3)	5.8
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	(1.5)	0
Other Comprehensive Income (Loss), Net of Tax, Total	(1.5)
TOTAL COMPREHENSIVE INCOME (LOSS)	(3.8)	5.8
Cash Flow Hedges, Tax	(0.4)	0
Southwestern Electric Power Co [Member]
Net Income (Loss)	41.8	45.1
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	0.4	0.1
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(0.3)	(0.4)
Other Comprehensive Income (Loss), Net of Tax, Total	0.1	(0.3)
TOTAL COMPREHENSIVE INCOME (LOSS)	41.9	44.8
Total Comprehensive Income (Loss) Attributable to Noncontrolling Interest	1.2	1
TOTAL COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	40.7	43.8
Cash Flow Hedges, Tax	0.1	0
Amortization of Pension and OPEB Deferred Costs, Tax	(0.1)	(0.1)
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
OTHER COMPREHENSIVE INCOME
Other Comprehensive Income (Loss), Net of Tax, Total	0.6	(2.2)
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | Appalachian Power Co [Member]
OTHER COMPREHENSIVE INCOME
Other Comprehensive Income (Loss), Net of Tax, Total	(0.8)	(1.1)
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | AEP Texas Inc. [Member]
OTHER COMPREHENSIVE INCOME
Other Comprehensive Income (Loss), Net of Tax, Total	(0.6)	0
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | Indiana Michigan Power Co [Member]
OTHER COMPREHENSIVE INCOME
Other Comprehensive Income (Loss), Net of Tax, Total	(1.9)	(0.1)
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | Southwestern Electric Power Co [Member]
OTHER COMPREHENSIVE INCOME
Other Comprehensive Income (Loss), Net of Tax, Total	$ (0.3)	$ (0.4)

Condensed Consolidated Statemen

Condensed Consolidated Statements of Changes in Equity - USD ($) $ in Millions	Total	Generation And Marketing [Member]	Appalachian Power Co [Member]	AEP Texas Inc. [Member]	AEP Transmission Co [Member]	Indiana Michigan Power Co [Member]	Ohio Power Co [Member]	Public Service Co Of Oklahoma [Member]	Southwestern Electric Power Co [Member]	Common Stock [Member]	Common Stock [Member] Appalachian Power Co [Member]	Common Stock [Member] Indiana Michigan Power Co [Member]	Common Stock [Member] Ohio Power Co [Member]	Common Stock [Member] Public Service Co Of Oklahoma [Member]	Common Stock [Member] Southwestern Electric Power Co [Member]	Additional Paid-in Capital [Member]	Additional Paid-in Capital [Member] Appalachian Power Co [Member]	Additional Paid-in Capital [Member] AEP Texas Inc. [Member]	Additional Paid-in Capital [Member] AEP Transmission Co [Member]	Additional Paid-in Capital [Member] Indiana Michigan Power Co [Member]	Additional Paid-in Capital [Member] Ohio Power Co [Member]	Additional Paid-in Capital [Member] Public Service Co Of Oklahoma [Member]	Additional Paid-in Capital [Member] Southwestern Electric Power Co [Member]	Retained Earnings [Member]		Retained Earnings [Member] Appalachian Power Co [Member]	Retained Earnings [Member] AEP Texas Inc. [Member]	Retained Earnings [Member] AEP Transmission Co [Member]	Retained Earnings [Member] Indiana Michigan Power Co [Member]	Retained Earnings [Member] Ohio Power Co [Member]	Retained Earnings [Member] Public Service Co Of Oklahoma [Member]	Retained Earnings [Member] Southwestern Electric Power Co [Member]	Accumulated Other Comprehensive Income [Member]	Accumulated Other Comprehensive Income [Member] Appalachian Power Co [Member]	Accumulated Other Comprehensive Income [Member] AEP Texas Inc. [Member]	Accumulated Other Comprehensive Income [Member] Indiana Michigan Power Co [Member]	Accumulated Other Comprehensive Income [Member] Public Service Co Of Oklahoma [Member]	Accumulated Other Comprehensive Income [Member] Southwestern Electric Power Co [Member]	Noncontrolling Interests [Member]	Noncontrolling Interests [Member] Southwestern Electric Power Co [Member]
Beginning Balance at Dec. 31, 2021					$ 5,376.1														$ 2,949.6									$ 2,426.5
Beginning Balance at Dec. 31, 2021	$ 22,680.2		$ 4,647.9	$ 3,594.2		$ 2,784.7	$ 2,846.3	$ 2,291.6	$ 3,149.8	$ 3,408.7	$ 260.4	$ 56.6	$ 321.2	$ 157.2	$ 0.1	$ 7,172.6	$ 1,828.7	$ 1,553.9		$ 980.9	$ 838.8	$ 1,039	$ 1,092.2	$ 11,667.1		$ 2,534.4	$ 2,046.8		$ 1,748.5	$ 1,686.3	$ 1,095.4	$ 2,050.9	$ 184.8	$ 24.4	$ (6.5)	$ (1.3)	$ 0	$ 6.7	$ 247	$ (0.1)
Beginning Balance, Shares at Dec. 31, 2021										524,400,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of Common Stock, Value	809.5									$ 2.4						807.1
Issuance of Common Stock, Shares										400,000
Common Stock Dividends	(398.8)																							(395.2)	[1]
Common Stock Dividends			(18.8)			(25)	(15)																			(18.8)			(25)	(15)
Common Stock Dividends									(0.8)																														(3.6)	(0.8)
Other Changes in Equity	(16.7)															(15.2)								(1.5)
Capital Contribution from Member									350														350
Dividends Paid on Common Stock			(18.8)		(40)	(25)	(15)	0																				(40)
Net Income (Loss)	714.7								44.1															714.7								44.1
Net Income (Loss) Attributable to Noncontrolling Interests	3.4								1																														3.4	1
Net Income (Loss)	718.1	$ 116	120.2	69.6	155.4	89.5	83.2	5.8	45.1																	120.2	69.6	155.4	89.5	83.2	5.8
Other Comprehensive Income (Loss)	245.8		(1.3)	0.3		0.3			(0.3)																								245.8	(1.3)	0.3	0.3		(0.3)
Ending Balance at Mar. 31, 2022					5,491.5														2,949.6									2,541.9
Ending Balance at Mar. 31, 2022	$ 24,038.1		4,748	3,664.1		2,849.5	2,914.5	2,297.4	3,543.8	$ 3,411.1	260.4	56.6	321.2	157.2	0.1	7,964.5	1,828.7	1,553.9		980.9	838.8	1,039	1,442.2	11,985.1		2,635.8	2,116.4		1,813	1,754.5	1,101.2	2,095	430.6	23.1	(6.2)	(1)	0	6.4	246.8	0.1
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contributions from Parent				0	0		0		350
Ending Balance, Shares at Mar. 31, 2022										524,800,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Dividends Per Share, Declared	$ 0.78
Beginning Balance at Dec. 31, 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	525,099,321							10,482,000		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)	[2]
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			0		(55)	(31.2)	0	(17.5)																				(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	$ (156.4)	112.5	47.6	162.7	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																									(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				$ 100	$ 25		$ 50		$ 50
Ending Balance, Shares at Mar. 31, 2023	525,883,990							10,482,000		525,900,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Dividends Per Share, Declared	$ 0.83
[1]Cash dividends declared per AEP common share were $0.78.[2]Cash dividends declared per AEP common share were $0.83.

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Millions		Mar. 31, 2023		Dec. 31, 2022
Current Assets
Cash and Cash Equivalents		$ 343.5		$ 509.4
Restricted Cash		50		47.1
Other Temporary Investments		194.6		187.6
Accounts Receivable:
Customers		949.8		1,145.1
Accrued Unbilled Revenues		239.7		322.9
Pledged Accounts Receivable - AEP Credit		1,133		1,207.4
Miscellaneous		39.3		49.7
Allowance for Uncollectible Accounts		(58)		(57.1)
Total Accounts Receivable		2,303.8		2,668
Fuel		554.7		435.1
Materials and Supplies		902.5		915.1
Risk Management Assets		190.6		348.8
Accrued Tax Benefits		141.2		99.4
Assets Held for Sale		1,396.3		0
Regulatory Asset for Under-Recovered Fuel Costs		1,380.1		1,310
Prepayments and Other Current Assets		340.9		255
TOTAL CURRENT ASSETS		7,798.2		6,775.5
Property, Plant and Equipment
Generation		24,034.3		25,834.2
Transmission		33,570.2		33,266.9
Distribution		27,521.1		27,138.8
Other Property, Plant and Equipment		6,056.3		5,971.8
Construction Work in Progress		5,526.2		4,809.7
Total Property, Plant and Equipment		96,708.1		97,021.4
Accumulated Depreciation and Amortization		23,361.1		23,682.3
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		73,347		73,339.1
Other Noncurrent Assets
Regulatory Assets		4,578		4,762
Securitized Assets		420.1		446
Spent Nuclear Fuel and Decommissioning Trusts		3,501.1		3,341.2
Goodwill		52.5		52.5
Long-term Risk Management Assets		318.2		284.1
Operating Lease Assets		631.5		645.5
Deferred Charges and Other Noncurrent Assets		3,871.3		3,757.4
TOTAL OTHER NONCURRENT ASSETS		13,372.7		13,288.7
TOTAL ASSETS		94,517.9	[1]	93,403.3
Current Liabilities
Accounts Payable		2,269.3		2,670.8
Short-term Debt:
Securitized Debt for Receivables - AEP Credit	[2]	750		750
Other Short-term Debt		2,872.1		3,362.2
Total Short-term Debt		3,622.1		4,112.2
Long-term Debt Due Within One Year		2,905.1		2,486.4
Risk Management Liabilities		166		145.2
Customer Deposits		390		408.8
Accrued Taxes		1,599.9		1,714.6
Accrued Interest		440.5		336.5
Obligations Under Operating Leases		116.4		113.6
Liabilities Held for Sale		67.2		0
Other Current Liabilities		1,045.2		1,278.2
TOTAL CURRENT LIABILITIES		12,621.7		13,266.3
Noncurrent Liabilities
Long-term Debt		36,239.1		34,314.6
Deferred Income Tax Liabilities, Net		8,989		8,896.9
Long-term Risk Management Liabilities		315.4		345.2
Regulatory Liabilities and Deferred Investment Tax Credits		8,095.3		8,115.6
Asset Retirement Obligations		2,877.5		2,879.3
Employee Benefits and Pension Obligations		246.5		257.3
Obligations Under Operating Leases		535.9		552.5
Deferred Credits and Other Noncurrent Liabilities		573.1		607.3
TOTAL NONCURRENT LIABILITIES		57,871.8		55,968.7
TOTAL LIABILITIES		70,493.5		69,235
Rate Matters
Commitments and Contingencies
Contingently Reedemable Performance Share Awards		56.6		45.9
Total Mezzanine Equity		56.6		45.9
Equity
Common Stock		3,418.2		3,413.1
Paid-in Capital		8,074.3		8,051
Retained Earnings		12,313.8		12,345.6
Accumulated Other Comprehensive Income (Loss)		(68.1)		83.7
TOTAL COMMON SHAREHOLDER'S EQUITY		23,738.2		23,893.4
Noncontrolling Interests		229.6		229
TOTAL EQUITY		23,967.8		24,122.4
TOTAL LIABILITIES AND EQUITY		$ 94,517.9		$ 93,403.3
Common Stock, No Par Value		$ 6.50		$ 6.50
Common Stock, Shares Authorized		600,000,000		600,000,000
Common Stock, Shares, Issued		525,883,990		525,099,321
Treasury Stock, Shares		11,233,240		11,233,240
Commodity [Member]
Equity
Cross Default Provisions Maximum Third Party Obligation Amount		$ 50
Subsidiaries [Member]
Current Assets
Restricted Cash		50		$ 47.1
Other Temporary Investments		187.5		182.9
Short-term Debt:
Long-term Debt Due Within One Year		206.9		218.2
Noncurrent Liabilities
Long-term Debt		624.2		755.3
AEP Texas Inc. [Member]
Current Assets
Cash and Cash Equivalents		0.1		0.1
Restricted Cash		42.5		32.7
Advances to Affiliates		6.8		6.9
Accounts Receivable:
Customers		141.3		150.9
Affiliated Companies - Contracts with Customers		13.5		11.9
Accrued Unbilled Revenues		74.7		91.4
Miscellaneous		0.2		0.2
Allowance for Uncollectible Accounts		(4.1)		(4.2)
Total Accounts Receivable		225.6		250.2
Materials and Supplies		139.9		138.8
Accrued Tax Benefits		8.3		12.2
Prepayments and Other Current Assets		5.9		6
TOTAL CURRENT ASSETS		429.1		446.9
Property, Plant and Equipment
Transmission		6,373.2		6,301.5
Distribution		5,419.5		5,312.8
Other Property, Plant and Equipment		1,078.7		1,022.8
Construction Work in Progress		934.8		805.2
Total Property, Plant and Equipment		13,806.2		13,442.3
Accumulated Depreciation and Amortization		1,798.2		1,760.7
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		12,008		11,681.6
Other Noncurrent Assets
Regulatory Assets		299.3		298.3
Securitized Assets		267.1		286.4
Deferred Charges and Other Noncurrent Assets		268.7		179
TOTAL OTHER NONCURRENT ASSETS		835.1		763.7
TOTAL ASSETS		13,272.2		12,892.2
Current Liabilities
Advances from Affiliates		450.8		96.5
Accounts Payable		288.4		331
Affiliated Companies		26.7		34.7
Short-term Debt:
Long-term Debt Due Within One Year		153.7		278.5
Accrued Taxes		136.1		95.5
Accrued Interest		72.2		48.3
Obligations Under Operating Leases		29.4		28.6
Other Current Liabilities		122.8		130.7
TOTAL CURRENT LIABILITIES		1,280.1		1,043.8
Noncurrent Liabilities
Long-term Debt		5,368.3		5,379.3
Deferred Income Tax Liabilities, Net		1,153.2		1,144.2
Regulatory Liabilities and Deferred Investment Tax Credits		1,258		1,259.6
Obligations Under Operating Leases		64.8		67.8
Deferred Credits and Other Noncurrent Liabilities		96.5		93.2
TOTAL NONCURRENT LIABILITIES		7,940.8		7,944.1
TOTAL LIABILITIES		9,220.9		8,987.9
Rate Matters
Commitments and Contingencies
Equity
Paid-in Capital		1,658.2		1,558.2
Retained Earnings		2,402.3		2,354.7
Accumulated Other Comprehensive Income (Loss)		(9.2)		(8.6)
TOTAL EQUITY		4,051.3		3,904.3
TOTAL LIABILITIES AND EQUITY		13,272.2		12,892.2
AEP Texas Inc. [Member] | AEP Texas Transition Funding and Restoration Funding [Member]
Current Assets
Restricted Cash		42.5		32.7
Other Noncurrent Assets
Securitized Assets		267.1		286.4
Short-term Debt:
Long-term Debt Due Within One Year		93.7		93.5
Accrued Interest		2.2		2.2
Noncurrent Liabilities
Long-term Debt		209.3		221
AEP Transmission Co [Member]
Current Assets
Cash and Cash Equivalents		0		0
Advances to Affiliates		297.5		4.4
Accounts Receivable:
Customers		51.9		46.9
Affiliated Companies - Contracts with Customers		127		119.5
Total Accounts Receivable		178.9		166.4
Materials and Supplies		14.8		10.7
Prepayments and Other Current Assets		2.1		7.2
TOTAL CURRENT ASSETS		493.3		188.7
Property, Plant and Equipment
Transmission		12,486.7		12,335.4
Other Property, Plant and Equipment		484.6		476.8
Construction Work in Progress		1,831.9		1,554.7
Total Property, Plant and Equipment		14,803.2		14,366.9
Accumulated Depreciation and Amortization		1,091.2		1,027
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		13,712		13,339.9
Other Noncurrent Assets
Regulatory Assets		5.8		7.2
Deferred Property Taxes		232		266.6
Deferred Charges and Other Noncurrent Assets		11.6		11.8
TOTAL OTHER NONCURRENT ASSETS		249.4		285.6
TOTAL ASSETS		14,454.7		13,814.2
Current Liabilities
Advances from Affiliates		4.4		229.3
Accounts Payable		421.7		427.8
Affiliated Companies		110.8		82.7
Short-term Debt:
Long-term Debt Due Within One Year		60		60
Accrued Taxes		465.7		529.8
Accrued Interest		56.8		28.8
Obligations Under Operating Leases		1.3		1.3
Other Current Liabilities		14.1		8.3
TOTAL CURRENT LIABILITIES		1,134.8		1,368
Noncurrent Liabilities
Long-term Debt		5,412.1		4,722.8
Deferred Income Tax Liabilities, Net		1,079.1		1,056.5
Regulatory Liabilities and Deferred Investment Tax Credits		746.4		723.3
Obligations Under Operating Leases		1.2		1.5
Deferred Credits and Other Noncurrent Liabilities		75.4		69.1
TOTAL NONCURRENT LIABILITIES		7,314.2		6,573.2
TOTAL LIABILITIES		8,449		7,941.2
Rate Matters
Commitments and Contingencies
Equity
Paid-in Captial		3,047.3		3,022.3
Retained Earnings		2,958.4		2,850.7
TOTAL MEMBER'S EQUITY		6,005.7		5,873
TOTAL LIABILITIES AND EQUITY		14,454.7		13,814.2
Appalachian Power Co [Member]
Current Assets
Cash and Cash Equivalents		7.1		7.5
Restricted Cash		7.5		14.4
Advances to Affiliates		18.7		19.8
Accounts Receivable:
Customers		154		168.9
Affiliated Companies - Contracts with Customers		91.5		94
Accrued Unbilled Revenues		55.4		91.3
Miscellaneous		0.2		0.3
Allowance for Uncollectible Accounts		(2)		(1.7)
Total Accounts Receivable		299.1		352.8
Fuel		220.5		158.9
Materials and Supplies		128.4		130.6
Risk Management Assets		12.4		69.1
Regulatory Asset for Under-Recovered Fuel Costs		574.5		473.1
Prepayments and Other Current Assets		30.8		33.4
TOTAL CURRENT ASSETS		1,299		1,259.6
Property, Plant and Equipment
Generation		6,886.9		6,776.8
Transmission		4,510.3		4,482.8
Distribution		4,992.6		4,933
Other Property, Plant and Equipment		890.3		883.3
Construction Work in Progress		689.4		705.3
Total Property, Plant and Equipment		17,969.5		17,781.2
Accumulated Depreciation and Amortization		5,463.4		5,402
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		12,506.1		12,379.2
Other Noncurrent Assets
Regulatory Assets		920.4		1,058.6
Securitized Assets		153.1		159.6
Employee Benefits and Pension Assets		157.4		152.9
Operating Lease Assets		71.2		73.6
Deferred Charges and Other Noncurrent Assets		149.2		138.7
TOTAL OTHER NONCURRENT ASSETS		1,451.3		1,583.4
TOTAL ASSETS		15,256.4		15,222.2
Current Liabilities
Advances from Affiliates		310.2		182.2
Accounts Payable		297.6		451.2
Affiliated Companies		101		142.7
Short-term Debt:
Long-term Debt Due Within One Year		252.3		251.8
Risk Management Liabilities		7		3.6
Customer Deposits		74.2		75.1
Accrued Taxes		112.3		101
Accrued Interest		83.2		57.9
Obligations Under Operating Leases		14.8		15
Other Current Liabilities		97.5		109.7
TOTAL CURRENT LIABILITIES		1,350.1		1,390.2
Noncurrent Liabilities
Long-term Debt		5,146.4		5,158.7
Deferred Income Tax Liabilities, Net		2,006.8		1,992.2
Regulatory Liabilities and Deferred Investment Tax Credits		1,109.5		1,143.6
Asset Retirement Obligations		422.5		419.2
Employee Benefits and Pension Obligations		33.1		34.2
Obligations Under Operating Leases		56.9		59.1
Deferred Credits and Other Noncurrent Liabilities		44.2		49.6
TOTAL NONCURRENT LIABILITIES		8,819.4		8,856.6
TOTAL LIABILITIES		10,169.5		10,246.8
Rate Matters
Commitments and Contingencies
Equity
Common Stock		260.4		260.4
Paid-in Capital		1,828.7		1,828.7
Retained Earnings		3,003.6		2,891.1
Accumulated Other Comprehensive Income (Loss)		(5.8)		(4.8)
TOTAL EQUITY		5,086.9		4,975.4
TOTAL LIABILITIES AND EQUITY		$ 15,256.4		$ 15,222.2
Common Stock, No Par Value		$ 0		$ 0
Common Stock, Shares Authorized		30,000,000		30,000,000
Common Stock, Shares, Outstanding		13,499,500		13,499,500
Indiana Michigan Power Co [Member]
Current Assets
Cash and Cash Equivalents		$ 8.5		$ 4.2
Advances to Affiliates		60		23
Accounts Receivable:
Customers		62.4		96.6
Affiliated Companies - Contracts with Customers		86.6		104
Accrued Unbilled Revenues		0		0.6
Miscellaneous		4.6		4.7
Allowance for Uncollectible Accounts		0		(0.1)
Total Accounts Receivable		153.6		205.8
Fuel		66.5		46.5
Materials and Supplies		192.2		188.1
Risk Management Assets		5.9		15.2
Regulatory Asset for Under-Recovered Fuel Costs		43.3		47.1
Prepayments and Other Current Assets		41.4		41.9
TOTAL CURRENT ASSETS		571.4		571.8
Property, Plant and Equipment
Generation		5,590.1		5,585.1
Transmission		1,861		1,842.2
Distribution		3,054.8		3,024.7
Other Property, Plant and Equipment		813.6		839.3
Construction Work in Progress		288.2		253
Total Property, Plant and Equipment		11,607.7		11,544.3
Accumulated Depreciation and Amortization		4,190.8		4,132.8
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		7,416.9		7,411.5
Other Noncurrent Assets
Regulatory Assets		420.8		459.6
Spent Nuclear Fuel and Decommissioning Trusts		3,501.1		3,341.2
Operating Lease Assets		60.9		64.3
Deferred Charges and Other Noncurrent Assets		271.2		270.5
TOTAL OTHER NONCURRENT ASSETS		4,254		4,135.6
TOTAL ASSETS		12,242.3		12,118.9
Current Liabilities
Advances from Affiliates		0		249.9
Accounts Payable		165.4		173.4
Affiliated Companies		91.8		121.5
Short-term Debt:
Long-term Debt Due Within One Year		86		341.8
Customer Deposits		46.3		48.6
Accrued Taxes		124.3		103.2
Accrued Interest		24.8		36.9
Obligations Under Operating Leases		16.7		16
Other Current Liabilities		79.5		105.8
TOTAL CURRENT LIABILITIES		634.8		1,197.1
Noncurrent Liabilities
Long-term Debt		3,403		2,919
Deferred Income Tax Liabilities, Net		1,162.5		1,157
Regulatory Liabilities and Deferred Investment Tax Credits		1,824		1,702.2
Asset Retirement Obligations		2,046.2		2,027.6
Obligations Under Operating Leases		45.2		48.9
Deferred Credits and Other Noncurrent Liabilities		49.3		58.8
TOTAL NONCURRENT LIABILITIES		8,530.2		7,913.5
TOTAL LIABILITIES		9,165		9,110.6
Rate Matters
Commitments and Contingencies
Equity
Common Stock		56.6		56.6
Paid-in Capital		988.8		988.8
Retained Earnings		2,034.8		1,963.2
Accumulated Other Comprehensive Income (Loss)		(2.9)		(0.3)
TOTAL EQUITY		3,077.3		3,008.3
TOTAL LIABILITIES AND EQUITY		$ 12,242.3		$ 12,118.9
Common Stock, No Par Value		$ 0		$ 0
Common Stock, Shares Authorized		2,500,000		2,500,000
Common Stock, Shares, Outstanding		1,400,000		1,400,000
Indiana Michigan Power Co [Member] | DCC Fuel [Member]
Short-term Debt:
Long-term Debt Due Within One Year		$ 83.8		$ 89.6
Ohio Power Co [Member]
Current Assets
Cash and Cash Equivalents		9.1		9.6
Accounts Receivable:
Customers		104.9		119.9
Affiliated Companies - Contracts with Customers		113.9		100.9
Accrued Unbilled Revenues		30		17.8
Miscellaneous		0.1		0.1
Allowance for Uncollectible Accounts		(0.1)		(0.1)
Total Accounts Receivable		248.8		238.6
Materials and Supplies		110		109.5
Renewable Energy Credits		36.7		35
Prepayments and Other Current Assets		25.6		21.7
TOTAL CURRENT ASSETS		430.2		414.4
Property, Plant and Equipment
Transmission		3,218.7		3,198.6
Distribution		6,535.9		6,450.3
Other Property, Plant and Equipment		1,066.5		1,051.4
Construction Work in Progress		589.1		474.3
Total Property, Plant and Equipment		11,410.2		11,174.6
Accumulated Depreciation and Amortization		2,602.9		2,565.3
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		8,807.3		8,609.3
Other Noncurrent Assets
Regulatory Assets		352.8		327.3
Operating Lease Assets		72.5		73.8
Deferred Charges and Other Noncurrent Assets		489.9		578.3
TOTAL OTHER NONCURRENT ASSETS		915.2		979.4
TOTAL ASSETS		10,152.7		10,003.1
Current Liabilities
Advances from Affiliates		414.6		172.9
Accounts Payable		333.5		337.3
Affiliated Companies		130		126.1
Short-term Debt:
Long-term Debt Due Within One Year		0.1		0.1
Risk Management Liabilities		6		1.8
Customer Deposits		73.8		96.5
Accrued Taxes		573.4		733.1
Obligations Under Operating Leases		13.4		13.5
Other Current Liabilities		145.5		154.2
TOTAL CURRENT LIABILITIES		1,690.3		1,635.5
Noncurrent Liabilities
Long-term Debt		2,970.7		2,970.2
Deferred Income Tax Liabilities, Net		1,109.1		1,101.1
Long-term Risk Management Liabilities		40.9		37.9
Regulatory Liabilities and Deferred Investment Tax Credits		1,014.6		1,044
Obligations Under Operating Leases		59.2		60.3
Deferred Credits and Other Noncurrent Liabilities		51.8		66
TOTAL NONCURRENT LIABILITIES		5,246.3		5,279.5
TOTAL LIABILITIES		6,936.6		6,915
Rate Matters
Commitments and Contingencies
Equity
Common Stock		321.2		321.2
Paid-in Capital		887.8		837.8
Retained Earnings		2,007.1		1,929.1
TOTAL EQUITY		3,216.1		3,088.1
TOTAL LIABILITIES AND EQUITY		$ 10,152.7		$ 10,003.1
Common Stock, No Par Value		$ 0		$ 0
Common Stock, Shares Authorized		40,000,000		40,000,000
Common Stock, Shares, Outstanding		27,952,473		27,952,473
Public Service Co Of Oklahoma [Member]
Current Assets
Cash and Cash Equivalents		$ 3.8		$ 4
Accounts Receivable:
Customers		61.4		70.1
Affiliated Companies - Contracts with Customers		33.5		52.2
Miscellaneous		1		0.8
Total Accounts Receivable		95.9		123.1
Fuel		14.9		11.6
Materials and Supplies		95.9		111.1
Risk Management Assets		9.4		25.3
Accrued Tax Benefits		27.4		16.1
Regulatory Asset for Under-Recovered Fuel Costs		178.7		178.7
Prepayments and Other Current Assets		23.3		21.6
TOTAL CURRENT ASSETS		449.3		491.5
Property, Plant and Equipment
Generation		2,658.9		2,394.8
Transmission		1,171.8		1,164.4
Distribution		3,264.4		3,216.4
Other Property, Plant and Equipment		478.5		469.3
Construction Work in Progress		263.8		219.3
Total Property, Plant and Equipment		7,837.4		7,464.2
Accumulated Depreciation and Amortization		1,973.1		1,837.7
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		5,864.3		5,626.5
Other Noncurrent Assets
Regulatory Assets		609.8		653.7
Employee Benefits and Pension Assets		68.7		67.3
Operating Lease Assets		106.1		106.1
Deferred Charges and Other Noncurrent Assets		66.4		20.8
TOTAL OTHER NONCURRENT ASSETS		851		847.9
TOTAL ASSETS		7,164.6		6,965.9
Current Liabilities
Advances from Affiliates		130.7		364.2
Accounts Payable		155.7		202.9
Affiliated Companies		56.3		76.7
Short-term Debt:
Long-term Debt Due Within One Year		0.5		0.5
Customer Deposits		59.4		59
Accrued Taxes		64.9		28.7
Obligations Under Operating Leases		9.2		8.9
Other Current Liabilities		93.7		101.8
TOTAL CURRENT LIABILITIES		570.4		842.7
Noncurrent Liabilities
Long-term Debt		2,383.1		1,912.3
Deferred Income Tax Liabilities, Net		805.9		788.6
Regulatory Liabilities and Deferred Investment Tax Credits		808.4		809.1
Asset Retirement Obligations		80.3		73.5
Obligations Under Operating Leases		99.1		99.3
Deferred Credits and Other Noncurrent Liabilities		19.6		21.3
TOTAL NONCURRENT LIABILITIES		4,196.4		3,704.1
TOTAL LIABILITIES		4,766.8		4,546.8
Rate Matters
Commitments and Contingencies
Equity
Common Stock		157.2		157.2
Paid-in Capital		1,042.6		1,042.6
Retained Earnings		1,198.2		1,218
Accumulated Other Comprehensive Income (Loss)		(0.2)		1.3
TOTAL EQUITY		2,397.8		2,419.1
TOTAL LIABILITIES AND EQUITY		$ 7,164.6		$ 6,965.9
Common Stock, Shares Authorized		11,000,000		11,000,000
Common Stock, Shares, Outstanding		9,013,000		9,013,000
Common Stock, Par or Stated Value Per Share		$ 15		$ 15
Common Stock, Shares, Issued		10,482,000		10,482,000
Southwestern Electric Power Co [Member]
Current Assets
Cash and Cash Equivalents		$ 8.2		$ 88.4
Advances to Affiliates		2.1		2.1
Accounts Receivable:
Customers		33.9		38.8
Affiliated Companies - Contracts with Customers		38.9		65.4
Miscellaneous		11.9		10.4
Total Accounts Receivable		84.7		114.6
Fuel		90.6		81.3
Materials and Supplies		84.5		92.1
Risk Management Assets		6.3		16.4
Accrued Tax Benefits		33.7		16.5
Regulatory Asset for Under-Recovered Fuel Costs		326.5		353
Prepayments and Other Current Assets		41.9		47.8
TOTAL CURRENT ASSETS		678.5		812.2
Property, Plant and Equipment
Generation		4,870.3		5,476.2
Transmission		2,481.5		2,479.8
Distribution		2,691.1		2,659.6
Other Property, Plant and Equipment		785.7		804.4
Construction Work in Progress		470.4		369.5
Total Property, Plant and Equipment		11,299		11,789.5
Accumulated Depreciation and Amortization		2,956.4		3,527.3
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		8,342.6		8,262.2
Other Noncurrent Assets
Regulatory Assets		1,040.9		1,042.4
Deferred Charges and Other Noncurrent Assets		334.6		262
TOTAL OTHER NONCURRENT ASSETS		1,375.5		1,304.4
TOTAL ASSETS		10,396.6		10,378.8
Current Liabilities
Advances from Affiliates		18.8		310.7
Accounts Payable		188.9		213.1
Affiliated Companies		51.5		81.7
Short-term Debt:
Other Short-term Debt		16		0
Long-term Debt Due Within One Year		0		6.2
Customer Deposits		68.7		65.4
Accrued Taxes		132.3		52.8
Accrued Interest		27.9		36
Obligations Under Operating Leases		8.9		8.4
Asset Retirement Obligations		43.7		43.7
Other Current Liabilities		105.7		129.7
TOTAL CURRENT LIABILITIES		662.4		947.7
Noncurrent Liabilities
Long-term Debt		3,644.8		3,385.4
Deferred Income Tax Liabilities, Net		1,103.7		1,089.7
Regulatory Liabilities and Deferred Investment Tax Credits		776.5		825.7
Asset Retirement Obligations		236.9		237.2
Employee Benefits and Pension Obligations		29.5		29.7
Obligations Under Operating Leases		121.4		120.2
Deferred Credits and Other Noncurrent Liabilities		56.2		68.4
TOTAL NONCURRENT LIABILITIES		5,969		5,756.3
TOTAL LIABILITIES		6,631.4		6,704
Rate Matters
Commitments and Contingencies
Equity
Common Stock		0.1		0.1
Paid-in Capital		1,492.2		1,442.2
Retained Earnings		2,276.6		2,236
Accumulated Other Comprehensive Income (Loss)		(4.1)		(4.2)
TOTAL COMMON SHAREHOLDER'S EQUITY		3,764.8		3,674.1
Noncontrolling Interests		0.4		0.7
TOTAL EQUITY		3,765.2		3,674.8
TOTAL LIABILITIES AND EQUITY		$ 10,396.6		$ 10,378.8
Common Stock, No Par Value		$ 18		$ 18
Common Stock, Shares Authorized		3,680		3,680
Common Stock, Shares, Outstanding		3,680		3,680
Southwestern Electric Power Co [Member] | Sabine Mining Co [Member]
Current Assets
Cash and Cash Equivalents		$ 3.9		$ 84.2
Accounts Receivable:
Fuel		0		14.2
Materials and Supplies		4.2		4.2
Property, Plant and Equipment
Other Property, Plant and Equipment		187.8		219.8
Accumulated Depreciation and Amortization		$ 187.8		$ 212.5
[1]Amount includes Assets Held for Sale on the balance sheet. See “Planned Disposition of the Competitive Contracted Renewables Portfolio” section of Note 6 for additional information.[2]Amount of securitized debt for receivables as accounted for under the “Transfers and Servicing” accounting guidance.

Condensed Consolidated Statem_2

Condensed Consolidated Statements of Cash Flows - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Operating Activities
Net Income (Loss)	$ 400.4	$ 718.1
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	775.5	792.4
Deferred Income Taxes	68	(17.7)
Allowance for Equity Funds Used During Construction	(31.3)	(31)
Mark-to-Market of Risk Management Contracts	(82)	282.3
Property Taxes	(101.6)	(82)
Deferred Fuel Over/Under-Recovery, Net	128	(148.8)
Change in Other Noncurrent Assets	(96)	49.4
Change in Other Noncurrent Liabilities	(58.7)	36.9
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	348.4	(24.3)
Fuel, Materials and Supplies	(115.9)	27.6
Accounts Payable	(255.9)	(1)
Accrued Taxes, Net	(150.9)	(51.8)
Other Current Assets	(94.6)	133.9
Other Current Liabilities	(127.6)	(61.8)
Net Cash Flows from (Used for) Operating Activities	717.8	1,622.2
Investing Activities
Construction Expenditures	(2,090.1)	(1,686.6)
Purchases of Investment Securities	(537.3)	(508.5)
Sales of Investment Securities	517.6	497.4
Acquisitions of Nuclear Fuel	(1.7)	(31.1)
Other Investing Activities	12	42.9
Net Cash Flows from (Used for) Investing Activities	(2,245.2)	(2,893.2)
Financing Activities
Issuance of Common Stock	41.1	809.5
Issuance of Long-term Debt	2,847.3	499.6
Issuance of Short-term Debt with Original Maturities greater than 90 Days	97.4	271
Change in Short-term Debt with Original Maturities less than 90 Days, Net	(433.7)	710.3
Retirement of Long-term Debt	(519.5)	(51)
Redemption of Short-term Debt with Original Maturities Greater than 90 Days	(153.8)	(215)
Principal Payments for Finance Leases Obligations	(26.8)	(14.7)
Dividends Paid on Common Stock	(431.8)	(398.8)
Other Financing Activities	(55.8)	(65.8)
Net Cash Flows from (Used for) Financing Activities	1,364.4	1,545.1
Net Increase (Decrease) in Cash and Cash Equivalents	(163)	274.1
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	556.5	451.4
Cash and Cash Equivalents at Beginning of Period	509.4
Cash, Cash Equivalents and Restricted Cash at End of Period	393.5	725.5
Cash and Cash Equivalents at End of Period	343.5
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	311.9	233.9
Net Cash Paid (Received) for Income Taxes	15.8	6.9
Noncash Acquisitions Under Finance Leases	12.5	7.2
Construction Expenditures Included in Current Liabilities as of March 31,	1,076.1	758.6
Forward Equity Purchase Contract Included in Current and Noncurrent Liabilities as of September 30,	12.5	16.7
Commitment from Bank Conduits to Finance Receivables	125
Commitment from Bank Conduits to Finance Receivables Two	$ 625
2020 Equity Units [Member] | Maximum [Member]
Supplementary Information
AEP Share Price for Equity Unit Conversion	$ 99.95
Retained Earnings [Member]
Supplementary Information
Forward Equity Purchase Contract Included in Current and Noncurrent Liabilities as of September 30,		1.5
Competitive Contracted Renewable Portfolio
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Loss on the Expected Sale of the Competitive Contracted Renewable Portfolio	$ 112	0
Renewable Energy Facilities
Investing Activities
Acquisitions of Assets	(145.7)	(1,207.3)
AEP Texas Inc. [Member]
Operating Activities
Net Income (Loss)	47.6	69.6
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	111	108.8
Deferred Income Taxes	6.4	7
Allowance for Equity Funds Used During Construction	(6.3)	(4.3)
Mark-to-Market of Risk Management Contracts	0.4	(0.2)
Property Taxes	(88.8)	(79.5)
Change in Other Noncurrent Assets	(18.3)	(17)
Change in Other Noncurrent Liabilities	(0.8)	5.8
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	24.6	(20.2)
Fuel, Materials and Supplies	(1.1)	(4.9)
Accounts Payable	3.6	9.6
Accrued Taxes, Net	44.5	37.9
Other Current Assets	0.9	0.8
Other Current Liabilities	13	16.5
Net Cash Flows from (Used for) Operating Activities	136.7	129.9
Investing Activities
Construction Expenditures	(450.4)	(356.6)
Change in Advances to Affiliates, Net	0.1	0.1
Other Investing Activities	7.3	13.7
Net Cash Flows from (Used for) Investing Activities	(443)	(342.8)
Financing Activities
Capital Contributions from Parent	100	0
Change in Advances from Affiliates, Net	354.3	235.3
Retirement of Long-term Debt	(136.7)	(11.4)
Principal Payments for Finance Leases Obligations	(1.8)	(1.7)
Other Financing Activities	0.3	0.2
Net Cash Flows from (Used for) Financing Activities	316.1	222.4
Net Increase (Decrease) in Cash and Cash Equivalents	9.8	9.5
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	32.8	30.5
Cash and Cash Equivalents at Beginning of Period	0.1
Cash, Cash Equivalents and Restricted Cash at End of Period	42.6	40
Cash and Cash Equivalents at End of Period	0.1
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	31.6	29.9
Noncash Acquisitions Under Finance Leases	1.8	0.6
Construction Expenditures Included in Current Liabilities as of March 31,	177.5	147.6
AEP Texas Inc. [Member] | Retained Earnings [Member]
Operating Activities
Net Income (Loss)	47.6	69.6
AEP Transmission Co [Member]
Operating Activities
Net Income (Loss)	162.7	155.4
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	95.2	83.1
Deferred Income Taxes	20.6	23.1
Allowance for Equity Funds Used During Construction	(16.4)	(15.6)
Property Taxes	34.6	31.3
Provision for Refund Affiliated	4.8	0.3
Change in Other Noncurrent Assets	0.9	2.1
Change in Other Noncurrent Liabilities	6.6	11.8
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(12.5)	(21.8)
Fuel, Materials and Supplies	(4.1)	(0.8)
Accounts Payable	41	3.6
Accrued Taxes, Net	(59.9)	(53.7)
Other Current Assets	1	0.5
Other Current Liabilities	29.6	19.8
Net Cash Flows from (Used for) Operating Activities	299.3	238.8
Investing Activities
Construction Expenditures	(439.7)	(417.1)
Change in Advances to Affiliates, Net	(293.1)	22.6
Other Investing Activities	(0.8)	(1.7)
Net Cash Flows from (Used for) Investing Activities	(733.6)	(396.2)
Financing Activities
Capital Contributions from Parent	25	0
Issuance of Long-term Debt	689.2	0
Change in Advances from Affiliates, Net	(224.9)	197.4
Dividends Paid on Common Stock	(55)	(40)
Net Cash Flows from (Used for) Financing Activities	434.3	157.4
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	16.2	16.4
Construction Expenditures Included in Current Liabilities as of March 31,	305.4	214.6
AEP Transmission Co [Member] | Retained Earnings [Member]
Operating Activities
Net Income (Loss)	162.7	155.4
Financing Activities
Dividends Paid on Common Stock	(55)	(40)
Appalachian Power Co [Member]
Operating Activities
Net Income (Loss)	112.5	120.2
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	143	145.2
Deferred Income Taxes	10.3	4.1
Allowance for Equity Funds Used During Construction	(2.4)	(2)
Mark-to-Market of Risk Management Contracts	60.1	34.3
Deferred Fuel Over/Under-Recovery, Net	26	(100.3)
Change in Other Noncurrent Assets	(5.5)	1.4
Change in Other Noncurrent Liabilities	(33)	(20.4)
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	54.5	72.4
Fuel, Materials and Supplies	(59.3)	19.5
Increase (Decrease) in Margin Deposits Outstanding	(11.1)	61.4
Accounts Payable	(156.1)	33.6
Accrued Taxes, Net	23.6	26.1
Other Current Assets	2.9	2.3
Other Current Liabilities	(1.2)	18.3
Net Cash Flows from (Used for) Operating Activities	164.3	416.1
Investing Activities
Construction Expenditures	(287.4)	(233.9)
Change in Advances to Affiliates, Net	1.1	1.1
Other Investing Activities	1.5	9.7
Net Cash Flows from (Used for) Investing Activities	(284.8)	(223.1)
Financing Activities
Change in Advances from Affiliates, Net	128	(163.8)
Retirement of Long-term Debt	(13)	(12.7)
Principal Payments for Finance Leases Obligations	(2)	(2)
Dividends Paid on Common Stock	0	(18.8)
Other Financing Activities	0.2	0.2
Net Cash Flows from (Used for) Financing Activities	113.2	(197.1)
Net Increase (Decrease) in Cash and Cash Equivalents	(7.3)	(4.1)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	21.9	20.1
Cash and Cash Equivalents at Beginning of Period	7.5
Cash, Cash Equivalents and Restricted Cash at End of Period	14.6	16
Cash and Cash Equivalents at End of Period	7.1
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	37.9	21
Noncash Acquisitions Under Finance Leases	0.6	0.3
Construction Expenditures Included in Current Liabilities as of March 31,	122.6	94.9
Appalachian Power Co [Member] | Retained Earnings [Member]
Operating Activities
Net Income (Loss)	112.5	120.2
Indiana Michigan Power Co [Member]
Operating Activities
Net Income (Loss)	102.8	89.5
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	125.2	134.9
Deferred Income Taxes	(3.3)	(11.5)
Amortization (Deferral) of Incremental Nuclear Refueling Outage Expenses, Net	18.1	(6.5)
Allowance for Equity Funds Used During Construction	(0.5)	(2.9)
Mark-to-Market of Risk Management Contracts	8.8	(2.8)
Amortization of Nuclear Fuel	25	22.9
Deferred Fuel Over/Under-Recovery, Net	3.8	6.1
Change in Other Noncurrent Assets	(4.3)	(5.2)
Change in Other Noncurrent Liabilities	3.7	2.4
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	52.7	25.9
Fuel, Materials and Supplies	(24.1)	6.3
Accounts Payable	(27.8)	3.8
Accrued Taxes, Net	21.1	22.3
Other Current Assets	(1.9)	15.3
Other Current Liabilities	(41.8)	(53.6)
Net Cash Flows from (Used for) Operating Activities	257.5	246.9
Investing Activities
Construction Expenditures	(141.7)	(129.9)
Change in Advances to Affiliates, Net	(37)	0
Purchases of Investment Securities	(536.3)	(507.7)
Sales of Investment Securities	517.6	493.5
Acquisitions of Nuclear Fuel	(1.7)	(31.1)
Other Investing Activities	3.3	0.3
Net Cash Flows from (Used for) Investing Activities	(195.8)	(174.9)
Financing Activities
Issuance of Long-term Debt	499.8	0
Change in Advances from Affiliates, Net	(249.9)	(19.7)
Retirement of Long-term Debt	(274.3)	(23.8)
Principal Payments for Finance Leases Obligations	(1.9)	(1.6)
Dividends Paid on Common Stock	(31.2)	(25)
Other Financing Activities	0.1	0.1
Net Cash Flows from (Used for) Financing Activities	(57.4)	(70)
Net Increase (Decrease) in Cash and Cash Equivalents	4.3	2
Cash and Cash Equivalents at Beginning of Period	4.2	1.3
Cash and Cash Equivalents at End of Period	8.5	3.3
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	44.4	41.6
Net Cash Paid (Received) for Income Taxes	2.4	0
Noncash Acquisitions Under Finance Leases	2.2	0.3
Construction Expenditures Included in Current Liabilities as of March 31,	61.3	60.7
Indiana Michigan Power Co [Member] | Retained Earnings [Member]
Operating Activities
Net Income (Loss)	102.8	89.5
Ohio Power Co [Member]
Operating Activities
Net Income (Loss)	78	83.2
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	75.2	74.9
Deferred Income Taxes	2.1	9.5
Carrying Costs Income	0	(0.1)
Allowance for Equity Funds Used During Construction	(2.8)	(3)
Mark-to-Market of Risk Management Contracts	7.2	(24)
Property Taxes	92	87
Change in Other Noncurrent Assets	(43.2)	(1.2)
Change in Other Noncurrent Liabilities	(21.7)	11
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(20.3)	(28.8)
Fuel, Materials and Supplies	(4.8)	(5)
Accounts Payable	(5.5)	4
Increase (Decrease) in Contract with Customer, Liability	(22.7)	24.1
Accrued Taxes, Net	(157.9)	(158.3)
Other Current Assets	(2.2)	13.5
Other Current Liabilities	(7.7)	20.3
Net Cash Flows from (Used for) Operating Activities	(34.3)	107.2
Investing Activities
Construction Expenditures	(262)	(188.7)
Change in Advances to Affiliates, Net	0	42
Other Investing Activities	4.9	4.2
Net Cash Flows from (Used for) Investing Activities	(257.1)	(142.5)
Financing Activities
Capital Contributions from Parent	50	0
Change in Advances from Affiliates, Net	241.7	55.7
Principal Payments for Finance Leases Obligations	(1.2)	(1.2)
Dividends Paid on Common Stock	0	(15)
Other Financing Activities	0.4	0.2
Net Cash Flows from (Used for) Financing Activities	290.9	39.7
Net Increase (Decrease) in Cash and Cash Equivalents	(0.5)	4.4
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	9.6	3
Cash and Cash Equivalents at Beginning of Period	9.6
Cash, Cash Equivalents and Restricted Cash at End of Period	9.1	7.4
Cash and Cash Equivalents at End of Period	9.1
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	20.9	19.5
Noncash Acquisitions Under Finance Leases	0.6	0.6
Construction Expenditures Included in Current Liabilities as of March 31,	109.9	67
Ohio Power Co [Member] | Retained Earnings [Member]
Operating Activities
Net Income (Loss)	78	83.2
Public Service Co Of Oklahoma [Member]
Operating Activities
Net Income (Loss)	(2.3)	5.8
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	61.1	52.7
Deferred Income Taxes	12.2	(17.4)
Allowance for Equity Funds Used During Construction	(1.5)	(1.1)
Mark-to-Market of Risk Management Contracts	13.9	1.8
Property Taxes	(45.6)	(37.8)
Deferred Fuel Over/Under-Recovery, Net	49.4	(26.4)
Change in Other Noncurrent Assets	(9.7)	(3.9)
Change in Other Noncurrent Liabilities	1.4	6.2
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	27.2	11.5
Fuel, Materials and Supplies	12.9	0
Accounts Payable	(62.8)	(20.8)
Accrued Taxes, Net	24.9	45.2
Other Current Assets	0.4	1.9
Other Current Liabilities	(7.5)	(1.8)
Net Cash Flows from (Used for) Operating Activities	74	15.9
Investing Activities
Construction Expenditures	(146.8)	(104.1)
Acquisitions of Assets	(146)
Other Investing Activities	0.4	0.4
Net Cash Flows from (Used for) Investing Activities	(292.1)	(653)
Financing Activities
Issuance of Long-term Debt	469.9	500
Change in Advances from Affiliates, Net	(233.5)	139.5
Retirement of Long-term Debt	(0.1)	(0.1)
Principal Payments for Finance Leases Obligations	(0.8)	(0.8)
Dividends Paid on Common Stock	(17.5)	0
Other Financing Activities	(0.1)	0.1
Net Cash Flows from (Used for) Financing Activities	217.9	638.7
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect	(0.2)	1.6
Cash and Cash Equivalents at Beginning of Period	4	1.3
Cash and Cash Equivalents at End of Period	3.8	2.9
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	22.3	21.3
Noncash Acquisitions Under Finance Leases	0.2	0.3
Construction Expenditures Included in Current Liabilities as of March 31,	63.4	37.1
Public Service Co Of Oklahoma [Member] | Retained Earnings [Member]
Operating Activities
Net Income (Loss)	(2.3)	5.8
Public Service Co Of Oklahoma [Member] | Renewable Energy Facilities
Investing Activities
Acquisitions of Assets	(145.7)	(549.3)
Southwestern Electric Power Co [Member]
Operating Activities
Net Income (Loss)	41.8	45.1
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	80.4	77.8
Deferred Income Taxes	10.8	(9.5)
Allowance for Equity Funds Used During Construction	(0.5)	(1.6)
Mark-to-Market of Risk Management Contracts	9.9	(7)
Property Taxes	(77.5)	(64.5)
Deferred Fuel Over/Under-Recovery, Net	42.9	9.2
Change in Other Noncurrent Assets	7.2	29.9
Change in Other Noncurrent Liabilities	(3.3)	16.7
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	29.9	7.6
Fuel, Materials and Supplies	(4.3)	(0.6)
Accounts Payable	(47.8)	(35.1)
Accrued Taxes, Net	62.3	75.7
Other Current Assets	7.3	3.8
Other Current Liabilities	(48.9)	(56.7)
Net Cash Flows from (Used for) Operating Activities	110.2	90.8
Investing Activities
Construction Expenditures	(201.9)	(129.5)
Change in Advances to Affiliates, Net	0	153.8
Acquisitions of Assets	0	658
Other Investing Activities	0.4	1.9
Net Cash Flows from (Used for) Investing Activities	(201.5)	(631.8)
Financing Activities
Capital Contributions from Parent	50	350
Issuance of Long-term Debt	347.3	0
Change in Short-term Debt with Original Maturities less than 90 Days, Net	16	0
Change in Advances from Affiliates, Net	(291.9)	202.9
Retirement of Long-term Debt	(94.1)	(1.6)
Principal Payments for Finance Leases Obligations	(14.8)	(2.7)
Dividends Paid on Common Stock	(1.5)	(0.8)
Other Financing Activities	0.1	0.1
Net Cash Flows from (Used for) Financing Activities	11.1	547.9
Net Increase (Decrease) in Cash and Cash Equivalents	(80.2)	6.9
Cash and Cash Equivalents at Beginning of Period	88.4	51.2
Cash and Cash Equivalents at End of Period	8.2	58.1
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	45.3	37.7
Noncash Acquisitions Under Finance Leases	0.9	1
Construction Expenditures Included in Current Liabilities as of March 31,	$ 113.3	$ 47.8

Significant Accounting Matters

Significant Accounting Matters	3 Months Ended
	Mar. 31, 2023
Significant Accounting Matters	SIGNIFICANT ACCOUNTING MATTERS The disclosures in this note apply to all Registrants unless indicated otherwise. General The unaudited condensed financial statements and footnotes were prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X of the SEC. Accordingly, they do not include all of the information and footnotes required by GAAP for complete annual financial statements. In the opinion of management, the unaudited condensed interim financial statements reflect all normal and recurring accruals and adjustments necessary for a fair statement of the net income, financial position and cash flows for the interim periods for each Registrant. Net income for the three months ended March 31, 2023 is not necessarily indicative of results that may be expected for the year ending December 31, 2023. The condensed financial statements are unaudited and should be read in conjunction with the audited 2022 financial statements and notes thereto, which are included in the Registrants’ Annual Reports on Form 10-K as filed with the SEC on February 23, 2023. Earnings Per Share (EPS) (Applies to AEP) Basic EPS is calculated by dividing net earnings available to common shareholders by the weighted-average number of common shares outstanding during the period. Diluted EPS is calculated by adjusting the weighted-average outstanding common shares, assuming conversion of all potentially dilutive stock awards. The following table presents AEP’s basic and diluted EPS calculations included on the statements of income: Three Months Ended March 31, 2023 2022 (in millions, except per share data) $/share $/share Earnings Attributable to AEP Common Shareholders $ 397.0 $ 714.7 Weighted-Average Number of Basic AEP Common Shares Outstanding 514.2 $ 0.77 506.1 $ 1.41 Weighted-Average Dilutive Effect of Stock-Based Awards 1.4 — 1.6 — Weighted-Average Number of Diluted AEP Common Shares Outstanding 515.6 $ 0.77 507.7 $ 1.41 Equity Units are potentially dilutive securities and were excluded from the calculation of diluted EPS for the three months ended March 31, 2023 and 2022, as the dilutive stock price threshold was not met. See Note 12 - Financing Activities for more information related to Equity Units. There were no antidilutive shares outstanding as of March 31, 2023 and 2022, respectively. Restricted Cash (Applies to AEP, AEP Texas and APCo) Restricted Cash primarily includes funds held by trustees for the payment of securitization bonds. Reconciliation of Cash, Cash Equivalents and Restricted Cash The following tables provide a reconciliation of Cash, Cash Equivalents and Restricted Cash reported within the balance sheets that sum to the total of the same amounts shown on the statements of cash flows: March 31, 2023 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 343.5 $ 0.1 $ 7.1 Restricted Cash 50.0 42.5 7.5 Total Cash, Cash Equivalents and Restricted Cash $ 393.5 $ 42.6 $ 14.6 December 31, 2022 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 509.4 $ 0.1 $ 7.5 Restricted Cash 47.1 32.7 14.4 Total Cash, Cash Equivalents and Restricted Cash $ 556.5 $ 32.8 $ 21.9

New Accounting Standards

New Accounting Standards	3 Months Ended
	Mar. 31, 2023
New Accounting Standards	NEW ACCOUNTING STANDARDS The disclosures in this note apply to all Registrants unless indicated otherwise. During the FASB’s standard-setting process and upon issuance of final standards, management reviews the new accounting literature to determine its relevance, if any, to the Registrants’ business. There are no new standards expected to have a material impact on the Registrants’ financial statements.

Comprehensive Income

Comprehensive Income	3 Months Ended
	Mar. 31, 2023
Comprehensive Income	COMPREHENSIVE INCOME The disclosures in this note apply to all Registrants except AEPTCo and OPCo. Presentation of Comprehensive Income The following tables provide the components of changes in AOCI and details of reclassifications from AOCI. The amortization of pension and OPEB AOCI components are included in the computation of net periodic pension and OPEB costs. See Note 7 - Benefit Plans for additional information. AEP Cash Flow Hedges Pension Three Months Ended 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 for Resale (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) Cash Flow Hedges Pension Three Months Ended March 31, 2022 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2021 $ 163.7 $ (21.3) $ 42.4 $ 184.8 Change in Fair Value Recognized in AOCI, Net of Tax 278.2 6.8 — 285.0 Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (a) (0.1) — — (0.1) Purchased Electricity for Resale (a) (47.9) — — (47.9) Interest Expense (a) — 1.1 — 1.1 Amortization of Prior Service Cost (Credit) — — (4.9) (4.9) Amortization of Actuarial (Gains) Losses — — 2.1 2.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit (48.0) 1.1 (2.8) (49.7) Income Tax (Expense) Benefit (10.1) 0.2 (0.6) (10.5) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (37.9) 0.9 (2.2) (39.2) Net Current Period Other Comprehensive Income (Loss) 240.3 7.7 (2.2) 245.8 Balance in AOCI as of March 31, 2022 $ 404.0 $ (13.6) $ 40.2 $ 430.6 AEP Texas Cash Flow Hedge – Pension Three Months Ended March 31, 2023 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2022 $ (0.3) $ (8.3) $ (8.6) Change in Fair Value Recognized in AOCI, Net of Tax (0.2) (0.5) (0.7) Amount of (Gain) Loss Reclassified from AOCI Interest Expense (a) 0.3 — 0.3 Amortization of Prior Service Cost (Credit) — (0.1) (0.1) Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.3 (0.1) 0.2 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.2 (0.1) 0.1 Net Current Period Other Comprehensive Income (Loss) — (0.6) (0.6) Balance in AOCI as of March 31, 2023 $ (0.3) $ (8.9) $ (9.2) Cash Flow Hedge – Pension Three Months Ended March 31, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2021 $ (1.3) $ (5.2) $ (6.5) Change in Fair Value Recognized in AOCI, Net of Tax — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (a) 0.4 — 0.4 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.4 — 0.4 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.3 — 0.3 Net Current Period Other Comprehensive Income (Loss) 0.3 — 0.3 Balance in AOCI as of March 31, 2022 $ (1.0) $ (5.2) $ (6.2) APCo Cash Flow Hedge – Pension Three Months Ended March 31, 2023 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2022 $ 6.7 $ (11.5) $ (4.8) Change in Fair Value Recognized in AOCI, Net of Tax — (0.1) (0.1) Amount of (Gain) Loss Reclassified from AOCI Interest Expense (a) (0.3) — (0.3) Amortization of Prior Service Cost (Credit) — (1.2) (1.2) Amortization of Actuarial (Gains) Losses — 0.3 0.3 Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.3) (0.9) (1.2) Income Tax (Expense) Benefit (0.1) (0.2) (0.3) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.2) (0.7) (0.9) Net Current Period Other Comprehensive Income (Loss) (0.2) (0.8) (1.0) Balance in AOCI as of March 31, 2023 $ 6.5 $ (12.3) $ (5.8) Cash Flow Hedge – Pension Three Months Ended March 31, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2021 $ 7.5 $ 16.9 $ 24.4 Change in Fair Value Recognized in AOCI, Net of Tax — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (a) (0.3) — (0.3) Amortization of Prior Service Cost (Credit) — (1.4) (1.4) Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.3) (1.4) (1.7) Income Tax (Expense) Benefit (0.1) (0.3) (0.4) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.2) (1.1) (1.3) Net Current Period Other Comprehensive Income (Loss) (0.2) (1.1) (1.3) Balance in AOCI as of March 31, 2022 $ 7.3 $ 15.8 $ 23.1 I&M Cash Flow Hedge – Pension Three Months Ended March 31, 2023 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2022 $ (5.1) $ 4.8 $ (0.3) Change in Fair Value Recognized in AOCI, Net of Tax (1.1) (1.7) (2.8) Amount of (Gain) Loss Reclassified from AOCI Interest Expense (a) 0.5 — 0.5 Amortization of Prior Service Cost (Credit) — (0.3) (0.3) Amortization of Actuarial (Gains) Losses — 0.1 0.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.5 (0.2) 0.3 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.4 (0.2) 0.2 Net Current Period Other Comprehensive Income (Loss) (0.7) (1.9) (2.6) Balance in AOCI as of March 31, 2023 $ (5.8) $ 2.9 $ (2.9) Cash Flow Hedge – Pension Three Months Ended March 31, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2021 $ (6.7) $ 5.4 $ (1.3) Change in Fair Value Recognized in AOCI, Net of Tax — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (a) 0.5 — 0.5 Amortization of Prior Service Cost (Credit) — (0.2) (0.2) Amortization of Actuarial (Gains) Losses — 0.1 0.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.5 (0.1) 0.4 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.4 (0.1) 0.3 Net Current Period Other Comprehensive Income (Loss) 0.4 (0.1) 0.3 Balance in AOCI as of March 31, 2022 $ (6.3) $ 5.3 $ (1.0) PSO Cash Flow Hedge – Three Months Ended March 31, 2023 Interest Rate (in millions) Balance in AOCI as of December 31, 2022 $ 1.3 Change in Fair Value Recognized in AOCI, Net of Tax (1.5) Amount of (Gain) Loss Reclassified from AOCI Interest Expense (a) — Reclassifications from AOCI, before Income Tax (Expense) Benefit — Income Tax (Expense) Benefit — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit — Net Current Period Other Comprehensive Income (Loss) (1.5) Balance in AOCI as of March 31, 2023 $ (0.2) Cash Flow Hedge – Three Months Ended March 31, 2022 Interest Rate (in millions) Balance in AOCI as of December 31, 2021 $ — Change in Fair Value Recognized in AOCI, Net of Tax — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (a) — Reclassifications from AOCI, before Income Tax (Expense) Benefit — Income Tax (Expense) Benefit — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit — Net Current Period Other Comprehensive Income (Loss) — Balance in AOCI as of March 31, 2022 $ — SWEPCo Cash Flow Hedge – Pension Three Months Ended March 31, 2023 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2022 $ 1.1 $ (5.3) $ (4.2) Change in Fair Value Recognized in AOCI, Net of Tax 0.5 — 0.5 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (a) (0.1) — (0.1) Amortization of Prior Service Cost (Credit) — (0.5) (0.5) Amortization of Actuarial (Gains) Losses — 0.1 0.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.1) (0.4) (0.5) Income Tax (Expense) Benefit — (0.1) (0.1) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.1) (0.3) (0.4) Net Current Period Other Comprehensive Income (Loss) 0.4 (0.3) 0.1 Balance in AOCI as of March 31, 2023 $ 1.5 $ (5.6) $ (4.1) Cash Flow Hedge – Pension Three Months Ended March 31, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2021 $ 1.2 $ 5.5 $ 6.7 Change in Fair Value Recognized in AOCI, Net of Tax — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (a) 0.1 — 0.1 Amortization of Prior Service Cost (Credit) — (0.5) (0.5) Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.1 (0.5) (0.4) Income Tax (Expense) Benefit — (0.1) (0.1) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.1 (0.4) (0.3) Net Current Period Other Comprehensive Income (Loss) 0.1 (0.4) (0.3) Balance in AOCI as of March 31, 2022 $ 1.3 $ 5.1 $ 6.4 (a) Amounts reclassified to the referenced line item on the statements of income.

Rate Matters

Rate Matters	3 Months Ended
	Mar. 31, 2023
Rate Matters	RATE MATTERS The disclosures in this note apply to all Registrants unless indicated otherwise. As discussed in the 2022 Annual Report, the Registrants are involved in rate and regulatory proceedings at the FERC and their state commissions. The Rate Matters note within the 2022 Annual Report should be read in conjunction with this report to gain a complete understanding of material rate matters still pending that could impact net income, cash flows and possibly financial condition. The following discusses ratemaking developments in 2023 and updates the 2022 Annual Report. Coal-Fired Generation Plants (Applies to AEP, PSO and SWEPCo) Compliance with extensive environmental regulations requires significant capital investment in environmental monitoring, installation of pollution control equipment, emission fees, disposal costs and permits. Management continuously evaluates cost estimates of complying with these regulations which has resulted in, and in the future may result in, a decision to retire coal-fired generating facilities earlier than their currently estimated useful lives. Management is seeking or will seek regulatory recovery, as necessary, for any net book value remaining when the plants are retired. To the extent the net book value of these generation assets is not deemed recoverable, it could materially reduce future net income and cash flows and impact financial condition. Regulated Generating Units that have been Retired SWEPCo In December 2021, the Dolet Hills Power Station was retired. As part of the 2020 Texas Base Rate Case, the PUCT authorized recovery of SWEPCo’s Texas jurisdictional share of the Dolet Hills Power Station through 2046, but denied SWEPCo the ability to earn a return on this investment resulting in a disallowance of $12 million in 2021. As part of the 2021 Arkansas Base Rate Case, the APSC authorized recovery of SWEPCo’s Arkansas jurisdictional share of the Dolet Hills Power Station through 2027, but denied SWEPCo the ability to earn a return on this investment resulting in a disallowance of $2 million in the second quarter of 2022. Also, the APSC did not rule on the prudency of the early retirement of the Dolet Hills Power Station, which will be addressed in a future proceeding. As part of the 2020 Louisiana Base Rate Case, the LPSC authorized the recovery of SWEPCo’s Louisiana share of the Dolet Hills Power Station, through a separate rider, through 2032, but did not rule on the prudency of the early retirement of the plant, which is being addressed in a separate proceeding. See “2020 Texas Base Rate Case” and “2020 Louisiana Base Rate Case” sections below for additional information. In March 2023, the Pirkey Plant was retired. As part of the 2020 Louisiana Base Rate Case, the LPSC authorized the recovery of SWEPCo’s Louisiana jurisdictional share of the Pirkey Plant, through a separate rider, through 2032. As part of the 2021 Arkansas Base Rate Case, the APSC granted SWEPCo regulatory asset treatment. SWEPCo will request recovery including a weighted average cost of capital carrying charge through a future proceeding. The Texas jurisdictional share of the Pirkey Plant will be addressed in SWEPCo’s next base rate case. Regulated Generating Units to be Retired PSO In 2014, PSO received final approval from the Federal EPA to close Northeastern Plant, Unit 3, in 2026. The plant was originally scheduled to close in 2040. As a result of the early retirement date, PSO revised the useful life of Northeastern Plant, Unit 3, to the projected retirement date of 2026 and the incremental depreciation is being deferred as a regulatory asset. As part of the 2021 Oklahoma Base Rate Case, PSO will continue to recover Northeastern Plant, Unit 3 through 2040. SWEPCo In November 2020, management announced that it will cease using coal at the Welsh Plant in 2028. As a result of the announcement, SWEPCo began recording a regulatory asset for accelerated depreciation. The table below summarizes the net book value including CWIP, before cost of removal and materials and supplies, as of March 31, 2023, of generating facilities planned for early retirement: Plant Net Book Value Accelerated Depreciation Regulatory Asset Cost of Removal Projected Current Authorized Annual (dollars in millions) Northeastern Plant, Unit 3 $ 128.5 $ 150.3 $ 20.3 (b) 2026 (c) $ 14.9 Welsh Plant, Units 1 and 3 399.6 95.5 58.1 (d) 2028 (e) 38.3 (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) 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, 2023, SWEPCo’s share of the net investment in the Dolet Hills Power Station was $110 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, 2023, SWEPCo had a net under-recovered fuel balance of $233 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 $33 million of additional costs with a recovery period to be determined at a later date. In August 2022, the LPSC staff filed testimony recommending fuel disallowances of $72 million, including denial of recovery of the $33 million deferral, with refunds to customers over five years. In September 2022, SWEPCo filed rebuttal testimony addressing the LPSC staff recommendations. In March 2021, the APSC approved fuel rates that provide recovery of $20 million for the Arkansas share of the 2021 Dolet Hills Power Station fuel costs over five years through the existing fuel clause. In August 2022, SWEPCo filed a fuel reconciliation with the PUCT covering the fuel period of January 1, 2020 through December 31, 2021. Intervenors submitted testimony and SWEPCo filed rebuttal testimony in the first quarter of 2023, and a decision from the PUCT is expected in the third quarter of 2023. If any of these costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. Pirkey Plant and Related Fuel Operations (Applies to AEP and SWEPCo) In March 2023, the Pirkey Plant was retired. SWEPCo is recovering, or will seek recovery of, the remaining net book value of Pirkey Plant non-fuel costs. As of March 31, 2023, SWEPCo’s share of the net investment in the Pirkey Plant was $177 million, including materials and supplies, net of cost of removal. See the “Regulated Generating Units that have been Retired” section above for additional information. Fuel costs are recovered through active fuel clauses and are subject to prudency determinations by the various commissions. As of March 31, 2023, SWEPCo fuel deliveries, including billings of all fixed costs, from Sabine ceased. Additionally, as of March 31, 2023, SWEPCo had a net under-recovered fuel balance of $233 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. If any of these costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. Regulatory Assets Pending Final Regulatory Approval (Applies to all Registrants except AEPTCo) AEP March 31, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Unrecovered Winter Storm Fuel Costs (a) $ 115.9 $ 121.7 Welsh Plant, Units 1 and 3 Accelerated Depreciation 95.5 85.6 Pirkey Plant Accelerated Depreciation 111.8 116.5 Dolet Hills Power Station Fuel Costs - Louisiana 33.3 32.0 Texas Mobile Generation Lease Payments 24.6 17.6 Other Regulatory Assets Pending Final Regulatory Approval 21.4 19.3 Regulatory Assets Currently Not Earning a Return Storm-Related Costs (b)(c) 265.1 407.2 2020-2022 Virginia Triennial Under-Earnings 37.9 37.9 Plant Retirement Costs – Asset Retirement Obligation Costs 25.9 25.9 Other Regulatory Assets Pending Final Regulatory Approval 43.1 55.6 Total Regulatory Assets Pending Final Regulatory Approval $ 774.5 $ 919.3 (a) Includes $37 million and $37 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of March 31, 2023 and December 31, 2022, respectively. See the “February 2021 Severe Winter Weather Impacts in SPP” section below for additional information. (b) In April 2023, OPCo filed a request with the PUCO for recovery of $34 million in Ohio storm-related costs. (c) In April 2023, the LPSC issued an order approving the prudence and future recovery of the Louisiana storm-related costs. See “2021 Louisiana Storm Cost Filing” section below for additional information. AEP Texas March 31, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Texas Mobile Generation Lease Payments $ 24.6 $ 17.6 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 28.9 26.7 Vegetation Management Program 5.2 5.2 Texas Retail Electric Provider Bad Debt Expense 4.1 4.1 Other Regulatory Assets Pending Final Regulatory Approval 13.5 13.4 Total Regulatory Assets Pending Final Regulatory Approval $ 76.3 $ 67.0 APCo March 31, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return COVID-19 – Virginia $ 7.1 $ 7.0 Regulatory Assets Currently Not Earning a Return Storm-Related Costs - West Virginia 72.1 72.6 2020-2022 Virginia Triennial Under-Earnings 37.9 37.9 Plant Retirement Costs – Asset Retirement Obligation Costs 25.9 25.9 Other Regulatory Assets Pending Final Regulatory Approval 0.6 1.1 Total Regulatory Assets Pending Final Regulatory Approval $ 143.6 $ 144.5 I&M March 31, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Other Regulatory Assets Pending Final Regulatory Approval $ 0.1 $ 0.1 Regulatory Assets Currently Not Earning a Return Storm-Related Costs - Indiana 23.0 21.6 Other Regulatory Assets Pending Final Regulatory Approval 2.2 2.0 Total Regulatory Assets Pending Final Regulatory Approval $ 25.3 $ 23.7 OPCo March 31, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Not Earning a Return Storm-Related Costs (a) $ 36.3 $ 33.8 Total Regulatory Assets Pending Final Regulatory Approval $ 36.3 $ 33.8 (a) In April 2023, OPCo filed a request with the PUCO for recovery of $34 million in storm costs. PSO March 31, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Not Earning a Return Storm-Related Costs $ 29.2 $ 25.5 Other Regulatory Assets Pending Final Regulatory Approval 0.1 0.1 Total Regulatory Assets Pending Final Regulatory Approval $ 29.3 $ 25.6 . SWEPCo March 31, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Unrecovered Winter Storm Fuel Costs (a) $ 115.9 $ 121.7 Welsh Plant, Units 1 and 3 Accelerated Depreciation 95.5 85.6 Pirkey Plant Accelerated Depreciation 111.8 116.5 Dolet Hills Power Station Fuel Costs - Louisiana 33.3 32.0 Dolet Hills Power Station 12.1 9.7 Other Regulatory Assets Pending Final Regulatory Approval 2.1 2.5 Regulatory Assets Currently Not Earning a Return Storm-Related Costs - Louisiana (b) — 151.5 Asset Retirement Obligation - Louisiana — 11.8 Other Regulatory Assets Pending Final Regulatory Approval 15.4 16.0 Total Regulatory Assets Pending Final Regulatory Approval $ 386.1 $ 547.3 (a) Includes $37 million and $37 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of March 31, 2023 and December 31, 2022, respectively. See the “February 2021 Severe Winter Weather Impacts in SPP” section below for additional information. (b) In April 2023, the LPSC issued an order approving the prudence and future recovery of the Louisiana storm-related costs. See “2021 Louisiana Storm Cost Filing” section below for additional information. 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, 2023, AEP Texas’ cumulative revenues from interim base rate increases that are subject to review is approximately $702 million. A base rate review could result in a refund to customers if AEP Texas incurs a disallowance of the transmission or distribution investment on which an interim increase was based. Management is unable to determine a range of potential losses, if any, that are reasonably possible of occurring. A revenue decrease, including a refund of interim transmission and distribution rates, could reduce future net income and cash flows and impact financial condition. AEP Texas is required to file for a comprehensive rate review no later than April 5, 2024. APCo and WPCo Rate Matters (Applies to AEP and APCo) 2020-2022 Virginia Triennial Review In March 2023, APCo submitted its 2020-2022 Virginia triennial review filing and base rate case with the Virginia SCC as required by state law. APCo requested a $213 million annual increase in Virginia base rates based upon a proposed 10.6% return on common equity. The requested annual increase includes $47 million related to vegetation management and a $35 million increase in depreciation expense. The requested increase in depreciation expense reflects, among other things, the impacts of incremental investments made since APCo’s last depreciation study using property balances as of December 31, 2022. Effective January 1, 2023 and in accordance with past Virginia SCC directives, APCo implemented updated Virginia depreciation rates. APCo’s proposed revenue requirement also includes the recovery of certain costs incurred that partially contributed to APCo’s calculated earnings shortfall for the 2020-2022 triennial period. For triennial review periods in which a Virginia utility earns below its authorized ROE band, the utility may file to recover expenses incurred, up to the bottom of the authorized ROE band, related to certain categories of costs, including major storm costs for severe weather events. As of March 31, 2023, APCo deferred approximately $38 million related to previously incurred major storm costs as a result of APCo’s calculation of Virginia earnings below the bottom of its authorized ROE band during the 2020-2022 Triennial Review period. Any APCo Virginia jurisdictional costs that are not recoverable or any refunds of revenues collected from customers during the triennial review period that are ordered by the Virginia SCC for the 2020-2022 Triennial Review period could reduce future net income and cash flows and impact financial condition. ENEC (Expanded Net Energy Cost) Filings In April 2021, APCo and WPCo (the Companies) requested a combined $73 million annual increase in ENEC rates based on a cumulative $55 million ENEC under-recovery as of February 28, 2021 and an $18 million increase in projected ENEC costs for the period September 2021 through August 2022. In September 2021, the WVPSC issued an order approving a $7 million overall increase in ENEC rates, including an approval for recovery of the Companies’ cumulative $55 million ENEC under-recovery balance and a $48 million reduction in projected costs for the period September 2021 through August 2022. Subsequently, the Companies submitted a request for reconsideration of this order, identifying flaws in the WVPSC’s calculation of forecasted future year fuel expense and purchased power costs. In March 2022, the WVPSC issued an order granting the Companies’ request for reconsideration, in part, and approving $31 million in projected costs for the period September 2021 through August 2022. The order also reopened the 2021 ENEC case to require the Companies to explain the significant growth in the reported under-recovery of ENEC costs and to provide various other information including revised projected costs for the period March 2022 through August 2022. Also, in March 2022, the Companies filed testimony providing the information requested in the WVPSC’s order and requested a $155 million annual increase in ENEC rates effective May 1, 2022. In May 2022, the WVPSC issued an order approving a $93 million overall increase to ENEC rates to recover projected annual ENEC costs. However, the WVPSC stated that actual and projected ENEC costs are still subject to a prudency review. In April 2022, the Companies submitted their 2022 annual ENEC filing with the WVPSC requesting a $297 million annual increase in ENEC revenues, inclusive of the previously requested $155 million increase, effective September 1, 2022. In September 2022, following an agreed upon delay in the proceedings of the Companies’ 2022 ENEC case, certain intervenors submitted testimony recommending disallowances of at least $83 million to the Companies’ historical period ENEC under-recovery balance along with proposals to either securitize the Companies’ remaining ENEC balance or defer recovery of this balance beyond the traditional one-year period. West Virginia Staff recommended a $13 million increase in ENEC rates pending the outcome of the ENEC prudency review. In February 2023, the WVPSC issued an order stating that the commission will not grant additional rate increases for fuel costs until the WVPSC staff completes its prudency review. In April 2023, the Companies submitted their 2023 annual ENEC filing with the WVPSC, proposing two alternatives to increase ENEC rates effective September 1, 2023. The first alternative is a $293 million annual increase in ENEC rates comprised of an $89 million increase for current year ENEC expense and a $200 million annual increase for the recovery of the Companies’ February 28, 2023 ENEC under-recovery balances over three years, including debt and equity carrying costs. The second alternative is an $89 million annual increase in ENEC rates with the Companies securitizing approximately $1.9 billion of assets, including: (a) $553 million relating to ENEC under-recoveries as of February 28, 2023, (b) $88 million relating to major storm expense deferrals and (c) $1.2 billion relating to APCo’s West Virginia jurisdictional book values of the Amos and Mountaineer Plants and forecasted CCR and ELG investments at these generating facilities. The Companies continue to reflect ENEC under-recovery balances as current on their balance sheets since management cannot assert whether the WVPSC will approve recovery of ENEC under-recovery balances over a time frame different from the traditional one-year period. Additionally, in April 2023, the Staff submitted the prudency review prepared by an independent consultant retained by the WVPSC Staff of the Companies’ operation of the Amos, Mountaineer and Mitchell coal plants that Staff was directed to conduct by the WVPSC in May 2022 (Consultant’s Report). The Consultant’s Report states the opinion of the consultant that the Companies acted imprudently by not taking steps to achieve a 69% capacity factor at their coal-fired plants and recommends applying a disallowance factor of 52.9% to the Companies’ cumulative, September 30, 2022 ENEC under-recovery balance of approximately $430 million. The Consultant’s Report further states the consultant’s opinion that this disallowance factor could also be utilized in future ENEC filings. Adoption of the Consultant’s Report’s findings by the WVPSC could result in a disallowance of up to $285 million of the Companies’ cumulative, March 31, 2023 ENEC under-recovery balance of approximately $539 million. The Companies disagree with the conclusions and recommendations contained in the Consultant’s Report and intend to dispute them in the appropriate proceedings before the WVPSC. If any deferred ENEC costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. ETT Rate Matters (Applies to AEP) ETT Interim Transmission Rates AEP has a 50% equity ownership interest in ETT. Predominantly all of ETT’s revenues are based on interim rate changes that can be filed twice annually and are subject to review and possible true-up in the next base rate proceeding. Through March 31, 2023, AEP’s share of ETT’s cumulative revenues that are subject to review is approximately $1.6 billion. A base rate review could produce a refund if ETT incurs a disallowance of the transmission investment on which an interim increase was based. A revenue decrease, including a refund of interim transmission rates, could reduce future net income and cash flows and impact financial condition. Management is unable to determine a range of potential losses, if any, that are reasonably possible of occurring. ETT is required to file for a comprehensive rate review no later than February 1, 2025, during which the $1.6 billion of cumulative revenues above will be subject to review. I&M Rate Matters (Applies to AEP and I&M) Michigan Power Supply Cost Recovery (PSCR) In April 2023, I&M received intervenor testimony in I&M’s 2021 PSCR Reconciliation for the 12-month period ending December 31, 2021 recommending disallowances of purchased power costs of $18 million associated with the OVEC Inter-Company Power Agreement (ICPA) and the AEGCo Unit Power Agreement (UPA) that were alleged to be above market in applying the MPSC’s Code of Conduct rules. Michigan Staff submitted testimony in I&M’s 2021 PSCR Reconciliation with no recommended disallowances for PSCR costs incurred, including those associated with the OVEC ICPA and the AEGCo UPA. An MPSC order on I&M’s 2021 PSCR Reconciliation is expected in 2023. If any PSCR costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. OPCo Rate Matters (Applies to AEP and OPCo) OVEC Cost Recovery Audits In December 2021, as part of OVEC cost recovery audits pending before the PUCO, intervenors filed positions claiming that costs incurred by OPCo during the 2018-2019 audit period were imprudent and should be disallowed. In May 2022, intervenors filed for rehearing on the 2016-2017 OVEC cost recovery audit period claiming the PUCO’s April 2022 order to adopt the findings of the audit report were unjust, unlawful and unreasonable for multiple reasons, including the position that OPCo recovered imprudently incurred costs. In June 2022, the PUCO granted rehearing on the 2016-2017 audit period for purposes of further consideration. Management disagrees with these claims and is unable to predict the impact of these disputes, however, if any costs are disallowed or refunds are ordered it could reduce future net income and cash flows and impact financial condition. See "OVEC" section of Note 17 in the 2022 Annual Report for additional information on AEP and OPCo’s investment in OVEC. Ohio ESP Filings In January 2023, OPCo filed an application with the PUCO to approve an ESP that included proposed rate adjustments, proposed new riders and the continuation and modification of certain existing riders, including the DIR, effective June 2024 through May 2030. The proposal includes a return on common equity of 10.65% on capital costs for certain riders. Intervenor testimony is due in the second quarter of 2023 and a hearing is scheduled for the third quarter of 2023. If OPCo is ultimately not permitted to fully collect its ESP rates it could reduce future net income and cash flows and impact financial condition. PSO Rate Matters (Applies to AEP and PSO) 2022 Oklahoma Base Rate Case In November 2022, PSO filed a request with the OCC for a $173 million annual increase in rates based upon a 10.4% ROE with a capital structure of 45.4% debt and 54.6% common equity, net of existing rider revenues and certain incremental renewable facility benefits expected to be provided to customers through riders. The requested annual revenue increase includes a $47 million annual depreciation expense increase related to the accelerated depreciation recovery of the Northeastern Plant, Unit 3 through 2026, and a $16 million annual amortization expense increase to recover intangible plant over a 5-year useful life instead of a 10-year useful life. PSO’s request also includes recovery of the 154 MW Rock Falls Wind Facility through base rates to aid PSO’s near-term capacity needs and support compliance with SPP’s 2023 increased capacity planning reserve margin requirements. In 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. PSO closed on the acquisition and placed the Rock Falls Wind Facility in-service on March 31, 2023. In addition, PSO requested an annual formula based rate tariff, with an initial one-year pilot term. In the event the requested formula based rate tariff is denied, PSO has requested an expanded rider to recover certain distribution investments and related expenses as well as an expanded transmission cost recovery rider. In March 2023, OCC staff and various intervenors filed testimony supporting net annual revenue changes ranging from a $42 million net decrease to a $49 million net increase based upon ROEs ranging from 8.6% to 9.5%. The difference between PSO’s request and OCC staff and intervenor testimony is primarily due to: (a) rejection of PSO’s request to accelerate the recovery of Northeastern Plant, Unit 3 from its original retirement date of 2040 to its projected retirement date of 2026, (b) rejection of PSO’s request to recover intangible plant over a 5-year useful life instead of a 10-year useful life, (c) recommended disallowance of approximately $9 million in certain distribution plant investments, (d) opposition to inclusion of the Rock Falls Wind Facility revenue requirement in customer rates before PSO’s next base rate case, (e) opposition to PSO’s inclusion of its deferred tax asset associated with net operating loss on a stand-alone tax basis in rate base and (f) lower recommended ROEs and recommendations to use certain hypothetical capital structures. Parties also recommended that the OCC reject PSO’s requested formula based rate, and alternate requests for expanded distribution investment and transmission cost recovery riders. A hearing is scheduled for May 2023. PSO expects to implement interim rates subject to refund starting with the June 2023 billing cycle. A final order is expected in the third quarter of 2023. If any of these costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. SWEPCo Rate Matters (Applies to AEP and SWEPCo) 2012 Texas Base Rate Case In 2012, SWEPCo filed a request with the PUCT to increase annual base rates primarily due to the completion of the Turk Plant. In 2013, the PUCT issued an order affirming the prudence of the Turk Plant but determined that the Turk Plant’s Texas jurisdictional capital cost cap established in a previous Certificate of Convenience and Necessity case also limited SWEPCo’s recovery of AFUDC in addition to limits on its recovery of cash construction costs. Upon rehearing in 2014, the PUCT reversed its initial ruling and determined that AFUDC was excluded from the Turk Plant’s Texas jurisdictional capital cost cap. As a result, SWEPCo reversed $114 million of a previously recorded regulatory disallowance in 2013. In 2017, the Texas District Court upheld the PUCT’s 2014 order and intervenors filed appeals with the Texas Third Court of Appeals. In July 2018, the Texas Third Court of Appeals reversed the PUCT’s judgment affirming the prudence of the Turk Plant and remanded the issue back to the PUCT. In January 2019, SWEPCo and the PUCT filed petitions for review with the Texas Supreme Court. In March 2021, the Texas Supreme Court issued an opinion reversing the July 2018 judgment of the Texas Third Court of Appeals and agreeing with the PUCT’s judgment affirming the prudence of the Turk Plant. In addition, the Texas Supreme Court remanded the AFUDC dispute back to the Texas Third Court of Appeals. No parties filed a motion for rehearing with the Texas Supreme Court. In August 2021, the Texas Third Court of Appeals reversed the Texas District Court judgment affirming the PUCT’s order on AFUDC, concluding that the language of the PUCT’s original 2008 order intended to include AFUDC in the Texas jurisdictional capital cost cap, and remanded the case to the PUCT for future proceedings. SWEPCo disagrees with the Court of Appeals decision. SWEPCo and the PUCT submitted Petitions for Review with the Texas Supreme Court in November 2021. In October 2022, the Texas Supreme Court denied the Petitions for Review submitted by SWEPCo and the PUCT. In December 2022, SWEPCo and the PUCT filed requests for rehearing with the Texas Supreme Court. In April 2023, SWEPCo and the PUCT filed replies to parties’ responses to the requests for rehearing. If SWEPCo’s request for rehearing is denied, the case will be remanded to the PUCT for future proceedings. Management does not believe a disallowance of capitalized Turk Plant costs or a revenue refund is probable as of March 31, 2023. However, if SWEPCo is ultimately unable to recover AFUDC in excess of the Texas jurisdictional capital cost cap, it would be expected to result in a pretax net disallowance ranging from $80 million to $90 million. In addition, if AFUDC is ultimately determined to be included in the Texas jurisdictional capital cost cap, SWEPCo estimates it may be required to make customer refunds ranging from $0 to $190 million related to revenues collected from February 2013 through March 2023 and such determination may reduce SWEPCo’s future revenues by approximately $15 million on an annual basis. 2016 Texas Base Rate Case In 2016, SWEPCo filed a request with the PUCT for a net increase in Texas annual revenues of $69 million based upon a 10% ROE. In January 2018, the PUCT issued a final order approving a net increase in Texas annual revenues of $50 million based upon a ROE of 9.6%, effective May 2017. The final order also included: (a) approval to recover the Texas jurisdictional share of environmental investments placed in-service, as of June 30, 2016, at various plants, including Welsh Plant, Units 1 and 3, (b) approval of recovery of, but no return on, the Texas jurisdictional share of the net book value of Welsh Plant, Unit 2, (c) approval of $2 million in additional vegetation management expenses and (d) the rejection of SWEPCo’s proposed transmission cost recovery mechanism. As a result of the final order, in 2017 SWEPCo: (a) recorded an impairment charge of $19 million, which included $7 million associated with the lack of return on Welsh Plant, Unit 2 and $12 million related to other disallowed plant investments, (b) recognized $32 million of additional revenues, for the period of May 2017 through December 2017, that was surcharged to customers in 2018 and (c) recognized an additional $7 million of expenses consisting primarily of depreciation expense and veget

Commitments, Guarantees and Con

Commitments, Guarantees and Contingencies	3 Months Ended
	Mar. 31, 2023
Commitments, Guarantees and Contingencies	COMMITMENTS, GUARANTEES AND CONTINGENCIES The disclosures in this note apply to all Registrants unless indicated otherwise. The Registrants are subject to certain claims and legal actions arising in the ordinary course of business. In addition, the Registrants’ business activities are subject to extensive governmental regulation related to public health and the environment. The ultimate outcome of such pending or potential litigation against the Registrants cannot be predicted. Management accrues contingent liabilities only when management concludes that it is both probable that a liability has been incurred at the date of the financial statements and the amount of loss can be reasonably estimated. When management determines that it is not probable, but rather reasonably possible that a liability has been incurred at the date of the financial statements, management discloses such contingencies and the possible loss or range of loss if such estimate can be made. Any estimated range is based on currently available information and involves elements of judgment and significant uncertainties. Any estimated range of possible loss may not represent the maximum possible loss exposure. Circumstances change over time and actual results may vary significantly from estimates. For current proceedings not specifically discussed below, management does not anticipate that the liabilities, if any, arising from such proceedings would have a material effect on the financial statements. The Commitments, Guarantees and Contingencies note within the 2022 Annual Report should be read in conjunction with this report. GUARANTEES Liabilities for guarantees are recorded in accordance with the accounting guidance for “Guarantees.” There is no collateral held in relation to any guarantees. In the event any guarantee is drawn, there is no recourse to third-parties unless specified below. Letters of Credit (Applies to AEP and AEP Texas) Standby letters of credit are entered into with third-parties. These letters of credit are issued in the ordinary course of business and cover items such as natural gas and electricity risk management contracts, construction contracts, insurance programs, security deposits and debt service reserves. AEP has $4 billion and $1 billion revolving credit facilities due in March 2027 and 2025, respectively, under which up to $1.2 billion may be issued as letters of credit on behalf of subsidiaries. As of March 31, 2023, no letters of credit were issued under the revolving credit facility. An uncommitted facility gives the issuer of the facility the right to accept or decline each request made under the facility. AEP issues letters of credit on behalf of subsidiaries under six uncommitted facilities totaling $450 million. The Registrants’ maximum future payments for letters of credit issued under the uncommitted facilities as of March 31, 2023 were as follows: Company Amount Maturity (in millions) AEP $ 299.0 April 2023 to March 2024 AEP Texas 1.8 July 2023 Guarantees of Equity Method Investees (Applies to AEP) Parent has issued guarantees over the performance of certain non-consolidated joint ventures included within the competitive contracted renewables portfolio and NM Renewable Development, LLC. If a joint venture were to default on payments or performance, Parent would be required to make payments on behalf of the joint venture. As of March 31, 2023, the maximum potential amount of future payments associated with the remaining guarantees was $78 million, with the last guarantee expiring in December 2045. The non-contingent liability recorded associated with these guarantees was $5 million, with an additional $1 million expected credit loss liability for the contingent portion of the guarantees. In accordance with the accounting guidance for guarantees, the initial recognition of the non-contingent liabilities increased AEP’s carrying values of the respective equity method investees. Management considered historical losses, economic conditions and reasonable and supportable forecasts in the calculation of the expected credit loss. As the joint ventures generate cash flows through PPAs, the measurement of the contingent portion of the guarantee liability is based upon assessments of the credit quality and default probabilities of the respective PPA counterparties. Indemnifications and Other Guarantees Contracts The Registrants enter into certain types of contracts which require indemnifications. Typically these contracts include, but are not limited to, sale agreements, lease agreements, purchase agreements and financing agreements. Generally, these agreements may include, but are not limited to, indemnifications around certain tax, contractual and environmental matters. With respect to sale agreements, exposure generally does not exceed the sale price. As of March 31, 2023, there were no material liabilities recorded for any indemnifications. AEPSC conducts power purchase-and-sale activity on behalf of APCo, I&M, KPCo and WPCo, who are jointly and severally liable for activity conducted on their behalf. AEPSC also conducts power purchase-and-sale activity on behalf of PSO and SWEPCo, who are jointly and severally liable for activity conducted on their behalf. Master Lease Agreements (Applies to all Registrants except AEPTCo) The Registrants lease certain equipment under master lease agreements. Under the lease agreements, the lessor is guaranteed a residual value up to a stated percentage of the equipment cost at the end of the lease term. If the actual fair value of the leased equipment is below the guaranteed residual value at the end of the lease term, the Registrants are committed to pay the difference between the actual fair value and the residual value guarantee. Historically, at the end of the lease term the fair value has been in excess of the amount guaranteed. As of March 31, 2023, the maximum potential loss by the Registrants for these lease agreements assuming the fair value of the equipment is zero at the end of the lease term was as follows: Company Maximum (in millions) AEP $ 46.4 AEP Texas 11.2 APCo 6.0 I&M 4.3 OPCo 7.4 PSO 4.9 SWEPCo 5.7 ENVIRONMENTAL CONTINGENCIES (Applies to all Registrants except AEPTCo) The Comprehensive Environmental Response Compensation and Liability Act (Superfund) and State Remediation By-products from the generation of electricity include materials such as ash, slag, sludge, low-level radioactive waste and SNF. Coal combustion by-products, which constitute the overwhelming percentage of these materials, are typically treated and deposited in captive disposal facilities or are beneficially utilized. In addition, the generation plants and transmission and distribution facilities have used asbestos, polychlorinated biphenyls and other hazardous and non-hazardous materials. The Registrants currently incur costs to dispose of these substances safely. For remediation processes not specifically discussed, management does not anticipate that the liabilities, if any, arising from such remediation processes would have a material effect on the financial statements. NUCLEAR CONTINGENCIES (Applies to AEP and I&M) I&M owns and operates the Cook Plant under licenses granted by the Nuclear Regulatory Commission. I&M has a significant future financial commitment to dispose of SNF and to safely decommission and decontaminate the plant. The licenses to operate the two nuclear units at the Cook Plant expire in 2034 and 2037. The operation of a nuclear facility also involves special risks, potential liabilities and specific regulatory and safety requirements. By agreement, I&M is partially liable, together with all other electric utility companies that own nuclear generation units, for a nuclear power plant incident at any nuclear plant in the U.S. Should a nuclear incident occur at any nuclear power plant in the U.S., the resultant liability could be substantial. OPERATIONAL CONTINGENCIES Litigation Related to Ohio House Bill 6 (HB 6) In 2019, Ohio adopted and implemented HB 6 which benefits OPCo by authorizing rate recovery for certain costs including renewable energy contracts and OVEC’s coal-fired generating units. OPCo engaged in lobbying efforts and provided testimony during the legislative process in connection with HB 6. In July 2020, an investigation led by the U.S. Attorney’s Office resulted in a federal grand jury indictment of an Ohio legislator and associates in connection with an alleged racketeering conspiracy involving the adoption of HB 6. After AEP learned of the criminal allegations against the Ohio legislator and others relating to HB 6, AEP, with assistance from outside advisors, conducted a review of the circumstances surrounding the passage of the bill. Management does not believe that AEP was involved in any wrongful conduct in connection with the passage of HB 6. In August 2020, an AEP shareholder filed a putative class action lawsuit in the U. S. District Court for the Southern District of Ohio against AEP and certain of its officers for alleged violations of securities laws. In December 2021, the district court issued an opinion and order dismissing the securities litigation complaint with prejudice, determining that the complaint failed to plead any actionable misrepresentations or omissions. The plaintiffs did not appeal the ruling. In January 2021, an AEP shareholder filed a derivative action in the U.S. District Court for the Southern District of Ohio purporting to assert claims on behalf of AEP against certain AEP officers and directors. In February 2021, a second AEP shareholder filed a similar derivative action in the Court of Common Pleas of Franklin County, Ohio. In April 2021, a third AEP shareholder filed a similar derivative action in the U.S. District Court for the Southern District of Ohio and a fourth AEP shareholder filed a similar derivative action in the Supreme Court for the State of New York, Nassau County. These derivative complaints allege the officers and directors made misrepresentations and omissions similar to those alleged in the putative securities class action lawsuit filed against AEP. The derivative complaints together assert claims for: (a) breach of fiduciary duty, (b) waste of corporate assets, (c) unjust enrichment, (d) breach of duty for insider trading and (e) contribution for violations of sections 10(b) and 21D of the Securities Exchange Act of 1934; and seek monetary damages and changes to AEP’s corporate governance and internal policies among other forms of relief. The court entered a scheduling order in the New York state court derivative action staying the case other than with respect to briefing the motion to dismiss. AEP filed substantive and forum-based motions to dismiss on April 29, 2022. On September 13, 2022, the New York state court granted the forum-based motion to dismiss with prejudice and the plaintiff subsequently filed a notice of appeal with the New York appellate court. On January 20, 2023, the New York plaintiff filed a motion to intervene in the pending Ohio federal court action and withdrew his appeal in New York. The two derivative actions pending in federal district court in Ohio have been consolidated and the plaintiffs in the consolidated action filed an amended complaint. AEP filed a motion to dismiss the amended complaint and subsequently filed a brief in opposition to the New York plaintiffs’ motion to intervene in the consolidated action in Ohio. On March 20, 2023, the federal district court issued an order granting the motion to dismiss with prejudice and denying the New York plaintiffs’ motion to intervene. On April 20, 2023, one of the plaintiffs filed a notice of appeal to the U.S. Court of Appeals for the Sixth Circuit of the Ohio federal district court order dismissing the consolidated action and denying the intervention. On June 15, 2022, the Ohio state court entered an order continuing the stays of that case until the final resolution of the consolidated derivative actions pending in Ohio federal district court. The defendants will continue to defend against the claims. Management is unable to determine a range of potential losses that is reasonably possible of occurring. In March 2021, AEP received a litigation demand letter from counsel representing a purported AEP shareholder. The litigation demand letter was directed to the Board of Directors of AEP (AEP Board) and contained factual allegations involving HB 6 that were generally consistent with those in the derivative litigation filed in state and federal court. The shareholder that sent the letter has since withdrawn the litigation demand, which is now terminated and of no further effect. In April 2023, AEP received a litigation demand from counsel representing the purported AEP shareholder who filed the dismissed derivative action in New York state court and unsuccessfully tried to intervene in the consolidated derivative actions in Ohio federal court. The litigation demand letter is directed to the AEP Board and contains factual allegations involving HB6 that are generally consistent with those in the derivative litigation filed in state and federal court. The letter demands, among other things, that the AEP Board undertake an independent investigation into alleged legal violations by certain current and former directors and officers, and that AEP commence a civil action for breaches of fiduciary duty and related claims against any individuals who allegedly harmed AEP. The AEP Board will act in response to the letter as appropriate. Management is unable to determine a range of potential losses that is reasonably possible of occurring. In May 2021, AEP received a subpoena from the SEC’s Division of Enforcement seeking various documents, including documents relating to the passage of HB 6 and documents relating to AEP’s policies and financial processes and controls. In August 2022, AEP received a second subpoena from the SEC seeking various additional documents relating to its ongoing investigation. AEP is cooperating fully with the SEC’s investigation, which has included taking testimony from certain individuals. Although the outcome of the SEC’s investigation cannot be predicted, management does not believe the results of this investigation will have a material impact on financial condition, results of operations or cash flows. Claims for Indemnification Related to Damages Resulting from the Federal EPA’s Denial of Alternative Closure Deadline for Gavin Plant and Associated Findings of Compliance In November 2022, the Federal EPA issued a final decision denying Gavin Power LLC’s requested extension to allow a CCR surface impoundment at the Gavin Power Station to continue to receive CCR and non-CCR waste streams after April 11, 2021 until May 4, 2023 (the Gavin Denial). As part of the Gavin Denial, the Federal EPA made several determinations related to the CCR Rule (see “Environmental Issues - Coal Combustion Residual (CCR) Rule” section of Management’s Discussion and Analysis of Financial Condition and Results of Operations for additional information), including a determination that the closure of the 300 acre unlined fly ash reservoir (FAR) is noncompliant with the CCR Rule in multiple respects. The Gavin Power Station was formerly owned and operated by AEP and was sold to Gavin Power LLC and Lightstone Generation LLC in 2017. Pursuant to the PSA, AEP maintained responsibility to complete closure of the FAR in accordance with the closure plan approved by the Ohio EPA which was completed in July 2021. The PSA contains indemnification provisions, pursuant to which the owners of the Gavin Power Station have notified AEP they believe they are entitled to indemnification for any damages that may result from the Gavin Denial, as well as any future enforcement or litigation resulting from the Federal EPA’s determinations of noncompliance with various aspects of the CCR Rule as part of the Gavin Denial. Management does not believe that the owners of the Gavin Power Station have any valid claim for indemnity or otherwise against AEP under the PSA. In addition, Gavin Power LLC, several AEP subsidiaries, and other parties have filed Petitions for Review of the Gavin Denial with the U.S. Court of Appeals for the District of Columbia Circuit. Management is unable to determine a range of potential losses that is reasonably possible of occurring. Claims for Damages Related to Sabine Coal Supply Contract In April 2023, AEP received a letter from North American Coal Corporation (NACC) alleging that SWEPCo breached it’s coal supply contract with Sabine, a subsidiary of NACC. The letter contends that SWEPCo is obligated to run the Pirkey Plant until 2035 or to pay $85 million in damages representing lost mining fees to Sabine. The letter threatens legal action for unspecified injunctive relief and breach of contract. Management does not believe SWEPCo is obligated to run the Pirkey Plant for any period of time beyond its useful life or that there is a valid claim for breach of contract or damages. 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
	Mar. 31, 2023
Acquisitions and Dispositions	ACQUISITIONS AND ASSETS AND LIABILITIES HELD FOR SALE The disclosures in this note apply to AEP unless indicated otherwise. ACQUISITIONS North Central Wind Energy Facilities (Vertically Integrated Utilities Segment) (Applies to AEP, PSO and SWEPCo) In 2020, PSO and SWEPCo received regulatory approvals to acquire the NCWF, comprised of three Oklahoma wind facilities totaling 1,484 MWs, on a fixed cost turn-key basis. PSO and SWEPCo own undivided interests of 45.5% and 54.5% of the NCWF, respectively. In total, the three wind facilities cost approximately $2 billion and consist of Traverse (998 MW), Maverick (287 MW) and Sundance (199 MW). Output from the NCWF serves retail load in PSO’s Oklahoma service territory and both retail and FERC wholesale load in SWEPCo’s service territories in Arkansas and Louisiana. The Oklahoma and Louisiana portions of the NCWF revenue requirement, net of PTC benefit, are recoverable through authorized riders until the amounts are reflected in base rates. Recovery of the Arkansas portion of the NCWF revenue requirement through base rates was approved by the APSC in May 2022. The NCWF are subject to various regulatory performance requirements. If these performance requirements are not met, PSO and SWEPCo would recognize a regulatory liability to refund retail customers. In March 2022, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Traverse during its development and construction for $1.2 billion, the third of the three NCWF acquisitions. Immediately following the acquisition, PSO and SWEPCo liquidated the entity and simultaneously distributed the Traverse assets in proportion to their undivided ownership interests. Traverse was placed in-service in March 2022. PSO and SWEPCo apply the joint plant accounting model to account for their respective undivided interests in the assets, liabilities, revenues and expenses of the NCWF projects. Rock Falls Wind Facility (Vertically Integrated Utilities Segment) (Applies to AEP and PSO) In November 2022, PSO entered into an agreement to acquire the Rock Falls Wind Facility. In February 2023, the FERC approved PSO’s acquisition of the Rock Falls Wind Facility under Section 203 of the Federal Power Act. In March 2023, PSO acquired an ownership interest in the entity that owned Rock Falls during its development and construction for $146 million. In accordance with the guidance for “Business Combinations,” management determined that the acquisition of the Rock Falls Wind Facility represents an asset acquisition. The current and noncurrent Obligations Under Operating Leases related to Rock Falls were not material as of March 31, 2023. See the “2022 Oklahoma Base Rate Case” section of Note 4 for additional information. ASSETS AND LIABILITIES HELD FOR SALE Termination of Planned Disposition of KPCo and KTCo (Vertically Integrated Utilities and AEP Transmission Holdco Segments) (Applies to AEP and AEPTCo) In October 2021, AEP entered into a Stock Purchase Agreement (SPA) to sell KPCo and KTCo to Liberty Utilities Co., a subsidiary of Algonquin Power & Utilities Corp. (Liberty), for approximately a $2.85 billion enterprise value. The SPA was subsequently amended in September 2022 to reduce the purchase price to approximately $2.646 billion. The sale required approval from the KPSC and from the FERC under Section 203 of the Federal Power Act. The SPA contained certain termination rights if the closing of the sale did not occur by April 26, 2023. In May 2022, the KPSC approved the sale of KPCo to Liberty subject to certain conditions contingent upon the closing of the sale. In December 2022, the FERC issued an order denying, without prejudice, authorization of the proposed sale stating the applicants failed to demonstrate the proposed transaction will not have an adverse effect on rates. In February 2023, a new filing for approval under Section 203 of the Federal Power Act was submitted. In March 2023, the KPSC and other intervenors made filings recommending the FERC reject AEP and Liberty’s new Section 203 application seeking approval of the sale. In April 2023, AEP, AEPTCo and Liberty entered into a Mutual Termination Agreement (Termination Agreement) terminating the SPA. The parties entered into the Termination Agreement as all of the conditions precedent to closing the sale could not be satisfied prior to April 26, 2023. As a result of the March 2023 filings made by intervenors with the FERC and the Termination Agreement, the assets and liabilities of KPCo and KTCo were reclassified out of Held for Sale on the March 31, 2023 and December 31, 2022 balance sheets of AEP and AEPTCo. The impact of the Termination Agreement did not have a material impact on AEP’s statements of income for the three months ended March 31, 2023. Upon reverting to a held and used model, AEP is required to present its investment in the Kentucky Operations at the lower of fair value or historical carrying value. As a result, AEP’s March 31, 2023 and December 31, 2022 balance sheets reflect a $335 million and $363 million, respectively, pretax reduction in the basis of its investment in KPCo’s assets which is recorded in Property, Plant and Equipment. The change in AEP’s basis of its investment in KPCo’s assets from December 31, 2022 to March 31, 2023 reflects the elimination of the expected costs to sell from the measurement. Planned Disposition of the Competitive Contracted Renewables Portfolio (Generation & Marketing Segment) (Applies to AEP) In February 2022, AEP management announced the initiation of a process to sell all or a portion of AEP Renewables’ competitive contracted renewables portfolio within the Generation & Marketing segment. As of March 31, 2023, the competitive contracted renewable portfolio assets totaled 1.4 gigawatts of generation resources representing consolidated solar and wind assets, with a net book value of $1.2 billion, and a 50% interest in four joint venture wind farms, totaling $247 million, accounted for as equity method investments. In late January 2023, AEP received final bids from interested parties. In February 2023, AEP’s Board of Directors approved management’s plan to sell the competitive contracted renewables portfolio and AEP signed an agreement to sell the competitive contracted renewables portfolio to a nonaffiliated party for $1.5 billion including the assumption of project debt. As part of the sale agreement, AEP provided the acquirer an indemnification related to certain losses, not to exceed $70 million, which could result from one of the joint venture wind farm’s inability to meet certain minimum performance requirements. The sale is subject to customary closing conditions, including FERC approval, clearance from the Committee on Foreign Investment in the United States and approval under applicable competition laws. AEP expects to close on the sale in the second quarter of 2023 and receive cash proceeds, net of taxes, transaction fees and other customary closing adjustments, of approximately $1.2 billion. Management concluded the consolidated assets within the competitive contracted renewables portfolio met the accounting requirements to be presented as Held for Sale in the first quarter of 2023 based on the receipt of final bids, Board of Director approval to consummate a sale transaction and the signing of the sale agreement. AEP recorded a pretax loss of $112 million ($88 million after-tax), in the first quarter of 2023 as a result of reaching Held for Sale status. Management concluded the impact of any other than temporary decline in the fair value of the four joint venture wind farms was not material to AEP’s March 31, 2023 financial statements. Any changes to the book value or carrying value of these assets, or the anticipated sale price, could further reduce future net income and impact financial condition. The Income Before Income Tax Expense (Benefit) of the competitive contracted renewables portfolio was not material to AEP on its statements of income for the three months ended March 31, 2023 and 2022. In March 2023, AEP ceased recognition of depreciation on the competitive contracted renewable portfolio assets due to their classification as Held for Sale on the balance sheets. The major classes of the assets and liabilities presented in Assets Held for Sale and Liabilities Held for Sale on the balance sheets of AEP are shown in the following table: March 31, 2023 (in millions) ASSETS Accounts Receivable and Accrued Unbilled Revenues $ 16.9 Property, Plant and Equipment, Net 1,404.7 Other Classes of Assets that are not Major 63.2 Total Major Classes of Assets Held for Sale 1,484.8 Loss on the Expected Sale of the Competitive Contracted Renewables Portfolio (net of $23.5 million of Income Taxes) (88.5) Assets Held for Sale $ 1,396.3 LIABILITIES Accounts Payable $ 6.8 Asset Retirement Obligations 30.6 Obligations Under Operating Leases 20.1 Other Classes of Liabilities that are not Major 9.7 Liabilities Held for Sale $ 67.2 The four joint venture wind farms totaling $247 million as of March 31, 2023, which are included in the plan of sale, continue to be classified as Deferred Charges and Other Noncurrent Assets and $192 million attributable to noncontrolling interests continues to be classified as Noncontrolling Interests on AEP’s consolidated balance sheets.

Benefit Plans

Benefit Plans	3 Months Ended
	Mar. 31, 2023
Benefit Plans	BENEFIT PLANS The disclosures in this note apply to all Registrants except AEPTCo. AEP sponsors a qualified pension plan and two unfunded nonqualified pension plans. Substantially all AEP employees are covered by the qualified plan or both the qualified and a nonqualified pension plan. AEP also sponsors OPEB plans to provide health and life insurance benefits for retired employees. Components of Net Periodic Benefit Cost The following tables provide the components of net periodic benefit cost (credit) by Registrant for the plans: AEP Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2023 2022 2023 2022 (in millions) Service Cost $ 23.6 $ 30.8 $ 1.1 $ 1.8 Interest Cost 54.8 37.0 11.6 7.3 Expected Return on Plan Assets (84.8) (63.4) (27.4) (27.5) Amortization of Prior Service Credit — — (15.8) (17.8) Amortization of Net Actuarial Loss 0.3 15.8 3.7 — Net Periodic Benefit Cost (Credit) $ (6.1) $ 20.2 $ (26.8) $ (36.2) AEP Texas Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2023 2022 2023 2022 (in millions) Service Cost $ 2.0 $ 2.8 $ 0.1 $ 0.1 Interest Cost 4.6 3.0 0.9 0.6 Expected Return on Plan Assets (7.0) (5.3) (2.3) (2.3) Amortization of Prior Service Credit — — (1.3) (1.5) Amortization of Net Actuarial Loss — 1.3 0.3 — Net Periodic Benefit Cost (Credit) $ (0.4) $ 1.8 $ (2.3) $ (3.1) APCo Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2023 2022 2023 2022 (in millions) Service Cost $ 2.3 $ 2.9 $ 0.1 $ 0.2 Interest Cost 6.6 4.4 1.8 1.2 Expected Return on Plan Assets (11.2) (8.1) (4.0) (4.1) Amortization of Prior Service Credit — — (2.3) (2.6) Amortization of Net Actuarial Loss — 1.8 0.6 — Net Periodic Benefit Cost (Credit) $ (2.3) $ 1.0 $ (3.8) $ (5.3) I&M Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2023 2022 2023 2022 (in millions) Service Cost $ 3.0 $ 4.0 $ 0.2 $ 0.2 Interest Cost 6.2 4.2 1.3 0.8 Expected Return on Plan Assets (11.0) (8.0) (3.4) (3.4) Amortization of Prior Service Credit — — (2.2) (2.4) Amortization of Net Actuarial Loss — 1.8 0.5 — Net Periodic Benefit Cost (Credit) $ (1.8) $ 2.0 $ (3.6) $ (4.8) OPCo Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2023 2022 2023 2022 (in millions) Service Cost $ 2.1 $ 2.7 $ 0.1 $ 0.2 Interest Cost 4.9 3.4 1.2 0.7 Expected Return on Plan Assets (8.5) (6.2) (2.9) (3.0) Amortization of Prior Service Credit — — (1.6) (1.8) Amortization of Net Actuarial Loss — 1.4 0.4 — Net Periodic Benefit Cost (Credit) $ (1.5) $ 1.3 $ (2.8) $ (3.9) PSO Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2023 2022 2023 2022 (in millions) Service Cost $ 1.4 $ 1.9 $ 0.1 $ 0.1 Interest Cost 2.7 1.8 0.6 0.4 Expected Return on Plan Assets (4.6) (3.4) (1.5) (1.5) Amortization of Prior Service Credit — — (1.0) (1.1) Amortization of Net Actuarial Loss — 0.7 0.2 — Net Periodic Benefit Cost (Credit) $ (0.5) $ 1.0 $ (1.6) $ (2.1) SWEPCo Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2023 2022 2023 2022 (in millions) Service Cost $ 1.9 $ 2.6 $ 0.1 $ 0.1 Interest Cost 3.5 2.3 0.7 0.5 Expected Return on Plan Assets (4.8) (3.7) (1.8) (1.9) Amortization of Prior Service Credit — — (1.2) (1.3) Amortization of Net Actuarial Loss — 1.0 0.2 — Net Periodic Benefit Cost (Credit) $ 0.6 $ 2.2 $ (2.0) $ (2.6)

Business Segments

Business Segments	3 Months Ended
	Mar. 31, 2023
Business Segments	BUSINESS SEGMENTS The disclosures in this note apply to all Registrants unless indicated otherwise. AEP’s Reportable Segments AEP’s primary business is the generation, transmission and distribution of electricity. Within its Vertically Integrated Utilities segment, AEP centrally dispatches generation assets and manages its overall utility operations on an integrated basis because of the substantial impact of cost-based rates and regulatory oversight. Intersegment sales and transfers are generally based on underlying contractual arrangements and agreements. AEP’s reportable segments and their related business activities are outlined below: Vertically Integrated Utilities • Generation, transmission and distribution of electricity for sale to retail and wholesale customers through assets owned and operated by AEGCo, APCo, I&M, KGPCo, KPCo, PSO, SWEPCo and WPCo. Transmission and Distribution Utilities • Transmission and distribution of electricity for sale to retail and wholesale customers through assets owned and operated by AEP Texas and OPCo. • OPCo purchases energy and capacity to serve standard service offer customers and provides transmission and distribution services for all connected load. AEP Transmission Holdco • Development, construction and operation of transmission facilities through investments in AEPTCo. These investments have FERC-approved ROEs. • Development, construction and operation of transmission facilities through investments in AEP’s transmission-only joint ventures. These investments have PUCT-approved or FERC-approved ROEs. Generation & Marketing • Contracted renewable energy investments and management services. • Marketing, risk management and retail activities in ERCOT, MISO, PJM and SPP. • Competitive generation in PJM. The remainder of AEP’s activitie s are p resented as Corporate and Other. While not considered a reportable segment, Corporate and Other primarily includes the purchasing of receivables from certain AEP utility subsidiaries, Parent’s guarantee revenue received from affiliates, investment income, interest income and interest expense, and other nonallocated costs. The tables below represent AEP’s reportable segment income statement information for the three months ended March 31, 2023 and 2022 and reportable segment balance sheet information as of March 31, 2023 and December 31, 2022. 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) — 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 Three Months Ended March 31, 2022 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) Revenues from: External Customers $ 2,646.8 $ 1,242.2 $ 83.4 $ 609.5 $ 10.7 $ — $ 4,592.6 Other Operating Segments 40.6 4.6 328.0 9.8 9.2 (392.2) — Total Revenues $ 2,687.4 $ 1,246.8 $ 411.4 $ 619.3 $ 19.9 $ (392.2) $ 4,592.6 Net Income (Loss) $ 299.2 $ 152.8 $ 173.7 $ 116.0 $ (23.6) $ — $ 718.1 March 31, 2023 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Consolidated (in millions) Total Assets (d) $ 50,164.1 $ 23,437.0 $ 15,883.1 $ 4,159.8 $ 6,457.2 (b) $ (5,583.3) (c) $ 94,517.9 December 31, 2022 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Consolidated (in millions) Total Assets $ 49,761.8 $ 22,920.2 $ 15,215.8 $ 4,520.1 $ 6,768.4 (b) $ (5,783.0) (c) $ 93,403.3 (a) Corporate and Other primarily includes the purchasing of receivables from certain AEP utility subsidiaries. This segment also includes Parent’s guarantee revenue received from affiliates, investment income, interest income, interest expense and other nonallocated costs. (b) Includes elimination of AEP Parent’s investments in wholly-owned subsidiary companies. (c) Reconciling Adjustments for Total Assets primarily include elimination of intercompany advances to affiliates and intercompany accounts receivable. (d) Amount includes Assets Held for Sale on the balance sheet. See “Planned Disposition of the Competitive Contracted Renewables Portfolio” section of Note 6 for additional information. Registrant Subsidiaries’ Reportable Segments (Applies to all Registrant Subsidiaries except AEPTCo) The Registrant Subsidiaries each have one reportable segment, an integrated electricity generation, transmission and distribution business for APCo, I&M, PSO and SWEPCo, and an integrated electricity transmission and distribution business for AEP Texas and OPCo. Other activities are insignificant. The Registrant Subsidiaries’ operations are managed on an integrated basis because of the substantial impact of cost-based rates and regulatory oversight on the business process, cost structures and operating results. AEPTCo’s Reportable Segments AEPTCo Parent is the holding company of seven FERC-regulated transmission-only electric utilities. The seven State Transcos have been identified as operating segments of AEPTCo under the accounting guidance for “Segment Reporting.” The State Transcos business consists of developing, constructing and operating transmission facilities at the request of the RTOs in which they operate and in replacing and upgrading facilities, assets and components of the existing AEP transmission system as needed to maintain reliability standards and provide service to AEP’s wholesale and retail customers. The State Transcos are regulated for rate-making purposes exclusively by the FERC and earn revenues through tariff rates charged for the use of their electric transmission systems. AEPTCo’s Chief Operating Decision Maker makes operating decisions, allocates resources to and assesses performance based on these operating segments. The State Transcos operating segments all have similar economic characteristics and meet all of the criteria under the accounting guidance for “Segment Reporting” to be aggregated into one operating segment. As a result, AEPTCo has one reportable segment. The remainder of AEPTCo’s activity is presented in AEPTCo Parent. While not considered a reportable segment, AEPTCo Parent represents the activity of the holding company which primarily relates to debt financing activity and general corporate activities. The tables below present AEPTCo’s reportable segment income statement information for the three months ended March 31, 2023 and 2022 and reportable segment balance sheet information as of March 31, 2023 and December 31, 2022. Three Months Ended March 31, 2023 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (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 Three Months Ended March 31, 2022 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Revenues from: External Customers $ 75.7 $ — $ — $ 75.7 Sales to AEP Affiliates 324.7 — — 324.7 Total Revenues $ 400.4 $ — $ — $ 400.4 Net Income $ 155.4 $ — (a) $ — $ 155.4 March 31, 2023 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Total Assets $ 14,493.6 $ 5,581.6 (b) $ (5,620.5) (c) $ 14,454.7 December 31, 2022 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Total Assets $ 13,875.6 $ 4,817.4 (b) $ (4,878.8) (c) $ 13,814.2 (a) Includes the elimination of AEPTCo Parent’s equity earnings in the State Transcos. (b) Primarily relates to Notes Receivable from the State Transcos. (c) Primarily relates to the elimination of Notes Receivable from the State Transcos.

Derivatives and Hedging

Derivatives and Hedging	3 Months Ended
	Mar. 31, 2023
Derivatives and Hedging	DERIVATIVES AND HEDGING The disclosures in this note apply to all Registrants unless indicated otherwise. For the periods presented, AEPTCo did not have any derivative and hedging activity. OBJECTIVES FOR UTILIZATION OF DERIVATIVE INSTRUMENTS AEPSC is agent for and transacts on behalf of certain AEP subsidiaries, including the Registrant Subsidiaries. AEPEP is agent for and transacts on behalf of other AEP subsidiaries. The Registrants are exposed to certain market risks as major power producers and participants in the electricity, capacity, natural gas, coal and emission allowance markets. These risks include commodity price risks which may be subject to capacity risk, interest rate risk and credit risk. These risks represent the risk of loss that may impact the Registrants due to changes in the underlying market prices or rates. Management utilizes derivative instruments to manage these risks. STRATEGIES FOR UTILIZATION OF DERIVATIVE INSTRUMENTS TO ACHIEVE OBJECTIVES Risk Management Strategies The strategy surrounding the use of derivative instruments primarily focuses on managing risk exposures, future cash flows and creating value utilizing both economic and formal hedging strategies. The risk management strategies also include the use of derivative instruments for trading purposes which focus on seizing market opportunities to create value driven by expected changes in the market prices of the commodities. To accomplish these objectives, the Registrants primarily employ risk management contracts including physical and financial forward purchase-and-sale contracts and, to a lesser extent, OTC swaps and options. Not all risk management contracts meet the definition of a derivative under the accounting guidance for “Derivatives and Hedging.” Derivative risk management contracts elected normal under the normal purchases and normal sales scope exception are not subject to the requirements of this accounting guidance. The Registrants utilize power, capacity, coal, natural gas, interest rate and, to a lesser extent, heating oil, gasoline and other commodity contracts to manage the risk associated with the energy business. The Registrants utilize interest rate derivative contracts in order to manage the interest rate exposure associated with the commodity portfolio. For disclosure purposes, such risks are grouped as “Commodity,” as these risks are related to energy risk management activities. The Registrants also utilize derivative contracts to manage interest rate risk associated with debt financing. For disclosure purposes, these risks are grouped as “Interest Rate.” The amount of risk taken is determined by the Commercial Operations, Energy Supply and Finance groups in accordance with established risk management policies as approved by the Finance Committee of the Board of Directors. The following tables represent the gross notional volume of the Registrants’ outstanding derivative contracts: Notional Volume of Derivative Instruments March 31, 2023 Primary Risk Unit of AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power MWhs 213.5 — 7.3 4.1 2.4 1.8 1.3 Natural Gas MMBtus 92.8 — 2.9 — — 3.1 1.8 Heating Oil and Gasoline Gallons 5.0 1.4 0.8 0.5 1.0 0.7 0.7 Interest Rate USD $ 91.4 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt USD $ 1,700.0 $ 150.0 $ — $ — $ — $ — $ — December 31, 2022 Primary Risk Unit of AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power MWhs 226.8 — 17.9 4.2 2.5 2.9 2.2 Natural Gas MMBtus 77.1 — 1.9 — — 1.9 2.1 Heating Oil and Gasoline Gallons 6.9 1.9 1.0 0.7 1.4 0.9 1.0 Interest Rate USD $ 99.9 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt USD $ 1,650.0 $ — $ — $ — $ — $ 200.0 $ — Fair Value Hedging Strategies (Applies to AEP) Parent enters into interest rate derivative transactions as part of an overall strategy to manage the mix of fixed-rate and floating-rate debt. Certain interest rate derivative transactions effectively modify exposure to interest rate risk by converting a portion of fixed-rate debt to a floating-rate. Provided specific criteria are met, these interest rate derivatives may be designated as fair value hedges. Cash Flow Hedging Strategies The Registrants utilize cash flow hedges on certain derivative transactions for the purchase and sale of power (“Commodity”) in order to manage the variable price risk related to forecasted purchases and sales. Management monitors the potential impacts of commodity price changes and, where appropriate, enters into derivative transactions to protect profit margins for a portion of future electricity sales and purchases. The Registrants do not hedge all commodity price risk. The Registrants utilize a variety of interest rate derivative transactions in order to manage interest rate risk exposure. The Registrants also utilize interest rate derivative contracts to manage interest rate exposure related to future borrowings of fixed-rate debt. The Registrants do not hedge all interest rate exposure. ACCOUNTING FOR DERIVATIVE INSTRUMENTS AND THE IMPACT ON THE FINANCIAL STATEMENTS The accounting guidance for “Derivatives and Hedging” requires recognition of all qualifying derivative instruments as either assets or liabilities on the balance sheets at fair value. The fair values of derivative instruments accounted for using MTM accounting or hedge accounting are based on exchange prices and broker quotes. If a quoted market price is not available, the estimate of fair value is based on the best information available including valuation models that estimate future energy prices based on existing market and broker quotes and other assumptions. In order to determine the relevant fair values of the derivative instruments, the Registrants apply valuation adjustments for discounting, liquidity and credit quality. Credit risk is the risk that a counterparty will fail to perform on the contract or fail to pay amounts due. Liquidity risk represents the risk that imperfections in the market will cause the price to vary from estimated fair value based upon prevailing market supply and demand conditions. Since energy markets are imperfect and volatile, there are inherent risks related to the underlying assumptions in models used to fair value risk management contracts. Unforeseen events may cause reasonable price curves to differ from actual price curves throughout a contract’s term and at the time a contract settles. Consequently, there could be significant adverse or favorable effects on future net income and cash flows if market prices are not consistent with management’s estimates of current market consensus for forward prices in the current period. This is particularly true for longer term contracts. Cash flows may vary based on market conditions, margin requirements and the timing of settlement of risk management contracts. According to the accounting guidance for “Derivatives and Hedging,” the Registrants reflect the fair values of derivative instruments subject to netting agreements with the same counterparty net of related cash collateral. For certain risk management contracts, the Registrants are required to post or receive cash collateral based on third-party contractual agreements and risk profiles. AEP netted cash collateral received from third-parties against short-term and long-term risk management assets in the amounts of $108 million and $481 million as of March 31, 2023 and December 31, 2022, respectively. There was no cash collateral received from third-parties netted against short-term and long-term risk management assets for the Registrant Subsidiaries as of March 31, 2023 and December 31, 2022. The amount of cash collateral paid to third-parties netted against short-term and long-term risk management liabilities was immaterial for the Registrants as of March 31, 2023 and December 31, 2022. The following tables represent the gross fair value of the Registrants’ derivative activity on the balance sheets. Unless shown as a separate line on the balance sheets due to materiality, Current Risk Management Assets are included in Prepayments and Other Current Assets, Long-term Risk Management Assets are included in Deferred Charges and Other Noncurrent Assets, Current Risk Management Liabilities are included in Other Current Liabilities and Long-term Risk Management Liabilities are included in Deferred Credits and Other Noncurrent Liabilities on the balance sheets. AEP March 31, 2023 Risk Hedging Contracts Gross Amounts Gross Net Amounts of Balance Sheet Location Commodity (a) Commodity (a) Interest Rate (a) (in millions) Current Risk Management Assets $ 621.1 $ 85.0 $ 8.9 $ 715.0 $ (524.4) $ 190.6 Long-term Risk Management Assets 494.3 117.0 — 611.3 (293.1) 318.2 Total Assets 1,115.4 202.0 8.9 1,326.3 (817.5) 508.8 Current Risk Management Liabilities 562.5 87.5 39.5 689.5 (523.5) 166.0 Long-term Risk Management Liabilities 402.6 31.4 82.7 516.7 (201.3) 315.4 Total Liabilities 965.1 118.9 122.2 1,206.2 (724.8) 481.4 Total MTM Derivative Contract Net Assets (Liabilities) (d) $ 150.3 $ 83.1 $ (113.3) $ 120.1 $ (92.7) $ 27.4 December 31, 2022 Risk Hedging Contracts Gross Amounts Gross Net Amounts of Balance Sheet Location Commodity (a) Commodity (a) Interest Rate (a) (in millions) Current Risk Management Assets $ 965.4 $ 212.2 $ 1.8 $ 1,179.4 $ (830.6) $ 348.8 Long-term Risk Management Assets 565.6 148.9 14.3 728.8 (444.7) 284.1 Total Assets 1,531.0 361.1 16.1 1,908.2 (1,275.3) 632.9 Current Risk Management Liabilities 663.8 60.4 41.4 765.6 (620.4) 145.2 Long-term Risk Management Liabilities 412.0 17.4 91.1 520.5 (175.3) 345.2 Total Liabilities 1,075.8 77.8 132.5 1,286.1 (795.7) 490.4 Total MTM Derivative Contract Net Assets (Liabilities) $ 455.2 $ 283.3 $ (116.4) $ 622.1 $ (479.6) $ 142.5 AEP Texas March 31, 2023 Risk Management Contracts - Hedging Contracts Gross Amounts of Risk Management Assets/Liabilities Recognized Gross Amounts Offset in the Statement of Financial Position (b) Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position (c) Balance Sheet Location Commodity (a) Interest Rate (a) (in millions) Current Risk Management Assets $ — $ 0.5 $ 0.5 $ — $ 0.5 Long-term Risk Management Assets — — — — — Total Assets — 0.5 0.5 — 0.5 Current Risk Management Liabilities 0.4 0.8 1.2 (0.4) 0.8 Long-term Risk Management Liabilities — — — — — Total Liabilities 0.4 0.8 1.2 (0.4) 0.8 Total MTM Derivative Contract Net Assets (Liabilities) (d) $ (0.4) $ (0.3) $ (0.7) $ 0.4 $ (0.3) December 31, 2022 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ — $ — $ — Long-term Risk Management Assets — — — Total Assets — — — Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — — — Total Liabilities — — — Total MTM Derivative Contract Net Assets $ — $ — $ — APCo March 31, 2023 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 12.8 $ (0.4) $ 12.4 Long-term Risk Management Assets 0.5 (0.5) — Total Assets 13.3 (0.9) 12.4 Current Risk Management Liabilities 7.6 (0.6) 7.0 Long-term Risk Management Liabilities 0.5 (0.5) — Total Liabilities 8.1 (1.1) 7.0 Total MTM Derivative Contract Net Assets (d) $ 5.2 $ 0.2 $ 5.4 December 31, 2022 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 69.3 $ (0.2) $ 69.1 Long-term Risk Management Assets 0.7 (0.7) — Total Assets 70.0 (0.9) 69.1 Current Risk Management Liabilities 4.1 (0.5) 3.6 Long-term Risk Management Liabilities 0.7 (0.6) 0.1 Total Liabilities 4.8 (1.1) 3.7 Total MTM Derivative Contract Net Assets $ 65.2 $ 0.2 $ 65.4 I&M March 31, 2023 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 8.1 $ (2.2) $ 5.9 Long-term Risk Management Assets 5.5 (4.4) 1.1 Total Assets 13.6 (6.6) 7.0 Current Risk Management Liabilities 2.7 (2.3) 0.4 Long-term Risk Management Liabilities 4.4 (4.4) — Total Liabilities 7.1 (6.7) 0.4 Total MTM Derivative Contract Net Assets (d) $ 6.5 $ 0.1 $ 6.6 December 31, 2022 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 16.0 $ (0.8) $ 15.2 Long-term Risk Management Assets 0.5 (0.3) 0.2 Total Assets 16.5 (1.1) 15.4 Current Risk Management Liabilities 0.9 (0.9) — Long-term Risk Management Liabilities 0.3 (0.3) — Total Liabilities 1.2 (1.2) — Total MTM Derivative Contract Net Assets $ 15.3 $ 0.1 $ 15.4 OPCo March 31, 2023 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ — $ — $ — Long-term Risk Management Assets — — — Total Assets — — — Current Risk Management Liabilities 6.2 (0.2) 6.0 Long-term Risk Management Liabilities 40.9 — 40.9 Total Liabilities 47.1 (0.2) 46.9 Total MTM Derivative Contract Net Assets (Liabilities) (d) $ (47.1) $ 0.2 $ (46.9) December 31, 2022 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ — $ — $ — Long-term Risk Management Assets — — — Total Assets — — — Current Risk Management Liabilities 2.1 (0.3) 1.8 Long-term Risk Management Liabilities 37.9 — 37.9 Total Liabilities 40.0 (0.3) 39.7 Total MTM Derivative Contract Net Assets (Liabilities) $ (40.0) $ 0.3 $ (39.7) PSO March 31, 2023 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 9.9 $ (0.5) $ 9.4 Long-term Risk Management Assets — — — Total Assets 9.9 (0.5) 9.4 Current Risk Management Liabilities 1.8 (0.7) 1.1 Long-term Risk Management Liabilities — — — Total Liabilities 1.8 (0.7) 1.1 Total MTM Derivative Contract Net Assets (d) $ 8.1 $ 0.2 $ 8.3 December 31, 2022 Risk Management Contracts – Hedging Contracts Gross Amounts of Risk Management Assets/Liabilities Recognized Gross Amounts Offset in the Statement of Financial Position (b) Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position (c) Balance Sheet Location Commodity (a) Interest Rate (a) (in millions) Current Risk Management Assets $ 24.1 $ 1.6 $ 25.7 $ (0.4) $ 25.3 Long-term Risk Management Assets — — — — — Total Assets 24.1 1.6 25.7 (0.4) 25.3 Current Risk Management Liabilities 2.1 — 2.1 (0.5) 1.6 Long-term Risk Management Liabilities — — — — — Total Liabilities 2.1 — 2.1 (0.5) 1.6 Total MTM Derivative Contract Net Assets $ 22.0 $ 1.6 $ 23.6 $ 0.1 $ 23.7 SWEPCo March 31, 2023 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 6.4 $ (0.1) $ 6.3 Long-term Risk Management Assets — — — Total Assets 6.4 (0.1) 6.3 Current Risk Management Liabilities 1.4 (0.3) 1.1 Long-term Risk Management Liabilities — — — Total Liabilities 1.4 (0.3) 1.1 Total MTM Derivative Contract Net Assets (d) $ 5.0 $ 0.2 $ 5.2 December 31, 2022 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 16.8 $ (0.4) $ 16.4 Long-term Risk Management Assets — — — Total Assets 16.8 (0.4) 16.4 Current Risk Management Liabilities 2.0 (0.6) 1.4 Long-term Risk Management Liabilities — — — Total Liabilities 2.0 (0.6) 1.4 Total MTM Derivative Contract Net Assets $ 14.8 $ 0.2 $ 15.0 (a) Derivative instruments within these categories are disclosed as gross. These instruments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with the accounting guidance for “Derivatives and Hedging.” (b) Amounts include counterparty netting of risk management and hedging contracts and associated cash collateral in accordance with the accounting guidance for “Derivatives and Hedging.” (c) All derivative contracts subject to a master netting arrangement or similar agreement are offset in the statement of financial position. (d) Decrease in amounts as of March 31, 2023 are primarily due to decreases in commodity prices for power and natural gas and a decrease in value of FTRs. The tables below present the Registrants’ amount of gain (loss) recognized on risk management contracts: Amount of Gain (Loss) Recognized on Risk Management Contracts Three Months Ended 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 for Resale 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 (b) $ (178.2) $ (0.4) $ (32.7) $ (4.6) $ (12.3) $ 16.8 $ 10.4 Three Months Ended March 31, 2022 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Generation & Marketing Revenues $ 152.3 $ — $ — $ — $ — $ — $ — Electric Generation, Transmission and Distribution Revenues — — 0.1 (0.1) — — — Purchased Electricity for Resale 1.5 — 1.4 — — — — Other Operation 0.6 0.2 — 0.1 0.1 0.1 0.1 Maintenance 0.8 0.2 0.1 0.1 0.1 0.1 0.1 Regulatory Assets (a) 23.6 — (0.1) (1.6) 23.9 3.6 (2.1) Regulatory Liabilities (a) 36.5 0.9 (1.4) 1.7 — 12.7 20.9 Total Gain on Risk Management Contracts $ 215.3 $ 1.3 $ 0.1 $ 0.2 $ 24.1 $ 16.5 $ 19.0 (a) Represents realized and unrealized gains and losses subject to regulatory accounting treatment recorded as either current or noncurrent on the balance sheets. (b) Decrease in amounts as of March 31, 2023 are primarily due to decreases in commodity prices for power and natural gas and a decrease in value of FTRs. Certain qualifying derivative instruments have been designated as normal purchase or normal sale contracts, as provided in the accounting guidance for “Derivatives and Hedging.” Derivative contracts that have been designated as normal purchases or normal sales under that accounting guidance are not subject to MTM accounting treatment and are recognized on the statements of income on an accrual basis. The accounting for the changes in the fair value of a derivative instrument depends on whether it qualifies for and has been designated as part of a hedging relationship and further, on the type of hedging relationship. Depending on the exposure, management designates a hedging instrument as a fair value hedge or a cash flow hedge. For contracts that have not been designated as part of a hedging relationship, the accounting for changes in fair value depends on whether the derivative instrument is held for trading purposes. Unrealized and realized gains and losses on derivative instruments held for trading purposes are included in revenues on a net basis on the statements of income. Unrealized and realized gains and losses on derivative instruments not held for trading purposes are included in revenues or expenses on the statements of income depending on the relevant facts and circumstances. Certain derivatives that economically hedge future commodity risk are recorded in the same line item on the statements of income as that of the associated risk being hedged. However, unrealized and some realized gains and losses in regulated jurisdictions for both trading and non-trading derivative instruments are recorded as regulatory assets (for losses) or regulatory liabilities (for gains) in accordance with the accounting guidance for “Regulated Operations.” Accounting for Fair Value Hedging Strategies (Applies to AEP) For fair value hedges (i.e. hedging the exposure to changes in the fair value of an asset, liability or an identified portion thereof attributable to a particular risk), the gain or loss on the derivative instrument as well as the offsetting gain or loss on the hedged item associated with the hedged risk impacts net income during the period of change. AEP records realized and unrealized gains or losses on interest rate swaps that are designated and qualify for fair value hedge accounting treatment and any offsetting changes in the fair value of the debt being hedged in Interest Expense on the statements of income. The following table shows the impacts recognized on the balance sheets related to the hedged items in fair value hedging relationships: Carrying Amount of the Hedged Liabilities Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of the Hedged Liabilities March 31, 2023 December 31, 2022 March 31, 2023 December 31, 2022 (in millions) Long-term Debt (a) (b) $ (860.8) $ (855.5) $ 84.7 $ 89.7 (a) Amounts included on the Balance Sheet within Noncurrent Liabilities line item Long-term Debt. (b) Amounts include $(36) million and $(38) million as of March 31, 2023 and December 31, 2022, respectively, for the fair value hedge adjustment of hedged debt obligations for which hedge accounting has been discontinued. The pretax effects of fair value hedge accounting on income were as follows: Three Months Ended March 31, 2023 2022 (in millions) Gain (Loss) on Interest Rate Contracts: Fair Value Hedging Instruments (a) $ 6.9 $ (44.8) Fair Value Portion of Long-term Debt (a) (6.9) 44.8 (a) Gain (Loss) is included in Interest Expense on the statements of income. Accounting for Cash Flow Hedging Strategies (Applies to AEP, AEP Texas, APCo, I&M, PSO and SWEPCo) For cash flow hedges (i.e. hedging the exposure to variability in expected future cash flows that is attributable to a particular risk), the Registrants initially report the gain or loss on the derivative instrument as a component of Accumulated Other Comprehensive Income (Loss) on the balance sheets until the period the hedged item affects net income. Realized gains and losses on derivative contracts for the purchase and sale of power designated as cash flow hedges are included in Total Revenues or Purchased Electricity for Resale on the statements of income or in Regulatory Assets or Regulatory Liabilities on the balance sheets, depending on the specific nature of the risk being hedged. During the three months ended March 31, 2023 and 2022, AEP applied cash flow hedging to outstanding power derivatives and the Registrant Subsidiaries did not. The Registrants reclassify gains and losses on interest rate derivative hedges related to debt financings from Accumulated Other Comprehensive Income (Loss) on the balance sheets into Interest Expense on the statements of income in those periods in which hedged interest payments occur. During the three months ended 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. During the three months ended March 31, 2022, AEP applied cash flow hedging to outstanding interest rate derivatives and the Registrant Subsidiaries did not. For details on effective cash flow hedges included in Accumulated Other Comprehensive Income (Loss) on the balance sheets and the reasons for changes in cash flow hedges, see Note 3 - Comprehensive Income. Cash flow hedges included in Accumulated Other Comprehensive Income (Loss) on the balance sheets were: Impact of Cash Flow Hedges on AEP’s Balance Sheets March 31, 2023 December 31, 2022 Commodity Interest Rate Commodity Interest Rate (in millions) AOCI Gain Net of Tax $ 65.3 $ 6.1 $ 223.5 $ 0.3 Portion Expected to be Reclassed to Net Income During the Next Twelve Months (2.0) 1.9 119.9 0.3 As of March 31, 2023 the maximum length of time that AEP is hedging its exposure to variability in future cash flows related to forecasted transactions is 96 months and 93 months for commodity and interest rate hedges, respectively. Impact of Cash Flow Hedges on the Registrant Subsidiaries’ Balance Sheets March 31, 2023 December 31, 2022 Interest Rate Expected to be Expected to be Reclassified to Reclassified to Net Income During Net Income During AOCI Gain (Loss) the Next AOCI Gain (Loss) the Next Company Net of Tax Twelve Months Net of Tax Twelve Months (in millions) AEP Texas $ (0.3) $ — $ (0.3) $ (0.2) APCo 6.5 0.8 6.7 0.8 I&M (5.8) (0.4) (5.1) (0.6) PSO (0.2) — 1.3 0.1 SWEPCo 1.5 0.3 1.1 0.2 The actual amounts reclassified from Accumulated Other Comprehensive Income (Loss) to Net Income can differ from the estimate above due to market price changes. Credit Risk Management mitigates credit risk in wholesale marketing and trading activities by assessing the creditworthiness of potential counterparties before entering into transactions with them and continuing to evaluate their creditworthiness on an ongoing basis. Management uses credit agency ratings and current market-based qualitative and quantitative data as well as financial statements to assess the financial health of counterparties on an ongoing basis. Master agreements are typically used to facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Collateral requirements in the form of cash, letters of credit and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. Some master agreements include margining, which requires a counterparty to post cash or letters of credit in the event exposure exceeds the established threshold. The threshold represents an unsecured credit limit which may be supported by a parental/affiliate guaranty, as determined in accordance with AEP’s credit policy. In addition, master agreements allow for termination and liquidation of all positions in the event of a default including a failure or inability to post collateral when required. Credit-Risk-Related Contingent Features Credit Downgrade Triggers (Applies to AEP, APCo, I&M, PSO and SWEPCo) A limited number of derivative contracts include collateral triggering events, which include a requirement to maintain certain credit ratings. On an ongoing basis, AEP’s risk management organization assesses the appropriateness of these collateral triggering events in contracts. The Registrants have not experienced a downgrade below a specified credit rating threshold that would require the posting of additional collateral. AEP had derivative contracts with collateral triggering events in a net liability position with a total exposure of $0 and $2 million as of March 31, 2023 and December 31, 2022, respectively. The Registrant Subsidiaries had no derivative contracts with collateral triggering events in a net liability position as of March 31, 2023 and December 31, 2022. Cross-Acceleration Triggers Certain interest rate derivative contracts contain cross-acceleration provisions that, if triggered, would permit the counterparty to declare a default and require settlement of the outstanding payable. These cross-acceleration provisions could be triggered if there was a non-performance event by the Registrants under any of their outstanding debt of at least $50 million and the lender on that debt has accelerated the entire repayment obligation. On an ongoing basis, AEP’s risk management organization assesses the appropriateness of these cross-acceleration provisions in contracts. AEP had derivative contracts with cross-acceleration provisions in a net liability position of $121 million and $127 million as of March 31, 2023 and December 31, 2022, respectively. There was no cash collateral posted as of March 31, 2023 and December 31, 2022, respectively. If a cross-acceleration provision would have been triggered, settlement at fair value would have been required. AEP Texas’ derivative contracts with cross-acceleration provisions in a net liability position were immaterial as of March 31, 2023 and AEP Texas had no derivative contracts with cross-acceleration provisions in a net liability as of December 31, 2022. The other Registrant Subsidiaries had no derivative contracts with cross-acceleration provisions outstanding as of March 31, 2023 and December 31, 2022. Cross-Default Triggers (Applies to AEP, APCo, I&M, PSO and SWEPCo) In addition, a majority of non-exchange traded commodity contracts contain cross-default provisions that, if triggered, would permit the counterparty to declare a default and require settlement of the outstanding payable. These cross-default provisions could be triggered if there was a non-performance event by Parent or the obligor under outstanding debt or a third-party obligation that is $50 million or greater. On an ongoing basis, AEP’s risk management organization assesses the appropriateness of these cross-default provisions in the contracts. AEP had derivative liabilities subject to cross-default provisions in a net liability position of $193 million and $217 million as of March 31, 2023 and December 31, 2022, respectively, after considering contractual netting arrangements. There was no cash collateral posted as of March 31, 2023 and December 31, 2022. If a cross-default provision would have been triggered, settlement at fair value would have been required. The Registrant Subsidiaries’ derivative contracts with cross-default provisions outstanding as of March 31, 2023 and December 31, 2022 were not material.

Fair Value Measurements

Fair Value Measurements	3 Months Ended
	Mar. 31, 2023
Fair Value Measurements	FAIR VALUE MEASUREMENTS The disclosures in this note apply to all Registrants except AEPTCo unless indicated otherwise. Fair Value Hierarchy and Valuation Techniques The accounting guidance for “Fair Value Measurements and Disclosures” establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). Where observable inputs are available for substantially the full term of the asset or liability, the instrument is categorized in Level 2. When quoted market prices are not available, pricing may be completed using comparable securities, dealer values, operating data and general market conditions to determine fair value. Valuation models utilize various inputs such as commodity, interest rate and, to a lesser degree, volatility and credit that include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, market corroborated inputs (i.e. inputs derived principally from, or correlated to, observable market data) and other observable inputs for the asset or liability. For commercial activities, exchange-traded derivatives, namely futures contracts, are generally fair valued based on unadjusted quoted prices in active markets and are classified as Level 1. Level 2 inputs primarily consist of OTC broker quotes in moderately active or less active markets, as well as exchange-traded derivatives where there is insufficient market liquidity to warrant inclusion in Level 1. Management verifies price curves using these broker quotes and classifies these fair values within Level 2 when substantially all of the fair value can be corroborated. Management typically obtains multiple broker quotes, which are nonbinding in nature but are based on recent trades in the marketplace. When multiple broker quotes are obtained, the quoted bid and ask prices are averaged. In certain circumstances, a broker quote may be discarded if it is a clear outlier. Management uses a historical correlation analysis between the broker quoted location and the illiquid locations. If the points are highly correlated, these locations are included within Level 2 as well. Certain OTC and bilaterally executed derivative instruments are executed in less active markets with a lower availability of pricing information. Illiquid transactions, complex structured transactions, FTRs and counterparty credit risk may require nonmarket-based inputs. Some of these inputs may be internally developed or extrapolated and utilized to estimate fair value. When such inputs have a significant impact on the measurement of fair value, the instrument is categorized as Level 3. The main driver of contracts being classified as Level 3 is the inability to substantiate energy price curves in the market. A portion of the Level 3 instruments have been economically hedged which limits potential earnings volatility. AEP utilizes its trustee’s external pricing service to estimate the fair value of the underlying investments held in the nuclear trusts. AEP’s investment managers review and validate the prices utilized by the trustee to determine fair value. AEP’s management performs its own valuation testing to verify the fair values of the securities. AEP receives audit reports of the trustee’s operating controls and valuation processes. Assets in the nuclear trusts, cash and cash equivalents, other temporary investments restricted cash for securitized funding are classified using the following methods. Equities are classified as Level 1 holdings if they are actively traded on exchanges. Items classified as Level 1 are investments in money market funds, fixed income and equity mutual funds and equity securities. They are valued based on observable inputs, primarily unadjusted quoted prices in active markets for identical assets. Items classified as Level 2 are primarily investments in individual fixed income securities. Fixed income securities generally do not trade on exchanges and do not have an official closing price but their valuation inputs are based on observable market data. Pricing vendors calculate bond valuations using financial models and matrices. The models use observable inputs including yields on benchmark securities, quotes by securities brokers, rating agency actions, discounts or premiums on securities compared to par prices, changes in yields for U.S. Treasury securities, corporate actions by bond issuers, prepayment schedules and histories, economic events and, for certain securities, adjustments to yields to reflect changes in the rate of inflation. Other securities with model-derived valuation inputs that are observable are also classified as Level 2 investments. Investments with unobservable valuation inputs are classified as Level 3 investments. Fair Value Measurements of Long-term Debt (Applies to all Registrants) The fair values of Long-term Debt are based on quoted market prices, without credit enhancements, for the same or similar issues and the current interest rates offered for instruments with similar maturities classified as Level 2 measurement inputs. These instruments are not marked-to-market. The estimates presented are not necessarily indicative of the amounts that could be realized in a current market exchange. The fair value of AEP’s Equity Units (Level 1) are valued based on publicly traded securities issued by AEP. The book values and fair values of Long-term Debt are summarized in the following table: March 31, 2023 December 31, 2022 Company Book Value Fair Value Book Value Fair Value (in millions) AEP (a) $ 39,144.2 $ 36,126.4 $ 36,801.0 $ 32,915.9 AEP Texas 5,522.0 5,009.5 5,657.8 5,045.8 AEPTCo 5,472.1 4,836.2 4,782.8 3,940.5 APCo 5,398.7 5,227.7 5,410.5 5,079.2 I&M 3,489.0 3,249.1 3,260.8 2,929.0 OPCo 2,970.8 2,566.6 2,970.3 2,516.6 PSO 2,383.6 2,172.6 1,912.8 1,635.8 SWEPCo 3,644.8 3,195.9 3,391.6 2,870.9 (a) The fair value amounts include debt related to AEP’s Equity Units and had a fair value of $856 million and $877 million as of March 31, 2023 and December 31, 2022, respectively. See “Equity Units” section of Note 12 for additional information. Fair Value Measurements of Other Temporary Investments and Restricted Cash (Applies to AEP) Other Temporary Investments include marketable securities that management intends to hold for less than one year and investments by AEP’s protected cell of EIS. The following is a summary of Other Temporary Investments and Restricted Cash: March 31, 2023 Gross Gross Unrealized Unrealized Fair Other Temporary Investments and Restricted Cash Cost Gains Losses Value (in millions) Restricted Cash (a) $ 50.0 $ — $ — $ 50.0 Other Cash Deposits 11.4 — — 11.4 Fixed Income Securities – Mutual Funds (b) 153.4 — (7.2) 146.2 Equity Securities – Mutual Funds 15.2 21.8 — 37.0 Total Other Temporary Investments and Restricted Cash $ 230.0 $ 21.8 $ (7.2) $ 244.6 December 31, 2022 Gross Gross Unrealized Unrealized Fair Other Temporary Investments and Restricted Cash Cost Gains Losses Value (in millions) Restricted Cash (a) $ 47.1 $ — $ — $ 47.1 Other Cash Deposits 9.0 — — 9.0 Fixed Income Securities – Mutual Funds (b) 152.4 — (8.3) 144.1 Equity Securities – Mutual Funds 15.1 19.4 — 34.5 Total Other Temporary Investments and Restricted Cash $ 223.6 $ 19.4 $ (8.3) $ 234.7 (a) Primarily represents amounts held for the repayment of debt. (b) Primarily short and intermediate maturities which may be sold and do not contain maturity dates. The following table provides the activity for fixed income and equity securities within Other Temporary Investments: Three Months Ended March 31, 2023 2022 (in millions) Proceeds from Investment Sales $ — $ 3.9 Purchases of Investments 1.0 0.8 Gross Realized Gains on Investment Sales — 0.3 Gross Realized Losses on Investment Sales — 0.1 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, 2023 December 31, 2022 Gross Gross Other-Than- Gross Gross Other-Than- Fair Unrealized Unrealized Temporary Fair Unrealized Unrealized Temporary Value Gains Losses Impairments Value Gains Losses Impairments (in millions) Cash and Cash Equivalents $ 26.5 $ — $ — $ — $ 21.2 $ — $ — $ — Fixed Income Securities: United States Government 1,207.6 20.9 (6.4) (28.3) 1,123.8 11.8 (14.9) (18.8) Corporate Debt 66.0 1.0 (6.1) (2.2) 61.6 0.7 (7.7) (9.6) State and Local Government 3.3 — — — 3.3 0.1 — (0.1) Subtotal Fixed Income Securities 1,276.9 21.9 (12.5) (30.5) 1,188.7 12.6 (22.6) (28.5) Equity Securities - Domestic 2,197.7 1,565.1 (2.9) — 2,131.3 1,483.7 (6.4) — Spent Nuclear Fuel and Decommissioning Trusts $ 3,501.1 $ 1,587.0 $ (15.4) $ (30.5) $ 3,341.2 $ 1,496.3 $ (29.0) $ (28.5) The following table provides the securities activity within the decommissioning and SNF trusts: Three Months Ended March 31, 2023 2022 (in millions) Proceeds from Investment Sales $ 517.6 $ 493.5 Purchases of Investments 536.3 507.7 Gross Realized Gains on Investment Sales 48.5 5.8 Gross Realized Losses on Investment Sales 8.6 7.2 The base cost of fixed income securities was $1.3 billion and $1.2 billion as of March 31, 2023 and December 31, 2022, respectively. The base cost of equity securities was $635 million and $654 million as of March 31, 2023 and December 31, 2022, respectively. The fair value of fixed income securities held in the nuclear trust funds, summarized by contractual maturities, as of March 31, 2023 was as follows: Fair Value of Fixed Income Securities (in millions) Within 1 year $ 347.8 After 1 year through 5 years 489.1 After 5 years through 10 years 215.6 After 10 years 224.4 Total $ 1,276.9 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, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments and Restricted Cash Restricted Cash $ 50.0 $ — $ — $ — $ 50.0 Other Cash Deposits (a) — — — 11.4 11.4 Fixed Income Securities – Mutual Funds 146.2 — — — 146.2 Equity Securities – Mutual Funds (b) 37.0 — — — 37.0 Total Other Temporary Investments and Restricted Cash 233.2 — — 11.4 244.6 Risk Management Assets Risk Management Commodity Contracts (c) (d) 13.0 861.2 209.2 (720.2) 363.2 Cash Flow Hedges: Commodity Hedges (c) — 177.8 20.3 (61.4) 136.7 Interest Rate Hedges — 8.9 — — 8.9 Total Risk Management Assets 13.0 1,047.9 229.5 (781.6) 508.8 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 17.1 — — 9.4 26.5 Fixed Income Securities: United States Government — 1,207.6 — — 1,207.6 Corporate Debt — 66.0 — — 66.0 State and Local Government — 3.3 — — 3.3 Subtotal Fixed Income Securities — 1,276.9 — — 1,276.9 Equity Securities – Domestic (b) 2,197.7 — — — 2,197.7 Total Spent Nuclear Fuel and Decommissioning Trusts 2,214.8 1,276.9 — 9.4 3,501.1 Total Assets $ 2,461.0 $ 2,324.8 $ 229.5 $ (760.8) $ 4,254.5 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (d) $ 33.5 $ 721.1 $ 178.5 $ (627.5) $ 305.6 Cash Flow Hedges: Commodity Hedges (c) — 109.1 5.9 (61.4) 53.6 Interest Rate Hedges — 1.7 — — 1.7 Fair Value Hedges — 120.5 — — 120.5 Total Risk Management Liabilities $ 33.5 $ 952.4 $ 184.4 $ (688.9) $ 481.4 AEP Assets and Liabilities Measured at Fair Value on a Recurring Basis December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments and Restricted Cash Restricted Cash $ 47.1 $ — $ — $ — $ 47.1 Other Cash Deposits (a) — — — 9.0 9.0 Fixed Income Securities – Mutual Funds 144.1 — — — 144.1 Equity Securities – Mutual Funds (b) 34.5 — — — 34.5 Total Other Temporary Investments and Restricted Cash 225.7 — — 9.0 234.7 Risk Management Assets Risk Management Commodity Contracts (c) (f) 15.0 1,197.5 314.4 (1,211.5) 315.4 Cash Flow Hedges: Commodity Hedges (c) — 332.6 26.7 (52.8) 306.5 Interest Rate Hedges — 11.0 — — 11.0 Total Risk Management Assets 15.0 1,541.1 341.1 (1,264.3) 632.9 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 11.3 — — 9.9 21.2 Fixed Income Securities: United States Government — 1,123.8 — — 1,123.8 Corporate Debt — 61.6 — — 61.6 State and Local Government — 3.3 — — 3.3 Subtotal Fixed Income Securities — 1,188.7 — — 1,188.7 Equity Securities – Domestic (b) 2,131.3 — — — 2,131.3 Total Spent Nuclear Fuel and Decommissioning Trusts 2,142.6 1,188.7 — 9.9 3,341.2 Total Assets $ 2,383.3 $ 2,729.8 $ 341.1 $ (1,245.4) $ 4,208.8 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (f) $ 21.8 $ 870.9 $ 179.0 $ (731.9) $ 339.8 Cash Flow Hedges: Commodity Hedges (c) — 74.3 1.7 (52.8) 23.2 Fair Value Hedges — 127.4 — — 127.4 Total Risk Management Liabilities $ 21.8 $ 1,072.6 $ 180.7 $ (784.7) $ 490.4 AEP Texas Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 42.5 $ — $ — $ — $ 42.5 Risk Management Assets Cash Flow Hedges: Interest Rate Hedges — 0.5 — — 0.5 Total Assets $ 42.5 $ 0.5 $ — $ — $ 43.0 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 0.4 $ — $ (0.4) $ — Cash Flow Hedges: Interest Rate Hedges — 0.8 — — 0.8 Total Liabilities $ — $ 1.2 $ — $ (0.4) $ 0.8 December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 32.7 $ — $ — $ — $ 32.7 APCo Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 7.5 $ — $ — $ — $ 7.5 Risk Management Assets Risk Management Commodity Contracts (c) (g) — 0.4 12.4 (0.4) 12.4 Total Assets $ 7.5 $ 0.4 $ 12.4 $ (0.4) $ 19.9 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 0.9 $ 6.7 $ (0.6) $ 7.0 December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 14.4 $ — $ — $ — $ 14.4 Risk Management Assets Risk Management Commodity Contracts (c) (g) — 0.7 69.4 (1.0) 69.1 Total Assets $ 14.4 $ 0.7 $ 69.4 $ (1.0) $ 83.5 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 4.6 $ 0.3 $ (1.4) $ 3.5 I&M Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 6.6 $ 1.6 $ (1.2) $ 7.0 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 17.1 — — 9.4 26.5 Fixed Income Securities: United States Government — 1,207.6 — — 1,207.6 Corporate Debt — 66.0 — — 66.0 State and Local Government — 3.3 — — 3.3 Subtotal Fixed Income Securities — 1,276.9 — — 1,276.9 Equity Securities - Domestic (b) 2,197.7 — — — 2,197.7 Total Spent Nuclear Fuel and Decommissioning Trusts 2,214.8 1,276.9 — 9.4 3,501.1 Total Assets $ 2,214.8 $ 1,283.5 $ 1.6 $ 8.2 $ 3,508.1 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 1.3 $ 0.5 $ (1.4) $ 0.4 December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 11.3 $ 5.3 $ (1.2) $ 15.4 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 11.3 — — 9.9 21.2 Fixed Income Securities: United States Government — 1,123.8 — — 1,123.8 Corporate Debt — 61.6 — — 61.6 State and Local Government — 3.3 — — 3.3 Subtotal Fixed Income Securities — 1,188.7 — — 1,188.7 Equity Securities - Domestic (b) 2,131.3 — — — 2,131.3 Total Spent Nuclear Fuel and Decommissioning Trusts 2,142.6 1,188.7 — 9.9 3,341.2 Total Assets $ 2,142.6 $ 1,200.0 $ 5.3 $ 8.7 $ 3,356.6 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 0.6 $ 0.7 $ (1.3) $ — OPCo Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (g) $ — $ — $ — $ — $ — Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 0.2 $ 46.9 $ (0.2) $ 46.9 December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (g) $ — $ — $ — $ — $ — Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 40.0 $ (0.3) $ 39.7 PSO Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ — $ 9.9 $ (0.5) $ 9.4 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 1.2 $ 0.6 $ (0.7) $ 1.1 December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ — $ 24.0 $ 1.3 $ 25.3 Cash Flow Hedges: Interest Rate Hedges — 1.6 — (1.6) — Total Assets $ — $ 1.6 $ 24.0 $ (0.3) $ 25.3 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 1.7 $ 0.3 $ (0.4) $ 1.6 SWEPCo Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ — $ 6.4 $ (0.1) $ 6.3 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 0.8 $ 0.6 $ (0.3) $ 1.1 December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 2.2 $ 14.6 $ (0.4) $ 16.4 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 1.6 $ 0.4 $ (0.6) $ 1.4 (a) Amounts in “Other’’ column primarily represent cash deposits in bank accounts with financial institutions or third-parties. Level 1 and Level 2 amounts primarily represent investments in money market funds. (b) Amounts represent publicly traded equity securities and equity-based mutual funds. (c) Amounts in “Other’’ column primarily represent counterparty netting of risk management and hedging contracts and associated cash collateral under the accounting guidance for “Derivatives and Hedging.’’ (d) The March 31, 2023 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 2023 and $(6) million in periods 2024-2026; Level 2 matures $24 million in 2023, $105 million in periods 2024-2026, $9 million in periods 2027-2028 and $1 million in periods 2029-2033; Level 3 matures $18 million in 2023, $9 million in periods 2024-2026, $11 million in periods 2027-2028 and $(7) million in periods 2029-2033. Risk management commodity contracts are substantially comprised of power contracts. (e) Amounts in “Other’’ column primarily represent accrued interest receivables from financial institutions. Level 1 amounts primarily represent investments in money market funds. (f) The December 31, 2022 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $(7) million in 2023; Level 2 matures $182 million in 2023, $134 million in periods 2024-2026, $10 million in periods 2027-2028 and $1 million in periods 2029-2033; Level 3 matures $128 million in 2023, $6 million in periods 2024-2026, $6 million in periods 2027-2028 and $(5) million in periods 2029-2033. Risk management commodity contracts are substantially comprised of power contracts. (g) Substantially comprised of power contracts for the Registrant Subsidiaries. The following tables set forth a reconciliation of changes in the fair value of net trading derivatives classified as Level 3 in the fair value hierarchy: Three Months Ended 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 Three Months Ended March 31, 2022 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of December 31, 2021 $ 103.1 $ 41.7 $ (0.7) $ (92.5) $ 12.1 $ 10.9 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 18.2 (2.9) 3.8 0.5 12.1 9.8 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (19.0) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 19.3 — — — — — Settlements (51.6) (32.4) (2.3) 1.4 (19.8) (16.2) Transfers into Level 3 (d) (e) 2.5 — — — — — Transfers out of Level 3 (e) 2.9 — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 7.4 0.2 0.2 22.1 2.1 11.2 Balance as of March 31, 2022 $ 82.8 $ 6.6 $ 1.0 $ (68.5) $ 6.5 $ 15.7 (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: AEP Significant Unobservable Inputs March 31, 2023 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) Energy Contracts $ 190.7 $ 166.5 Discounted Cash Flow Forward Market Price $ 0.74 $ 101.65 $ 48.48 FTRs 38.8 17.9 Discounted Cash Flow Forward Market Price (55.98) 101.82 (0.45) Total $ 229.5 $ 184.4 December 31, 2022 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) Energy Contracts $ 204.0 $ 167.4 Discounted Cash Flow Forward Market Price $2.91 $ 187.34 $ 49.14 FTRs 137.1 13.3 Discounted Cash Flow Forward Market Price (36.45) 20.72 1.18 Total $ 341.1 $ 180.7 APCo Significant Unobservable Inputs March 31, 2023 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) FTRs $ 12.4 $ 6.7 Discounted Cash Flow Forward Market Price $ (1.67) $ 6.59 $ 0.79 December 31, 2022 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) FTRs $ 69.4 $ 0.3 Discounted Cash Flow Forward Market Price $ (2.82) $ 18.88 $ 3.89 I&M Significant Unobservable Inputs March 31, 2023 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) FTRs $ 1.6 $ 0.5 Discounted Cash Flow Forward Market Price $ 0.24 $ 4.75 $ 0.78 December 31, 2022 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) FTRs $ 5.3 $ 0.7 Discounted Cash Flow Forward Market Price $ 0.16 $ 18.79 $ 1.23 OPCo Significant Unobservable Inputs March 31, 2023 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) Energy Contracts $ — $ 46.9 Discounted Cash Flow Forward Market Price $ 14.41 $ 79.98 $ 45.92 December 31, 2022 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) Energy Contracts $ — $ 40.0 Discounted Cash Flow Forward Market Price $ 2.91 $ 187.34 $ 48.76 PSO Significant Unobservable Inputs March 31, 2023 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) FTRs $ 9.9 $ 0.6 Discounted Cash Flow Forward Market Price $ (21.10) $ 3.04 $ (4.75) December 31, 2022 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) FTRs $ 24.0 $ 0.3 Discounted Cash Flow Forward Market Price $ (36.45) $ 3.40 $ (7.55) SWEPCo Significant Unobservable Inputs March 31, 2023 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) FTRs $ 6.4 $ 0.6 Discounted Cash Flow Forward Market Price $ (21.10) $ 3.04 $ (4.75) December 31, 2022 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) FTRs $ 14.6 $ 0.4 Discounted Cash Flow Forward Market Price $ (36.45) $ 3.40 $ (7.55) (a) Represents market prices in dollars per MWh. (b) The weighted average is the product of the forward market price of the underlying commodity and volume weighted by term. The following table provides the measurement uncertainty of fair value measurements to increases (decreases) in significant unobservable inputs related to Energy Contracts and FTRs for the Registrants as of March 31, 2023 and December 31, 2022: Uncertainty of Fair Value Measurements Significant Unobservable Input Position Change in Input Impact on Fair Value Forward Market Price Buy Increase (Decrease) Higher (Lower) Forward Market Price Sell Increase (Decrease) Lower (Higher)

Income Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2023
Income Taxes	INCOME TAXES The disclosures in this note apply to all Registrants unless indicated otherwise. Effective Tax Rates (ETR) The Registrants’ interim ETR reflect the estimated annual ETR for 2023 and 2022, adjusted for tax expense associated with certain discrete items. The Registrants include the amortization of Excess ADIT not subject to normalization requirements in the annual estimated ETR when regulatory proceedings instruct the Registrants to provide the benefits of Tax Reform to customers over multiple interim periods. Certain regulatory proceedings instruct the Registrants to provide the benefits of Tax Reform to customers in a single period (e.g. by applying the Excess ADIT not subject to normalization requirements against an existing regulatory asset balance) and in these circumstances, the Registrants recognize the tax benefit discretely in the period recorded. The annual amount of Excess ADIT approved by the Registrant’s regulatory commissions may not impact the ETR ratably during each interim period due to the variability of pretax book income between interim periods and the application of an annual estimated ETR. The ETR for each of the Registrants are included in the following tables: Three Months Ended 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) % Three Months Ended March 31, 2022 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo U.S. Federal Statutory Rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % Increase (decrease) due to: State Income Tax, net of Federal Benefit 1.5 % 0.3 % 2.6 % 2.9 % 1.6 % 0.7 % 0.6 % 2.3 % Tax Reform Excess ADIT Reversal (6.6) % (2.0) % 0.3 % (5.8) % (17.3) % (7.8) % (15.3) % (4.9) % Production and Investment Tax Credits (8.0) % (0.2) % — % — % (1.4) % — % (26.2) % (23.1) % Flow Through 0.3 % 0.3 % 0.3 % 1.7 % (1.9) % 0.9 % 0.6 % (0.6) % AFUDC Equity (0.9) % (0.9) % (1.6) % (0.7) % (0.6) % (0.6) % (0.7) % (0.5) % Discrete Tax Adjustments (0.6) % — % — % (0.6) % — % — % — % — % Other 0.2 % (0.1) % — % — % (0.2) % — % (0.8) % 0.6 % Effective Income Tax Rate 6.9 % 18.4 % 22.6 % 18.5 % 1.2 % 14.2 % (20.8) % (5.2) % 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 and 2018 tax returns to December 31, 2023, to allow time for the current IRS audit to be completed including a refund claim approval by the Congressional Joint Committee on Taxation. The statute of limitations for the 2019 return is set to naturally expire in 2023 as well. The current IRS audit and associated refund claim evolved from a net operating loss carryback to 2015 that originated in the 2017 return. AEP has received and agreed to two IRS proposed adjustments on the 2017 tax return, which were immaterial. The exam is nearly complete, and AEP is currently working with the IRS to submit the refund claim to the Congressional Joint Committee on Taxation for resolution and final approval. AEP and subsidiaries file income tax returns in various state and local jurisdictions. These taxing authorities routinely examine the tax returns, and AEP and subsidiaries are currently under examination in several state and local jurisdictions. Generally, the statutes of limitations have expired for tax years prior to 2017. In addition, management is monitoring and continues to evaluate the potential impact of federal legislation and corresponding state conformity. Federal Legislation In August 2022, President Biden signed H.R. 5376 into law, commonly known as the Inflation Reduction Act of 2022 or IRA. Most notably this budget reconciliation legislation creates a 15% minimum tax on adjusted financial statement income (Corporate Alternative Minimum Tax or CAMT), extends and increases the value of PTCs and ITCs, adds a nuclear and clean hydrogen PTC, an energy storage ITC and allows the sale or transfer of tax credits to third parties for cash. As further significant guidance from Treasury and the IRS is expected on the tax provisions in the IRA, AEP will continue to monitor any issued guidance and evaluate the impact on future net income, cash flows and financial condition. In December 2022, the IRS released Notice 2023-7 addressing time sensitive issues related to the CAMT. The notice provided initial guidance that AEP can begin to rely on in 2023 and also stated that additional guidance is expected, of which AEP will continue to monitor and assess. Notably, the interim guidance in Notice 2023-7 confirmed the CAMT depreciation adjustment includes tax depreciation that is capitalized to inventory under §263A and recovered as part of cost of goods sold, providing significant relief to AEP’s potential CAMT exposure.

Financing Activities

Financing Activities	3 Months Ended
	Mar. 31, 2023
Financing Activities	12. FINANCING ACTIVITIES The disclosures in this note apply to all Registrants, unless indicated otherwise. Common Stock (Applies to AEP) At-the-Market (ATM) Program In 2020, AEP filed a prospectus supplement and executed an Equity Distribution Agreement, pursuant to which AEP may sell, from time to time, up to an aggregate of $1 billion of its common stock through an ATM offering program, including an equity forward sales component. The compensation paid to the selling agents by AEP may be up to 2% of the gross offering proceeds of the shares. There were no issuances under the ATM program for the three months ended March 31, 2023. Long-term Debt Outstanding (Applies to AEP) The following table details long-term debt outstanding, net of issuance costs and premiums or discounts: Type of Debt March 31, 2023 December 31, 2022 (in millions) Senior Unsecured Notes $ 32,654.3 $ 30,174.8 Pollution Control Bonds 1,770.4 1,770.2 Notes Payable 190.0 269.7 Securitization Bonds 463.4 487.8 Spent Nuclear Fuel Obligation (a) 288.8 285.6 Junior Subordinated Notes (b) 2,383.3 2,381.3 Other Long-term Debt 1,394.0 1,431.6 Total Long-term Debt Outstanding 39,144.2 36,801.0 Long-term Debt Due Within One Year 2,905.1 2,486.4 Long-term Debt $ 36,239.1 $ 34,314.6 (a) Pursuant to the Nuclear Waste Policy Act of 1982, I&M, a nuclear licensee, has an obligation to the United States Department of Energy for SNF disposal. The obligation includes a one-time fee for nuclear fuel consumed prior to April 7, 1983. Trust fund assets related to this obligation were $335 million and $330 million as of March 31, 2023 and December 31, 2022, respectively, and are included in Spent Nuclear Fuel and Decommissioning Trusts on the balance sheets. (b) See “Equity Units” section below for additional information. Long-term Debt Activity Long-term debt and other securities issued, retired and principal payments made during the first three months of 2023 are shown in the following tables: Principal Interest Company Type of Debt Amount (a) Rate Due Date Issuances: (in millions) (%) AEP Senior Unsecured Notes $ 850.0 5.63 2033 AEPTCo Senior Unsecured Notes 700.0 5.40 2053 I&M Senior Unsecured Notes 500.0 5.63 2053 PSO Senior Unsecured Notes 475.0 5.25 2033 SWEPCo Senior Unsecured Notes 350.0 5.30 2033 Non-Registrant: Transource Energy Other Long-term Debt 1.0 Variable 2025 Total Issuances $ 2,876.0 (a) Amounts indicated on the statements of cash flows are net of issuance costs and premium or discount and will not tie to the issuance amounts. Principal Interest Company Type of Debt Amount Paid Rate Due Date Retirements and Principal Payments: (in millions) (%) AEP Texas Senior Unsecured Notes $ 125.0 3.09 2023 AEP Texas Securitization Bonds 11.7 2.06 2025 APCo Securitization Bonds 9.7 2.01 2023 APCo Securitization Bonds 3.3 3.77 2028 I&M Senior Unsecured Notes 250.0 3.20 2023 I&M Notes Payable 0.6 Variable 2023 I&M Notes Payable 1.2 Variable 2024 I&M Notes Payable 4.6 Variable 2025 I&M Notes Payable 3.9 0.93 2025 I&M Notes Payable 6.8 3.44 2026 I&M Notes Payable 6.7 5.93 2027 I&M Other Long-term Debt 0.5 6.00 2025 PSO Other Long-term Debt 0.1 3.00 2027 SWEPCo Notes Payable 25.0 6.37 2024 SWEPCo Notes Payable 30.9 4.58 2032 SWEPCo Other Long-term Debt 38.2 4.68 2028 Non-Registrant: Transource Energy Senior Unsecured Notes 1.3 2.75 2050 Total Retirements and Principal Payments $ 519.5 Long-term Debt Subsequent Event In April 2023, I&M retired $8 million of Notes Payable related to DCC Fuel. Equity Units (Applies to AEP) 2020 Equity Units In August 2020, AEP issued 17 million Equity Units initially in the form of corporate units, at a stated amount of $50 per unit, for a total stated amount of $850 million. Net proceeds from the issuance were approximately $833 million. The proceeds were used to support AEP’s overall capital expenditure plans. Each corporate unit represents a 1/20 undivided beneficial ownership interest in $1,000 principal amount of AEP’s 1.30% Junior Subordinated Notes (notes) due in 2025 and a forward equity purchase contract which settles after three years in August 2023. The notes are expected to be remarketed in 2023, at which time the interest rate will reset at the then current market rate. Investors may choose to remarket their notes to receive the remarketing proceeds and use those funds to settle the forward equity purchase contract, or accept the remarketed debt and use other funds for the equity purchase. If the remarketing is unsuccessful, investors have the right to put their notes to AEP at a price equal to the principal. The Equity Units carry an annual distribution rate of 6.125%, which is comprised of a quarterly coupon rate of interest of 1.30% and a quarterly forward equity purchase contract payment of 4.825%. Each forward equity purchase contract obligates the holder to purchase, and AEP to sell, for $50 a number of shares in common stock in accordance with the conversion ratios set forth below (subject to an anti-dilution adjustment): • If the AEP common stock market price is equal to or greater than $99.95: 0.5003 shares per contract. • If the AEP common stock market price is less than $99.95 but greater than $83.29: a number of shares per contract equal to $50 divided by the applicable market price. The holder receives a variable number of shares at $50. • If the AEP common stock market price is less than or equal to $83.29: 0.6003 shares per contract. A holder’s ownership interest in the notes is pledged to AEP to secure the holder’s obligation under the related forward equity purchase contract. If a holder of the forward equity purchase contract chooses at any time to no longer be a holder of the notes, such holder’s obligation under the forward equity purchase contract must be secured by a U.S. Treasury security which must be equal to the aggregate principal amount of the notes. At the time of issuance, the $850 million of notes were recorded within Long-term Debt on the balance sheets. The present value of the purchase contract payments of $121 million were recorded in Deferred Credits and Other Noncurrent Liabilities with a current portion in Other Current Liabilities at the time of issuance, representing the obligation to make forward equity contract payments, with an offsetting reduction to Paid-in Capital. The difference between the face value and present value of the purchase contract payments will be accreted to Interest Expense on the statements of income over the three year period ending in 2023. The liability recorded for the contract payments is considered non-cash and excluded from the statements of cash flows. Until settlement of the forward equity purchase contract, earnings per share dilution resulting from the equity unit issuance will be determined under the treasury stock method. The maximum amount of shares AEP will be required to issue to settle the purchase contract is 10,205,100 shares (subject to an anti-dilution adjustment). 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 0.0% of consolidated tangible net assets as of March 31, 2023. The method for calculating the consolidated tangible net assets is contractually-defined in the note purchase agreements. Dividend Restrictions Utility Subsidiaries’ Restrictions Parent depends on its utility subsidiaries to pay dividends to shareholders. AEP utility subsidiaries pay dividends to Parent provided funds are legally available. Various financing arrangements and regulatory requirements may impose certain restrictions on the ability of the subsidiaries to transfer funds to Parent in the form of dividends. All of the dividends declared by AEP’s utility subsidiaries that provide transmission or local distribution services are subject to a Federal Power Act requirement that prohibits the payment of dividends out of capital accounts in certain circumstances; payment of dividends is generally allowed out of retained earnings. The Federal Power Act also creates a reserve on earnings attributable to hydroelectric generation plants. Because of their ownership of such plants, this reserve applies to APCo and I&M. Certain AEP subsidiaries have credit agreements that contain covenants that limit their debt to capitalization ratio to 67.5%. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. The Federal Power Act restriction does not limit the ability of the AEP subsidiaries to pay dividends out of retained earnings. Parent Restrictions (Applies to AEP) The holders of AEP’s common stock are entitled to receive the dividends declared by the Board of Directors provided funds are legally available for such dividends. Parent’s income primarily derives from common stock equity in the earnings of its utility subsidiaries. Pursuant to the leverage restrictions in credit agreements, AEP must maintain a percentage of debt to total capitalization at a level that does not exceed 67.5%. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. Corporate Borrowing Program - AEP System (Applies to all Registrant Subsidiaries) The AEP System uses a corporate borrowing program to meet the short-term borrowing needs of AEP’s subsidiaries. The corporate borrowing program includes a Utility Money Pool, which funds AEP’s utility subsidiaries; a Nonutility Money Pool, which funds certain AEP nonutility subsidiaries; and direct borrowing from AEP. The AEP System Utility Money Pool operates in accordance with the terms and conditions of its agreement filed with the FERC. The amounts of outstanding loans to (borrowings from) the Utility Money Pool as of March 31, 2023 and December 31, 2022 are included in Advances to Affiliates and Advances from Affiliates, respectively, on the Registrant Subsidiaries’ balance sheets. The Utility Money Pool participants’ activity and corresponding authorized borrowing limits for the three months ended March 31, 2023 are described in the following table: Maximum Average Net Loans to Borrowings Maximum Borrowings Average (Borrowings from) Authorized from the Loans to the from the Loans to the the Utility Money Short-term Utility Utility Utility Utility Pool as of Borrowing Company Money Pool Money Pool Money Pool Money Pool March 31, 2023 Limit (in millions) AEP Texas $ 453.7 $ — $ 285.3 $ — $ (450.8) $ 500.0 AEPTCo 471.3 309.4 272.9 45.7 260.5 820.0 (a) APCo 373.6 19.8 285.3 18.9 (291.5) 500.0 I&M 475.3 82.9 212.5 28.1 60.0 500.0 OPCo 483.0 — 292.6 — (414.6) 500.0 PSO 375.0 121.5 321.7 74.8 (130.7) 400.0 SWEPCo 401.6 (b) — 353.9 — (18.8) 400.0 (a) Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions. (b) SWEPCo’s maximum borrowings from the Utility Money Pool exceeded the authorized short-term borrowing limit by $1.6 million on March 15, 2023. On March 16, 2023, SWEPCo’s borrowings from the Utility Money Pool were reduced below the $400 million authorized limit and borrowings have continued to remain below the authorized limit. The activity in the above table does not include short-term lending activity of certain AEP nonutility subsidiaries. AEP Texas’ wholly-owned subsidiary, AEP Texas North Generation Company, LLC and SWEPCo’s wholly-owned subsidiary, Mutual Energy SWEPCo, LLC participate in the Nonutility Money Pool. The amounts of outstanding loans to the Nonutility Money Pool as of March 31, 2023 and December 31, 2022 are included in Advances to Affiliates on the subsidiaries’ balance sheets. The Nonutility Money Pool participants’ activity for the three months ended March 31, 2023 is described in the following table: Maximum Loans Average Loans Loans to the Nonutility to the Nonutility to the Nonutility Money Pool as of Company Money Pool Money Pool March 31, 2023 (in millions) AEP Texas $ 6.9 $ 6.8 $ 6.8 SWEPCo 2.1 2.1 2.1 AEP has a direct financing relationship with AEPTCo to meet its short-term borrowing needs. The amounts of outstanding loans to and borrowings from AEP as of March 31, 2023 and December 31, 2022 are included in Advances to Affiliates and Advances from Affiliates, respectively, on AEPTCo’s balance sheets. AEPTCo’s direct borrowing and lending activity with AEP and corresponding authorized borrowing limit for the three months ended March 31, 2023 are described in the following table: Maximum Maximum Average Average Borrowings from Loans to Authorized Borrowings Loans Borrowings Loans AEP as of AEP as of Short-term from AEP to AEP from AEP to AEP March 31, 2023 March 31, 2023 Borrowing Limit (in millions) $ 29.4 $ 158.1 $ 3.1 $ 80.2 $ 1.6 $ 34.2 $ 50.0 (a) (a) Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions. The maximum and minimum interest rates for funds either borrowed from or loaned to the Utility Money Pool are summarized in the following table: Three Months Ended March 31, 2023 2022 Maximum Interest Rate 5.42 % 1.00 % Minimum Interest Rate 4.66 % 0.10 % The average interest rates for funds borrowed from and loaned to the Utility Money Pool are summarized for all Registrant Subsidiaries in the following table: Average Interest Rate for Funds Average Interest Rate for Funds Borrowed from the Utility Money Pool Loaned to the Utility Money Pool for Three Months Ended March 31, for Three Months Ended March 31, Company 2023 2022 2023 2022 AEP Texas 5.18 % 0.70 % — % — % AEPTCo 5.09 % 0.66 % 5.29 % 0.60 % APCo 5.14 % 0.55 % 5.12 % 0.62 % I&M 5.12 % 0.63 % 5.16 % 0.62 % OPCo 5.17 % 0.77 % — % 0.48 % PSO 4.84 % 0.69 % 5.11 % 0.65 % SWEPCo 5.12 % 0.98 % — % 0.55 % 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, 2023 Three Months Ended March 31, 2022 Maximum Minimum Average Maximum Minimum Average Interest Rate Interest Rate Interest Rate Interest Rate Interest Rate Interest Rate for Funds for Funds for Funds for Funds for Funds for Funds Loaned to Loaned to Loaned to Loaned to Loaned to Loaned to the Nonutility the Nonutility the Nonutility the Nonutility the Nonutility the Nonutility Company Money Pool Money Pool Money Pool Money Pool Money Pool Money Pool AEP Texas 5.42 % 4.66 % 5.12 % 1.00 % 0.46 % 0.62 % SWEPCo 5.42 % 4.66 % 5.13 % 1.00 % 0.46 % 0.62 % 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 2023 5.38 % 4.53 % 5.38 % 4.53 % 5.03 % 5.15 % 2022 1.00 % 0.46 % 1.00 % 0.46 % 0.66 % 0.60 % Short-term Debt (Applies to AEP and SWEPCo) Outstanding short-term debt was as follows: March 31, 2023 December 31, 2022 Outstanding Interest Outstanding Interest Company Type of Debt Amount Rate (a) Amount Rate (a) (dollars in millions) AEP Securitized Debt for Receivables (b) $ 750.0 5.05 % $ 750.0 4.67 % AEP Commercial Paper 1,981.1 5.20 % 2,862.2 4.80 % AEP Term Loan 500.0 5.67 % — — % AEP Term Loan 150.0 5.63 % 150.0 5.17 % AEP Term Loan 125.0 5.64 % 125.0 5.17 % AEP Term Loan 100.0 5.64 % 100.0 5.23 % AEP Term Loan — — % 125.0 4.87 % SWEPCo Notes Payable 16.0 7.27 % — — % AEP Total Short-term Debt $ 3,622.1 $ 4,112.2 (a) Weighted-average rate as of March 31, 2023 and December 31, 2022, respectively. (b) Amount of securitized debt for receivables as accounted for under the “Transfers and Servicing” accounting guidance. Credit Facilities For a discussion of credit facilities, see “Letters of Credit” section of Note 5. Securitized Accounts Receivables – AEP Credit (Applies to AEP) AEP Credit has a receivables securitization agreement with bank conduits. Under the securitization agreement, AEP Credit receives financing from the bank conduits for the interest in the receivables AEP Credit acquires from affiliated utility subsidiaries. These securitized transactions allow AEP Credit to repay its outstanding debt obligations, continue to purchase the operating companies’ receivables and accelerate AEP Credit’s cash collections. AEP Credit’s receivables securitization agreement provides a commitment of $750 million from bank conduits to purchase receivables and includes a $125 million and a $625 million facility, both of which expire in September 2024. As of March 31, 2023, the affiliated utility subsidiaries were in compliance with all requirements under the agreement. SWEPCo temporarily eased credit policies from August 2022 through October 2022 to assist customers with higher than normal bills driven by increased fuel costs and, in turn, experienced higher than normal aged receivables. In response, in January 2023, AEP Credit amended its receivables securitization agreement to increase the eligibility criteria related to their aged receivables requirements to ensure SWEPCo remains in compliance. Accounts receivable information for AEP Credit was as follows: Three Months Ended March 31, 2023 2022 (dollars in millions) Effective Interest Rates on Securitization of Accounts Receivable 4.86 % 0.31 % Net Uncollectible Accounts Receivable Written-Off $ 6.9 $ 7.4 March 31, 2023 December 31, 2022 (in millions) Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts $ 1,091.8 $ 1,167.7 Short-term – Securitized Debt of Receivables 750.0 750.0 Delinquent Securitized Accounts Receivable 49.3 44.2 Bad Debt Reserves Related to Securitization 41.2 39.7 Unbilled Receivables Related to Securitization 287.3 360.9 AEP Credit’s delinquent customer accounts receivable represent accounts greater than 30 days past due. Securitized Accounts Receivables – AEP Credit (Applies to all Registrant Subsidiaries except AEP Texas and AEPTCo) Under this sale of receivables arrangement, the Registrant Subsidiaries sell, without recourse, certain of their customer accounts receivable and accrued unbilled revenue balances to AEP Credit and are charged a fee based on AEP Credit’s financing costs, administrative costs and uncollectible accounts experience for each Registrant Subsidiary’s receivables. APCo does not have regulatory authority to sell its West Virginia accounts receivable. KPCo ceased selling accounts receivable to AEP Credit in the first quarter of 2022, based on the expected sale to Liberty. As a result, in the first quarter of 2022, KPCo recorded an allowance for uncollectible accounts on its balance sheet for those receivables no longer sold to AEP Credit. The costs of customer accounts receivable sold are reported in Other Operation expense on the Registrant Subsidiaries’ statements of income. The Registrant Subsidiaries manage and service their customer accounts receivable, which are sold to AEP Credit. AEP Credit securitizes the eligible receivables for the operating companies and retains the remainder. The amount of accounts receivable and accrued unbilled revenues under the sale of receivables agreements were: Company March 31, 2023 December 31, 2022 (in millions) APCo $ 195.5 $ 194.4 I&M 167.9 166.9 OPCo 457.5 478.6 PSO 134.2 155.5 SWEPCo 157.8 194.0 The fees paid to AEP Credit for customer accounts receivable sold were: Three Months Ended March 31, Company 2023 2022 (in millions) APCo $ 4.9 $ 1.3 I&M 3.9 1.7 OPCo 7.3 7.4 PSO 3.2 0.9 SWEPCo 4.3 1.3 The proceeds on the sale of receivables to AEP Credit were: Three Months Ended March 31, Company 2023 2022 (in millions) APCo $ 506.2 $ 415.5 I&M 525.4 513.4 OPCo 884.4 716.6 PSO 416.3 363.4 SWEPCo 437.6 394.5

Variable Interest Entities

Variable Interest Entities	3 Months Ended
	Mar. 31, 2023
Variable Interest Entities	VARIABLE INTEREST ENTITIES The disclosures in this note apply to AEP unless indicated otherwise. The accounting guidance for “Variable Interest Entities” is a consolidation model that considers if a company has a variable interest in a VIE. A VIE is a legal entity that possesses any of the following conditions: the entity’s equity at risk is not sufficient to permit the legal entity to finance its activities without additional subordinated financial support, equity owners are unable to direct the activities that most significantly impact the legal entity’s economic performance (or they possess disproportionate voting rights in relation to the economic interest in the legal entity), or the equity owners lack the obligation to absorb the legal entity’s expected losses or the right to receive the legal entity’s expected residual returns. Entities are required to consolidate a VIE when it is determined that they have a controlling financial interest in a VIE and therefore, are the primary beneficiary of that VIE, as defined by the accounting guidance for “Variable Interest Entities.” In determining whether AEP is the primary beneficiary of a VIE, management considers whether AEP has the power to direct the most significant activities of the VIE and is obligated to absorb losses or receive the expected residual returns that are significant to the VIE. AEP holds ownership interests in businesses with varying ownership structures. AEP has not provided material financial or other support that was not previously contractually required to any of its consolidated VIEs. If an entity is determined not to be a VIE, or if the entity is determined to be a VIE and AEP is not deemed to be the primary beneficiary, the entity is accounted for under the equity method of accounting. Consolidated Variable Interests Entities The Annual Report on Form 10-K for the year ended December 31, 2022 includes a detailed discussion of the Registrants’ consolidated VIEs. There were no reconsideration events with respect to those VIEs in the first quarter of 2023. The balances below represent the assets and liabilities of consolidated VIEs. These balances include intercompany transactions that are eliminated upon consolidation. American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities March 31, 2023 Registrant Subsidiaries SWEPCo I&M AEP Texas Transition Funding AEP Texas Restoration Funding APCo (in millions) ASSETS Current Assets $ 23.0 $ 84.3 $ 43.0 $ 13.4 $ 6.1 Net Property, Plant and Equipment — 154.3 — — — Other Noncurrent Assets 135.1 76.0 125.2 (a) 163.0 (b) 157.4 (c) Total Assets $ 158.1 $ 314.6 $ 168.2 $ 176.4 $ 163.5 LIABILITIES AND EQUITY Current Liabilities $ 33.5 $ 84.2 $ 74.3 $ 30.5 $ 28.1 Noncurrent Liabilities 124.2 230.4 89.6 144.7 133.5 Equity 0.4 — 4.3 1.2 1.9 Total Liabilities and Equity $ 158.1 $ 314.6 $ 168.2 $ 176.4 $ 163.5 (a) Includes an intercompany item eliminated in consolidation of $14 million. (b) Includes an intercompany item eliminated in consolidation of $7 million . (c) Includes an intercompany item eliminated in consolidation of $2 million . American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities March 31, 2023 Other Consolidated VIEs AEP Credit Protected Transource Energy (in millions) ASSETS Current Assets $ 1,092.6 $ 203.2 $ 22.1 Net Property, Plant and Equipment — — 495.1 Other Noncurrent Assets 8.9 — 6.8 Total Assets $ 1,101.5 $ 203.2 $ 524.0 LIABILITIES AND EQUITY Current Liabilities $ 1,043.2 $ 50.2 $ 33.4 Noncurrent Liabilities 0.9 78.0 219.0 Equity 57.4 75.0 271.6 Total Liabilities and Equity $ 1,101.5 $ 203.2 $ 524.0 Apple Blossom, Black Oak, Santa Rita East and Dry Lake are consolidated VIEs included in the plan of sale of the Competitive Contracted Renewables Portfolio. See the “Planned Disposition of the Competitive Contracted Renewables Portfolio” section of Note 6 for the assets and liabilities classified Held for Sale as of March 31, 2023 inclusive of the assets and liabilities of the aforementioned consolidated VIEs. American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities December 31, 2022 Registrant Subsidiaries SWEPCo I&M AEP Texas Transition Funding AEP Texas Restoration Funding APCo (in millions) ASSETS Current Assets $ 108.3 $ 90.2 $ 27.0 $ 21.1 $ 13.5 Net Property, Plant and Equipment 7.2 179.1 — — — Other Noncurrent Assets 130.0 94.0 140.9 (a) 168.8 (b) 164.6 (c) Total Assets $ 245.5 $ 363.3 $ 167.9 $ 189.9 $ 178.1 LIABILITIES AND EQUITY Current Liabilities $ 25.4 $ 90.0 $ 73.2 $ 31.3 $ 29.3 Noncurrent Liabilities 219.4 273.3 90.4 157.4 146.9 Equity 0.7 — 4.3 1.2 1.9 Total Liabilities and Equity $ 245.5 $ 363.3 $ 167.9 $ 189.9 $ 178.1 (a) Includes an intercompany item eliminated in consolidation of $16 million . (b) Includes an intercompany item eliminated in consolidation of $7 million . (c) Includes an intercompany item eliminated in consolidation of $2 million . American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities December 31, 2022 Other Consolidated VIEs AEP Credit Protected Transource Energy Apple Blossom and Black Oak Santa Rita East Dry Lake (in millions) ASSETS Current Assets $ 1,181.0 $ 194.5 $ 23.5 $ 8.3 $ 21.3 $ 4.0 Net Property, Plant and Equipment — — 482.3 216.5 421.6 142.6 Other Noncurrent Assets 9.0 0.3 2.7 13.6 0.1 0.3 Total Assets $ 1,190.0 $ 194.8 $ 508.5 $ 238.4 $ 443.0 $ 146.9 LIABILITIES AND EQUITY Current Liabilities $ 1,087.8 $ 46.4 $ 22.8 $ 4.5 $ 9.6 $ 1.0 Noncurrent Liabilities 0.9 79.1 218.6 5.4 7.3 0.7 Equity 101.3 69.3 267.1 228.5 426.1 145.2 Total Liabilities and Equity $ 1,190.0 $ 194.8 $ 508.5 $ 238.4 $ 443.0 $ 146.9 Significant Variable Interests in Non-Consolidated VIEs and Significant Equity Method Investments The Annual Report on Form 10-K for the year ended December 31, 2022 includes a detailed discussion of significant variable interests in non-consolidated VIEs and other significant equity method investments. There were no reconsideration events or material changes in carrying values as of March 31, 2023.

Revenue from Contracts with Cus

Revenue from Contracts with Customers	3 Months Ended
	Mar. 31, 2022
Revenue from Contract with Customer	14. REVENUE FROM CONTRACTS WITH CUSTOMERS The disclosures in this note apply to all Registrants, unless indicated otherwise. Disaggregated Revenues from Contracts with Customers The tables below represent AEP’s reportable segment revenues from contracts with customers, net of respective provisions for refund, by type of revenue: Three Months Ended 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, 2022 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation & Marketing Corporate and Other Reconciling Adjustments AEP Consolidated (in millions) Retail Revenues: Residential Revenues $ 1,150.8 $ 600.6 $ — $ — $ — $ — $ 1,751.4 Commercial Revenues 572.9 289.7 — — — — 862.6 Industrial Revenues 563.0 133.3 — — — (0.4) 695.9 Other Retail Revenues 47.4 11.6 — — — — 59.0 Total Retail Revenues 2,334.1 1,035.2 — — — (0.4) 3,368.9 Wholesale and Competitive Retail Revenues: Generation Revenues 187.2 — — 40.3 — — 227.5 Transmission Revenues (a) 105.3 154.9 414.5 — — (361.8) 312.9 Renewable Generation Revenues (b) — — — 22.4 — (0.8) 21.6 Retail, Trading and Marketing Revenues (c) — — — 388.8 3.2 (9.0) 383.0 Total Wholesale and Competitive Retail Revenues 292.5 154.9 414.5 451.5 3.2 (371.6) 945.0 Other Revenues from Contracts with Customers (b) 61.6 53.8 (0.2) 8.6 13.9 (18.6) 119.1 Total Revenues from Contracts with Customers 2,688.2 1,243.9 414.3 460.1 17.1 (390.6) 4,433.0 Other Revenues: Alternative Revenue Programs (d) (0.8) (3.4) (2.9) — — 1.3 (5.8) Other Revenues (b) (e) — 6.3 — 159.2 2.8 (2.9) 165.4 Total Other Revenues (0.8) 2.9 (2.9) 159.2 2.8 (1.6) 159.6 Total Revenues $ 2,687.4 $ 1,246.8 $ 411.4 $ 619.3 $ 19.9 $ (392.2) $ 4,592.6 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $327 million. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $9 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, 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. Three Months Ended March 31, 2022 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 141.9 $ — $ 458.0 $ 231.8 $ 458.7 $ 165.9 $ 175.9 Commercial Revenues 94.9 — 153.9 126.6 194.7 97.5 130.5 Industrial Revenues 30.6 — 153.8 136.5 102.7 78.6 84.7 Other Retail Revenues 8.2 — 20.6 1.3 3.3 21.2 2.4 Total Retail Revenues 275.6 — 786.3 496.2 759.4 363.2 393.5 Wholesale Revenues: Generation Revenues (a) — — 56.2 90.4 — 9.5 61.2 Transmission Revenues (b) 133.1 400.3 41.1 8.8 21.8 9.6 35.2 Total Wholesale Revenues 133.1 400.3 97.3 99.2 21.8 19.1 96.4 Other Revenues from Contracts with Customers (c) 9.3 (0.3) 24.3 29.9 44.6 5.4 5.3 Total Revenues from Contracts with Customers 418.0 400.0 907.9 625.3 825.8 387.7 495.2 Other Revenues: Alternative Revenue Programs (d) (1.3) 0.4 (0.7) — (2.1) (0.1) (0.4) Other Revenues (e) — — 0.1 (0.1) 6.3 — — Total Other Revenues (1.3) 0.4 (0.6) (0.1) 4.2 (0.1) (0.4) Total Revenues $ 416.7 $ 400.4 $ 907.3 $ 625.2 $ 830.0 $ 387.6 $ 494.8 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $36 million primarily related to the PPA with KGPCo. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $323 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $10 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, 2023. Fixed performance obligations primarily include electricity sales for fixed amounts of energy and stand ready services into PJM’s RPM market. The Registrants elected to apply the exemption to not disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less. Due to the annual establishment of revenue requirements, transmission revenues are excluded from the table below. The Registrant Subsidiaries amounts shown in the table below include affiliated and nonaffiliated revenues. Company 2023 2024-2025 2026-2027 After 2027 Total (in millions) AEP $ 63.4 $ 160.5 $ 137.1 $ 61.0 $ 422.0 APCo 12.1 32.2 24.3 11.7 80.3 I&M 3.4 9.2 9.2 4.6 26.4 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, 2023 and December 31, 2022. When the Registrants receive consideration, or such consideration is unconditionally due from a customer prior to transferring goods or services to the customer under the terms of a sales contract, they recognize a contract liability on the balance sheets in the amount of that consideration. Revenue for such consideration is subsequently recognized in the period or periods in which the remaining performance obligations in the contract are satisfied. The Registrants’ contract liabilities typically arise from services provided under joint use agreements for utility poles. The Registrants did not have material contract liabilities as of March 31, 2023 and December 31, 2022. Accounts Receivable from Contracts with Customers Accounts receivable from contracts with customers are presented on the Registrant Subsidiaries’ balance sheets within the Accounts Receivable - Customers line item. The Registrant Subsidiaries’ balances for receivables from contracts that are not recognized in accordance with the accounting guidance for “Revenue from Contracts with Customers” included in Accounts Receivable - Customers were not material as of March 31, 2023 and December 31, 2022. See “Securitized Accounts Receivable - AEP Credit” section of Note 12 for additional information. The following table represents the amount of affiliated accounts receivable from contracts with customers included in Accounts Receivable - Affiliated Companies on the Registrant Subsidiaries’ balance sheets: Company March 31, 2023 December 31, 2022 (in millions) AEP Texas $ — $ 0.1 AEPTCo 122.5 113.8 APCo 65.1 64.5 I&M 56.4 75.3 OPCo 57.5 49.9 PSO 12.7 18.8 SWEPCo 19.6 19.1

Significant Accounting Matters

Significant Accounting Matters (Policies)	3 Months Ended
	Mar. 31, 2023
Basis of Accounting	General The unaudited condensed financial statements and footnotes were prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X of the SEC. Accordingly, they do not include all of the information and footnotes required by GAAP for complete annual financial statements. In the opinion of management, the unaudited condensed interim financial statements reflect all normal and recurring accruals and adjustments necessary for a fair statement of the net income, financial position and cash flows for the interim periods for each Registrant. Net income for the three months ended March 31, 2023 is not necessarily indicative of results that may be expected for the year ending December 31, 2023. The condensed financial statements are unaudited and should be read in conjunction with the audited 2022 financial statements and notes thereto, which are included in the Registrants’ Annual Reports on Form 10-K as filed with the SEC on February 23, 2023.
Earnings Per Share	Earnings Per Share (EPS) (Applies to AEP) Basic EPS is calculated by dividing net earnings available to common shareholders by the weighted-average number of common shares outstanding during the period. Diluted EPS is calculated by adjusting the weighted-average outstanding common shares, assuming conversion of all potentially dilutive stock awards.

Derivatives and Hedging (Polici

Derivatives and Hedging (Policies)	3 Months Ended
	Mar. 31, 2023
Derivatives and Hedging	OBJECTIVES FOR UTILIZATION OF DERIVATIVE INSTRUMENTS AEPSC is agent for and transacts on behalf of certain AEP subsidiaries, including the Registrant Subsidiaries. AEPEP is agent for and transacts on behalf of other AEP subsidiaries. The Registrants are exposed to certain market risks as major power producers and participants in the electricity, capacity, natural gas, coal and emission allowance markets. These risks include commodity price risks which may be subject to capacity risk, interest rate risk and credit risk. These risks represent the risk of loss that may impact the Registrants due to changes in the underlying market prices or rates. Management utilizes derivative instruments to manage these risks. STRATEGIES FOR UTILIZATION OF DERIVATIVE INSTRUMENTS TO ACHIEVE OBJECTIVES Risk Management Strategies The strategy surrounding the use of derivative instruments primarily focuses on managing risk exposures, future cash flows and creating value utilizing both economic and formal hedging strategies. The risk management strategies also include the use of derivative instruments for trading purposes which focus on seizing market opportunities to create value driven by expected changes in the market prices of the commodities. To accomplish these objectives, the Registrants primarily employ risk management contracts including physical and financial forward purchase-and-sale contracts and, to a lesser extent, OTC swaps and options. Not all risk management contracts meet the definition of a derivative under the accounting guidance for “Derivatives and Hedging.” Derivative risk management contracts elected normal under the normal purchases and normal sales scope exception are not subject to the requirements of this accounting guidance. The Registrants utilize power, capacity, coal, natural gas, interest rate and, to a lesser extent, heating oil, gasoline and other commodity contracts to manage the risk associated with the energy business. The Registrants utilize interest rate derivative contracts in order to manage the interest rate exposure associated with the commodity portfolio. For disclosure purposes, such risks are grouped as “Commodity,” as these risks are related to energy risk management activities. The Registrants also utilize derivative contracts to manage interest rate risk associated with debt financing. For disclosure purposes, these risks are grouped as “Interest Rate.” The amount of risk taken is determined by the Commercial Operations, Energy Supply and Finance groups in accordance with established risk management policies as approved by the Finance Committee of the Board of Directors. Fair Value Hedging Strategies (Applies to AEP) Parent enters into interest rate derivative transactions as part of an overall strategy to manage the mix of fixed-rate and floating-rate debt. Certain interest rate derivative transactions effectively modify exposure to interest rate risk by converting a portion of fixed-rate debt to a floating-rate. Provided specific criteria are met, these interest rate derivatives may be designated as fair value hedges. Cash Flow Hedging Strategies The Registrants utilize cash flow hedges on certain derivative transactions for the purchase and sale of power (“Commodity”) in order to manage the variable price risk related to forecasted purchases and sales. Management monitors the potential impacts of commodity price changes and, where appropriate, enters into derivative transactions to protect profit margins for a portion of future electricity sales and purchases. The Registrants do not hedge all commodity price risk. The Registrants utilize a variety of interest rate derivative transactions in order to manage interest rate risk exposure. The Registrants also utilize interest rate derivative contracts to manage interest rate exposure related to future borrowings of fixed-rate debt. The Registrants do not hedge all interest rate exposure. ACCOUNTING FOR DERIVATIVE INSTRUMENTS AND THE IMPACT ON THE FINANCIAL STATEMENTS The accounting guidance for “Derivatives and Hedging” requires recognition of all qualifying derivative instruments as either assets or liabilities on the balance sheets at fair value. The fair values of derivative instruments accounted for using MTM accounting or hedge accounting are based on exchange prices and broker quotes. If a quoted market price is not available, the estimate of fair value is based on the best information available including valuation models that estimate future energy prices based on existing market and broker quotes and other assumptions. In order to determine the relevant fair values of the derivative instruments, the Registrants apply valuation adjustments for discounting, liquidity and credit quality. Credit risk is the risk that a counterparty will fail to perform on the contract or fail to pay amounts due. Liquidity risk represents the risk that imperfections in the market will cause the price to vary from estimated fair value based upon prevailing market supply and demand conditions. Since energy markets are imperfect and volatile, there are inherent risks related to the underlying assumptions in models used to fair value risk management contracts. Unforeseen events may cause reasonable price curves to differ from actual price curves throughout a contract’s term and at the time a contract settles. Consequently, there could be significant adverse or favorable effects on future net income and cash flows if market prices are not consistent with management’s estimates of current market consensus for forward prices in the current period. This is particularly true for longer term contracts. Cash flows may vary based on market conditions, margin requirements and the timing of settlement of risk management contracts. Certain qualifying derivative instruments have been designated as normal purchase or normal sale contracts, as provided in the accounting guidance for “Derivatives and Hedging.” Derivative contracts that have been designated as normal purchases or normal sales under that accounting guidance are not subject to MTM accounting treatment and are recognized on the statements of income on an accrual basis. The accounting for the changes in the fair value of a derivative instrument depends on whether it qualifies for and has been designated as part of a hedging relationship and further, on the type of hedging relationship. Depending on the exposure, management designates a hedging instrument as a fair value hedge or a cash flow hedge. For contracts that have not been designated as part of a hedging relationship, the accounting for changes in fair value depends on whether the derivative instrument is held for trading purposes. Unrealized and realized gains and losses on derivative instruments held for trading purposes are included in revenues on a net basis on the statements of income. Unrealized and realized gains and losses on derivative instruments not held for trading purposes are included in revenues or expenses on the statements of income depending on the relevant facts and circumstances. Certain derivatives that economically hedge future commodity risk are recorded in the same line item on the statements of income as that of the associated risk being hedged. However, unrealized and some realized gains and losses in regulated jurisdictions for both trading and non-trading derivative instruments are recorded as regulatory assets (for losses) or regulatory liabilities (for gains) in accordance with the accounting guidance for “Regulated Operations.” Accounting for Fair Value Hedging Strategies (Applies to AEP) For fair value hedges (i.e. hedging the exposure to changes in the fair value of an asset, liability or an identified portion thereof attributable to a particular risk), the gain or loss on the derivative instrument as well as the offsetting gain or loss on the hedged item associated with the hedged risk impacts net income during the period of change. AEP records realized and unrealized gains or losses on interest rate swaps that are designated and qualify for fair value hedge accounting treatment and any offsetting changes in the fair value of the debt being hedged in Interest Expense on the statements of income. Accounting for Cash Flow Hedging Strategies (Applies to AEP, AEP Texas, APCo, I&M, PSO and SWEPCo) For cash flow hedges (i.e. hedging the exposure to variability in expected future cash flows that is attributable to a particular risk), the Registrants initially report the gain or loss on the derivative instrument as a component of Accumulated Other Comprehensive Income (Loss) on the balance sheets until the period the hedged item affects net income. Credit Risk Management mitigates credit risk in wholesale marketing and trading activities by assessing the creditworthiness of potential counterparties before entering into transactions with them and continuing to evaluate their creditworthiness on an ongoing basis. Management uses credit agency ratings and current market-based qualitative and quantitative data as well as financial statements to assess the financial health of counterparties on an ongoing basis. Master agreements are typically used to facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Collateral requirements in the form of cash, letters of credit and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. Some master agreements include margining, which requires a counterparty to post cash or letters of credit in the event exposure exceeds the established threshold. The threshold represents an unsecured credit limit which may be supported by a parental/affiliate guaranty, as determined in accordance with AEP’s credit policy. In addition, master agreements allow for termination and liquidation of all positions in the event of a default including a failure or inability to post collateral when required. Credit-Risk-Related Contingent Features Credit Downgrade Triggers (Applies to AEP, APCo, I&M, PSO and SWEPCo)

Fair Value Measurements (Polici

Fair Value Measurements (Policies)	3 Months Ended
	Mar. 31, 2023
Valuation Techniques	Fair Value Hierarchy and Valuation Techniques The accounting guidance for “Fair Value Measurements and Disclosures” establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). Where observable inputs are available for substantially the full term of the asset or liability, the instrument is categorized in Level 2. When quoted market prices are not available, pricing may be completed using comparable securities, dealer values, operating data and general market conditions to determine fair value. Valuation models utilize various inputs such as commodity, interest rate and, to a lesser degree, volatility and credit that include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, market corroborated inputs (i.e. inputs derived principally from, or correlated to, observable market data) and other observable inputs for the asset or liability. For commercial activities, exchange-traded derivatives, namely futures contracts, are generally fair valued based on unadjusted quoted prices in active markets and are classified as Level 1. Level 2 inputs primarily consist of OTC broker quotes in moderately active or less active markets, as well as exchange-traded derivatives where there is insufficient market liquidity to warrant inclusion in Level 1. Management verifies price curves using these broker quotes and classifies these fair values within Level 2 when substantially all of the fair value can be corroborated. Management typically obtains multiple broker quotes, which are nonbinding in nature but are based on recent trades in the marketplace. When multiple broker quotes are obtained, the quoted bid and ask prices are averaged. In certain circumstances, a broker quote may be discarded if it is a clear outlier. Management uses a historical correlation analysis between the broker quoted location and the illiquid locations. If the points are highly correlated, these locations are included within Level 2 as well. Certain OTC and bilaterally executed derivative instruments are executed in less active markets with a lower availability of pricing information. Illiquid transactions, complex structured transactions, FTRs and counterparty credit risk may require nonmarket-based inputs. Some of these inputs may be internally developed or extrapolated and utilized to estimate fair value. When such inputs have a significant impact on the measurement of fair value, the instrument is categorized as Level 3. The main driver of contracts being classified as Level 3 is the inability to substantiate energy price curves in the market. A portion of the Level 3 instruments have been economically hedged which limits potential earnings volatility. AEP utilizes its trustee’s external pricing service to estimate the fair value of the underlying investments held in the nuclear trusts. AEP’s investment managers review and validate the prices utilized by the trustee to determine fair value. AEP’s management performs its own valuation testing to verify the fair values of the securities. AEP receives audit reports of the trustee’s operating controls and valuation processes. Assets in the nuclear trusts, cash and cash equivalents, other temporary investments restricted cash for securitized funding are classified using the following methods. Equities are classified as Level 1 holdings if they are actively traded on exchanges. Items classified as Level 1 are investments in money market funds, fixed income and equity mutual funds and equity securities. They are valued based on observable inputs, primarily unadjusted quoted prices in active markets for identical assets. Items classified as Level 2 are primarily investments in individual fixed income securities. Fixed income securities generally do not trade on exchanges and do not have an official closing price but their valuation inputs are based on observable market data. Pricing vendors calculate bond valuations using financial models and matrices. The models use observable inputs including yields on benchmark securities, quotes by securities brokers, rating agency actions, discounts or premiums on securities compared to par prices, changes in yields for U.S. Treasury securities, corporate actions by bond issuers, prepayment schedules and histories, economic events and, for certain securities, adjustments to yields to reflect changes in the rate of inflation. Other securities with model-derived valuation inputs that are observable are also classified as Level 2 investments. Investments with unobservable valuation inputs are classified as Level 3 investments.
Fair Values of Long-term Debt	Fair Value Measurements of Long-term Debt (Applies to all Registrants) The fair values of Long-term Debt are based on quoted market prices, without credit enhancements, for the same or similar issues and the current interest rates offered for instruments with similar maturities classified as Level 2 measurement inputs. These instruments are not marked-to-market. The estimates presented are not necessarily indicative of the amounts that could be realized in a current market exchange. The fair value of AEP’s Equity Units (Level 1) are valued based on publicly traded securities issued by AEP.
Trust Assets for Decommissioning and Spent Nuclear Fuel Disposal	Fair Value Measurements of Trust Assets for Decommissioning and SNF Disposal (Applies to AEP and I&M) Nuclear decommissioning and SNF trust funds represent funds that regulatory commissions allow I&M to collect through rates to fund future decommissioning and SNF disposal liabilities. By rules or orders, the IURC, the MPSC and the FERC established investment limitations and general risk management guidelines. In general, limitations include: • Acceptable investments (rated investment grade or above when purchased). • Maximum percentage invested in a specific type of investment. • Prohibition of investment in obligations of AEP, I&M or their affiliates. • Withdrawals permitted only for payment of decommissioning costs and trust expenses. I&M maintains trust funds for each regulatory jurisdiction. Regulatory approval is required to withdraw decommissioning funds. These funds are managed by an external investment manager that must comply with the guidelines and rules of the applicable regulatory authorities. The trust assets are invested to optimize the net of tax earnings of the trust giving consideration to liquidity, risk, diversification and other prudent investment objectives. I&M records securities held in these trust funds in Spent Nuclear Fuel and Decommissioning Trusts on its balance sheets. I&M records these securities at fair value. I&M classifies debt securities in the trust funds as available-for-sale due to their long-term purpose. Other-than-temporary impairments for investments in debt securities are considered realized losses as a result of securities being managed by an external investment management firm. The external investment management firm makes specific investment decisions regarding the debt and equity investments held in these trusts and generally intends to sell debt securities in an unrealized loss position as part of a tax optimization strategy. Impairments
Fair Value Assets and Liabilities Measured on Recurring Basis	Fair Value Measurements of Financial Assets and Liabilities The following tables set forth, by level within the fair value hierarchy, the Registrants’ financial assets and liabilities that were accounted for at fair value on a recurring basis. As required by the accounting guidance for “Fair Value Measurements and Disclosures,” financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. Management’s assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. There have not been any significant changes in management’s valuation techniques.

Income Taxes (Policies)

Income Taxes (Policies)	3 Months Ended
	Mar. 31, 2023
Amortization of Excess ADIT Not Subject to Normalization Requirements Policy	The Registrants include the amortization of Excess ADIT not subject to normalization requirements in the annual estimated ETR when regulatory proceedings instruct the Registrants to provide the benefits of Tax Reform to customers over multiple interim periods.  Certain regulatory proceedings instruct the Registrants to provide the benefits of Tax Reform to customers in a single period (e.g. by applying the Excess ADIT not subject to normalization requirements against an existing regulatory asset balance) and in these circumstances, the Registrants recognize the tax benefit discretely in the period recorded. The annual amount of Excess ADIT approved by the Registrant’s regulatory commissions may not impact the ETR ratably during each interim period due to the variability of pretax book income between interim periods and the application of an annual estimated ETR.

Variable Interest Entities (Pol

Variable Interest Entities (Policies)	3 Months Ended
	Mar. 31, 2023
Variable Interest Entities	The accounting guidance for “Variable Interest Entities” is a consolidation model that considers if a company has a variable interest in a VIE. A VIE is a legal entity that possesses any of the following conditions: the entity’s equity at risk is not sufficient to permit the legal entity to finance its activities without additional subordinated financial support, equity owners are unable to direct the activities that most significantly impact the legal entity’s economic performance (or they possess disproportionate voting rights in relation to the economic interest in the legal entity), or the equity owners lack the obligation to absorb the legal entity’s expected losses or the right to receive the legal entity’s expected residual returns. Entities are required to consolidate a VIE when it is determined that they have a controlling financial interest in a VIE and therefore, are the primary beneficiary of that VIE, as defined by the accounting guidance for “Variable Interest Entities.” In determining whether AEP is the primary beneficiary of a VIE, management considers whether AEP has the power to direct the most significant activities of the VIE and is obligated to absorb losses or receive the expected residual returns that are significant to the VIE. AEP holds ownership interests in businesses with varying ownership structures. AEP has not provided material financial or other support that was not previously contractually required to any of its consolidated VIEs. If an entity is determined not to be a VIE, or if the entity is determined to be a VIE and AEP is not deemed to be the primary beneficiary, the entity is accounted for under the equity method of accounting.

Significant Accounting Matter_2

Significant Accounting Matters (Tables)	3 Months Ended
	Mar. 31, 2023
Reconciliation of Cash, Cash Equivalents and Restricted Cash	March 31, 2023 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 343.5 $ 0.1 $ 7.1 Restricted Cash 50.0 42.5 7.5 Total Cash, Cash Equivalents and Restricted Cash $ 393.5 $ 42.6 $ 14.6 December 31, 2022 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 509.4 $ 0.1 $ 7.5 Restricted Cash 47.1 32.7 14.4 Total Cash, Cash Equivalents and Restricted Cash $ 556.5 $ 32.8 $ 21.9
Earnings Per Share	Three Months Ended March 31, 2023 2022 (in millions, except per share data) $/share $/share Earnings Attributable to AEP Common Shareholders $ 397.0 $ 714.7 Weighted-Average Number of Basic AEP Common Shares Outstanding 514.2 $ 0.77 506.1 $ 1.41 Weighted-Average Dilutive Effect of Stock-Based Awards 1.4 — 1.6 — Weighted-Average Number of Diluted AEP Common Shares Outstanding 515.6 $ 0.77 507.7 $ 1.41
Supplementary Information

Comprehensive Income (Tables)

Comprehensive Income (Tables)	3 Months Ended
	Mar. 31, 2023
Changes in Accumulated Other Comprehensive Income (Loss) by Component	AEP 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 for Resale (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) Cash Flow Hedges Pension Three Months Ended March 31, 2022 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2021 $ 163.7 $ (21.3) $ 42.4 $ 184.8 Change in Fair Value Recognized in AOCI, Net of Tax 278.2 6.8 — 285.0 Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (a) (0.1) — — (0.1) Purchased Electricity for Resale (a) (47.9) — — (47.9) Interest Expense (a) — 1.1 — 1.1 Amortization of Prior Service Cost (Credit) — — (4.9) (4.9) Amortization of Actuarial (Gains) Losses — — 2.1 2.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit (48.0) 1.1 (2.8) (49.7) Income Tax (Expense) Benefit (10.1) 0.2 (0.6) (10.5) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (37.9) 0.9 (2.2) (39.2) Net Current Period Other Comprehensive Income (Loss) 240.3 7.7 (2.2) 245.8 Balance in AOCI as of March 31, 2022 $ 404.0 $ (13.6) $ 40.2 $ 430.6 AEP Texas Cash Flow Hedge – Pension Three Months Ended March 31, 2023 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2022 $ (0.3) $ (8.3) $ (8.6) Change in Fair Value Recognized in AOCI, Net of Tax (0.2) (0.5) (0.7) Amount of (Gain) Loss Reclassified from AOCI Interest Expense (a) 0.3 — 0.3 Amortization of Prior Service Cost (Credit) — (0.1) (0.1) Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.3 (0.1) 0.2 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.2 (0.1) 0.1 Net Current Period Other Comprehensive Income (Loss) — (0.6) (0.6) Balance in AOCI as of March 31, 2023 $ (0.3) $ (8.9) $ (9.2) Cash Flow Hedge – Pension Three Months Ended March 31, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2021 $ (1.3) $ (5.2) $ (6.5) Change in Fair Value Recognized in AOCI, Net of Tax — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (a) 0.4 — 0.4 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.4 — 0.4 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.3 — 0.3 Net Current Period Other Comprehensive Income (Loss) 0.3 — 0.3 Balance in AOCI as of March 31, 2022 $ (1.0) $ (5.2) $ (6.2) APCo Cash Flow Hedge – Pension Three Months Ended March 31, 2023 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2022 $ 6.7 $ (11.5) $ (4.8) Change in Fair Value Recognized in AOCI, Net of Tax — (0.1) (0.1) Amount of (Gain) Loss Reclassified from AOCI Interest Expense (a) (0.3) — (0.3) Amortization of Prior Service Cost (Credit) — (1.2) (1.2) Amortization of Actuarial (Gains) Losses — 0.3 0.3 Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.3) (0.9) (1.2) Income Tax (Expense) Benefit (0.1) (0.2) (0.3) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.2) (0.7) (0.9) Net Current Period Other Comprehensive Income (Loss) (0.2) (0.8) (1.0) Balance in AOCI as of March 31, 2023 $ 6.5 $ (12.3) $ (5.8) Cash Flow Hedge – Pension Three Months Ended March 31, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2021 $ 7.5 $ 16.9 $ 24.4 Change in Fair Value Recognized in AOCI, Net of Tax — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (a) (0.3) — (0.3) Amortization of Prior Service Cost (Credit) — (1.4) (1.4) Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.3) (1.4) (1.7) Income Tax (Expense) Benefit (0.1) (0.3) (0.4) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.2) (1.1) (1.3) Net Current Period Other Comprehensive Income (Loss) (0.2) (1.1) (1.3) Balance in AOCI as of March 31, 2022 $ 7.3 $ 15.8 $ 23.1 I&M Cash Flow Hedge – Pension Three Months Ended March 31, 2023 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2022 $ (5.1) $ 4.8 $ (0.3) Change in Fair Value Recognized in AOCI, Net of Tax (1.1) (1.7) (2.8) Amount of (Gain) Loss Reclassified from AOCI Interest Expense (a) 0.5 — 0.5 Amortization of Prior Service Cost (Credit) — (0.3) (0.3) Amortization of Actuarial (Gains) Losses — 0.1 0.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.5 (0.2) 0.3 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.4 (0.2) 0.2 Net Current Period Other Comprehensive Income (Loss) (0.7) (1.9) (2.6) Balance in AOCI as of March 31, 2023 $ (5.8) $ 2.9 $ (2.9) Cash Flow Hedge – Pension Three Months Ended March 31, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2021 $ (6.7) $ 5.4 $ (1.3) Change in Fair Value Recognized in AOCI, Net of Tax — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (a) 0.5 — 0.5 Amortization of Prior Service Cost (Credit) — (0.2) (0.2) Amortization of Actuarial (Gains) Losses — 0.1 0.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.5 (0.1) 0.4 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.4 (0.1) 0.3 Net Current Period Other Comprehensive Income (Loss) 0.4 (0.1) 0.3 Balance in AOCI as of March 31, 2022 $ (6.3) $ 5.3 $ (1.0) PSO Cash Flow Hedge – Three Months Ended March 31, 2023 Interest Rate (in millions) Balance in AOCI as of December 31, 2022 $ 1.3 Change in Fair Value Recognized in AOCI, Net of Tax (1.5) Amount of (Gain) Loss Reclassified from AOCI Interest Expense (a) — Reclassifications from AOCI, before Income Tax (Expense) Benefit — Income Tax (Expense) Benefit — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit — Net Current Period Other Comprehensive Income (Loss) (1.5) Balance in AOCI as of March 31, 2023 $ (0.2) Cash Flow Hedge – Three Months Ended March 31, 2022 Interest Rate (in millions) Balance in AOCI as of December 31, 2021 $ — Change in Fair Value Recognized in AOCI, Net of Tax — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (a) — Reclassifications from AOCI, before Income Tax (Expense) Benefit — Income Tax (Expense) Benefit — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit — Net Current Period Other Comprehensive Income (Loss) — Balance in AOCI as of March 31, 2022 $ — SWEPCo Cash Flow Hedge – Pension Three Months Ended March 31, 2023 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2022 $ 1.1 $ (5.3) $ (4.2) Change in Fair Value Recognized in AOCI, Net of Tax 0.5 — 0.5 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (a) (0.1) — (0.1) Amortization of Prior Service Cost (Credit) — (0.5) (0.5) Amortization of Actuarial (Gains) Losses — 0.1 0.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.1) (0.4) (0.5) Income Tax (Expense) Benefit — (0.1) (0.1) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.1) (0.3) (0.4) Net Current Period Other Comprehensive Income (Loss) 0.4 (0.3) 0.1 Balance in AOCI as of March 31, 2023 $ 1.5 $ (5.6) $ (4.1) Cash Flow Hedge – Pension Three Months Ended March 31, 2022 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2021 $ 1.2 $ 5.5 $ 6.7 Change in Fair Value Recognized in AOCI, Net of Tax — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (a) 0.1 — 0.1 Amortization of Prior Service Cost (Credit) — (0.5) (0.5) Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.1 (0.5) (0.4) Income Tax (Expense) Benefit — (0.1) (0.1) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.1 (0.4) (0.3) Net Current Period Other Comprehensive Income (Loss) 0.1 (0.4) (0.3) Balance in AOCI as of March 31, 2022 $ 1.3 $ 5.1 $ 6.4 (a) Amounts reclassified to the referenced line item on the statements of income.

Rate Matters (Tables)

Rate Matters (Tables)	3 Months Ended
	Mar. 31, 2023
Regulated Generating Units to be Retired	Plant Net Book Value Accelerated Depreciation Regulatory Asset Cost of Removal Projected Current Authorized Annual (dollars in millions) Northeastern Plant, Unit 3 $ 128.5 $ 150.3 $ 20.3 (b) 2026 (c) $ 14.9 Welsh Plant, Units 1 and 3 399.6 95.5 58.1 (d) 2028 (e) 38.3 (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.
Regulatory Assets Pending Final Regulatory Approval	AEP March 31, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Unrecovered Winter Storm Fuel Costs (a) $ 115.9 $ 121.7 Welsh Plant, Units 1 and 3 Accelerated Depreciation 95.5 85.6 Pirkey Plant Accelerated Depreciation 111.8 116.5 Dolet Hills Power Station Fuel Costs - Louisiana 33.3 32.0 Texas Mobile Generation Lease Payments 24.6 17.6 Other Regulatory Assets Pending Final Regulatory Approval 21.4 19.3 Regulatory Assets Currently Not Earning a Return Storm-Related Costs (b)(c) 265.1 407.2 2020-2022 Virginia Triennial Under-Earnings 37.9 37.9 Plant Retirement Costs – Asset Retirement Obligation Costs 25.9 25.9 Other Regulatory Assets Pending Final Regulatory Approval 43.1 55.6 Total Regulatory Assets Pending Final Regulatory Approval $ 774.5 $ 919.3 (a) Includes $37 million and $37 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of March 31, 2023 and December 31, 2022, respectively. See the “February 2021 Severe Winter Weather Impacts in SPP” section below for additional information. (b) In April 2023, OPCo filed a request with the PUCO for recovery of $34 million in Ohio storm-related costs. (c) In April 2023, the LPSC issued an order approving the prudence and future recovery of the Louisiana storm-related costs. See “2021 Louisiana Storm Cost Filing” section below for additional information. AEP Texas March 31, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Texas Mobile Generation Lease Payments $ 24.6 $ 17.6 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 28.9 26.7 Vegetation Management Program 5.2 5.2 Texas Retail Electric Provider Bad Debt Expense 4.1 4.1 Other Regulatory Assets Pending Final Regulatory Approval 13.5 13.4 Total Regulatory Assets Pending Final Regulatory Approval $ 76.3 $ 67.0 APCo March 31, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return COVID-19 – Virginia $ 7.1 $ 7.0 Regulatory Assets Currently Not Earning a Return Storm-Related Costs - West Virginia 72.1 72.6 2020-2022 Virginia Triennial Under-Earnings 37.9 37.9 Plant Retirement Costs – Asset Retirement Obligation Costs 25.9 25.9 Other Regulatory Assets Pending Final Regulatory Approval 0.6 1.1 Total Regulatory Assets Pending Final Regulatory Approval $ 143.6 $ 144.5 I&M March 31, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Other Regulatory Assets Pending Final Regulatory Approval $ 0.1 $ 0.1 Regulatory Assets Currently Not Earning a Return Storm-Related Costs - Indiana 23.0 21.6 Other Regulatory Assets Pending Final Regulatory Approval 2.2 2.0 Total Regulatory Assets Pending Final Regulatory Approval $ 25.3 $ 23.7 OPCo March 31, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Not Earning a Return Storm-Related Costs (a) $ 36.3 $ 33.8 Total Regulatory Assets Pending Final Regulatory Approval $ 36.3 $ 33.8 (a) In April 2023, OPCo filed a request with the PUCO for recovery of $34 million in storm costs. PSO March 31, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Not Earning a Return Storm-Related Costs $ 29.2 $ 25.5 Other Regulatory Assets Pending Final Regulatory Approval 0.1 0.1 Total Regulatory Assets Pending Final Regulatory Approval $ 29.3 $ 25.6 . SWEPCo March 31, December 31, 2023 2022 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Unrecovered Winter Storm Fuel Costs (a) $ 115.9 $ 121.7 Welsh Plant, Units 1 and 3 Accelerated Depreciation 95.5 85.6 Pirkey Plant Accelerated Depreciation 111.8 116.5 Dolet Hills Power Station Fuel Costs - Louisiana 33.3 32.0 Dolet Hills Power Station 12.1 9.7 Other Regulatory Assets Pending Final Regulatory Approval 2.1 2.5 Regulatory Assets Currently Not Earning a Return Storm-Related Costs - Louisiana (b) — 151.5 Asset Retirement Obligation - Louisiana — 11.8 Other Regulatory Assets Pending Final Regulatory Approval 15.4 16.0 Total Regulatory Assets Pending Final Regulatory Approval $ 386.1 $ 547.3 (a) Includes $37 million and $37 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of March 31, 2023 and December 31, 2022, respectively. See the “February 2021 Severe Winter Weather Impacts in SPP” section below for additional information. (b) In April 2023, the LPSC issued an order approving the prudence and future recovery of the Louisiana storm-related costs. See “2021 Louisiana Storm Cost Filing” section below for additional information.
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, 2023 December 31, 2022 Approved Recovery Period Approved Carrying Charge (in millions) Arkansas $ 71.7 $ 74.9 6 years (a) Louisiana 115.9 121.7 (b) (b) Texas 124.5 132.4 5 years 1.65% Total $ 312.1 $ 329.0 (a) SWEPCo is permitted to record carrying costs on the unrecovered balance of fuel costs at a weighted-cost of capital approved by the APSC. (b) In March 2021, the LPSC approved a special order granting a temporary modification to the FAC and shortly after SWEPCo began recovery of its Louisiana jurisdictional share of these fuel costs based on a five-year recovery period inclusive of an interim carrying charge equal to the prime rate. SWEPCo will work with the LPSC to finalize the actual recovery period and determine the appropriate carrying charge in future proceedings.

Commitments, Guarantees and C_2

Commitments, Guarantees and Contingencies (Tables)	3 Months Ended
	Mar. 31, 2023
Maximum Future Payments for Letters of Credit Uncommitted Facilities	Company Amount Maturity (in millions) AEP $ 299.0 April 2023 to March 2024 AEP Texas 1.8 July 2023
Max Potential Loss on Master Lease Agreements	Company Maximum (in millions) AEP $ 46.4 AEP Texas 11.2 APCo 6.0 I&M 4.3 OPCo 7.4 PSO 4.9 SWEPCo 5.7

Discontinued Operations and Dis

Discontinued Operations and Disposal Groups (Tables)	3 Months Ended
	Mar. 31, 2023
Discontinued Operations and Disposal Groups [Abstract]
Assets and Liabilities HFS - Contracted Renewables	March 31, 2023 (in millions) ASSETS Accounts Receivable and Accrued Unbilled Revenues $ 16.9 Property, Plant and Equipment, Net 1,404.7 Other Classes of Assets that are not Major 63.2 Total Major Classes of Assets Held for Sale 1,484.8 Loss on the Expected Sale of the Competitive Contracted Renewables Portfolio (net of $23.5 million of Income Taxes) (88.5) Assets Held for Sale $ 1,396.3 LIABILITIES Accounts Payable $ 6.8 Asset Retirement Obligations 30.6 Obligations Under Operating Leases 20.1 Other Classes of Liabilities that are not Major 9.7 Liabilities Held for Sale $ 67.2

Benefit Plans (Tables)

Benefit Plans (Tables)	3 Months Ended
	Mar. 31, 2023
Components of Net Periodic Benefit Cost	AEP Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2023 2022 2023 2022 (in millions) Service Cost $ 23.6 $ 30.8 $ 1.1 $ 1.8 Interest Cost 54.8 37.0 11.6 7.3 Expected Return on Plan Assets (84.8) (63.4) (27.4) (27.5) Amortization of Prior Service Credit — — (15.8) (17.8) Amortization of Net Actuarial Loss 0.3 15.8 3.7 — Net Periodic Benefit Cost (Credit) $ (6.1) $ 20.2 $ (26.8) $ (36.2) AEP Texas Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2023 2022 2023 2022 (in millions) Service Cost $ 2.0 $ 2.8 $ 0.1 $ 0.1 Interest Cost 4.6 3.0 0.9 0.6 Expected Return on Plan Assets (7.0) (5.3) (2.3) (2.3) Amortization of Prior Service Credit — — (1.3) (1.5) Amortization of Net Actuarial Loss — 1.3 0.3 — Net Periodic Benefit Cost (Credit) $ (0.4) $ 1.8 $ (2.3) $ (3.1) APCo Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2023 2022 2023 2022 (in millions) Service Cost $ 2.3 $ 2.9 $ 0.1 $ 0.2 Interest Cost 6.6 4.4 1.8 1.2 Expected Return on Plan Assets (11.2) (8.1) (4.0) (4.1) Amortization of Prior Service Credit — — (2.3) (2.6) Amortization of Net Actuarial Loss — 1.8 0.6 — Net Periodic Benefit Cost (Credit) $ (2.3) $ 1.0 $ (3.8) $ (5.3) I&M Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2023 2022 2023 2022 (in millions) Service Cost $ 3.0 $ 4.0 $ 0.2 $ 0.2 Interest Cost 6.2 4.2 1.3 0.8 Expected Return on Plan Assets (11.0) (8.0) (3.4) (3.4) Amortization of Prior Service Credit — — (2.2) (2.4) Amortization of Net Actuarial Loss — 1.8 0.5 — Net Periodic Benefit Cost (Credit) $ (1.8) $ 2.0 $ (3.6) $ (4.8) OPCo Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2023 2022 2023 2022 (in millions) Service Cost $ 2.1 $ 2.7 $ 0.1 $ 0.2 Interest Cost 4.9 3.4 1.2 0.7 Expected Return on Plan Assets (8.5) (6.2) (2.9) (3.0) Amortization of Prior Service Credit — — (1.6) (1.8) Amortization of Net Actuarial Loss — 1.4 0.4 — Net Periodic Benefit Cost (Credit) $ (1.5) $ 1.3 $ (2.8) $ (3.9) PSO Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2023 2022 2023 2022 (in millions) Service Cost $ 1.4 $ 1.9 $ 0.1 $ 0.1 Interest Cost 2.7 1.8 0.6 0.4 Expected Return on Plan Assets (4.6) (3.4) (1.5) (1.5) Amortization of Prior Service Credit — — (1.0) (1.1) Amortization of Net Actuarial Loss — 0.7 0.2 — Net Periodic Benefit Cost (Credit) $ (0.5) $ 1.0 $ (1.6) $ (2.1) SWEPCo Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2023 2022 2023 2022 (in millions) Service Cost $ 1.9 $ 2.6 $ 0.1 $ 0.1 Interest Cost 3.5 2.3 0.7 0.5 Expected Return on Plan Assets (4.8) (3.7) (1.8) (1.9) Amortization of Prior Service Credit — — (1.2) (1.3) Amortization of Net Actuarial Loss — 1.0 0.2 — Net Periodic Benefit Cost (Credit) $ 0.6 $ 2.2 $ (2.0) $ (2.6)

Business Segments (Tables)

Business Segments (Tables)	3 Months Ended
	Mar. 31, 2023
Segment Reporting Information [Line Items]
Reportable Segment Information	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) — 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 Three Months Ended March 31, 2022 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) Revenues from: External Customers $ 2,646.8 $ 1,242.2 $ 83.4 $ 609.5 $ 10.7 $ — $ 4,592.6 Other Operating Segments 40.6 4.6 328.0 9.8 9.2 (392.2) — Total Revenues $ 2,687.4 $ 1,246.8 $ 411.4 $ 619.3 $ 19.9 $ (392.2) $ 4,592.6 Net Income (Loss) $ 299.2 $ 152.8 $ 173.7 $ 116.0 $ (23.6) $ — $ 718.1 March 31, 2023 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Consolidated (in millions) Total Assets (d) $ 50,164.1 $ 23,437.0 $ 15,883.1 $ 4,159.8 $ 6,457.2 (b) $ (5,583.3) (c) $ 94,517.9 December 31, 2022 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Consolidated (in millions) Total Assets $ 49,761.8 $ 22,920.2 $ 15,215.8 $ 4,520.1 $ 6,768.4 (b) $ (5,783.0) (c) $ 93,403.3 (a) Corporate and Other primarily includes the purchasing of receivables from certain AEP utility subsidiaries. This segment also includes Parent’s guarantee revenue received from affiliates, investment income, interest income, interest expense and other nonallocated costs. (b) Includes elimination of AEP Parent’s investments in wholly-owned subsidiary companies. (c) Reconciling Adjustments for Total Assets primarily include elimination of intercompany advances to affiliates and intercompany accounts receivable. (d) Amount includes Assets Held for Sale on the balance sheet. See “Planned Disposition of the Competitive Contracted Renewables Portfolio” section of Note 6 for additional information. Three Months Ended March 31, 2023 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (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 Three Months Ended March 31, 2022 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Revenues from: External Customers $ 75.7 $ — $ — $ 75.7 Sales to AEP Affiliates 324.7 — — 324.7 Total Revenues $ 400.4 $ — $ — $ 400.4 Net Income $ 155.4 $ — (a) $ — $ 155.4 March 31, 2023 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Total Assets $ 14,493.6 $ 5,581.6 (b) $ (5,620.5) (c) $ 14,454.7 December 31, 2022 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Total Assets $ 13,875.6 $ 4,817.4 (b) $ (4,878.8) (c) $ 13,814.2 (a) Includes the elimination of AEPTCo Parent’s equity earnings in the State Transcos. (b) Primarily relates to Notes Receivable from the State Transcos. (c) Primarily relates to the elimination of Notes Receivable from the State Transcos.

Derivatives and Hedging (Tables

Derivatives and Hedging (Tables)	3 Months Ended
	Mar. 31, 2023
Notional Volume of Derivative Instruments	Notional Volume of Derivative Instruments March 31, 2023 Primary Risk Unit of AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power MWhs 213.5 — 7.3 4.1 2.4 1.8 1.3 Natural Gas MMBtus 92.8 — 2.9 — — 3.1 1.8 Heating Oil and Gasoline Gallons 5.0 1.4 0.8 0.5 1.0 0.7 0.7 Interest Rate USD $ 91.4 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt USD $ 1,700.0 $ 150.0 $ — $ — $ — $ — $ — December 31, 2022 Primary Risk Unit of AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power MWhs 226.8 — 17.9 4.2 2.5 2.9 2.2 Natural Gas MMBtus 77.1 — 1.9 — — 1.9 2.1 Heating Oil and Gasoline Gallons 6.9 1.9 1.0 0.7 1.4 0.9 1.0 Interest Rate USD $ 99.9 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt USD $ 1,650.0 $ — $ — $ — $ — $ 200.0 $ —
Fair Value of Derivative Instruments	AEP March 31, 2023 Risk Hedging Contracts Gross Amounts Gross Net Amounts of Balance Sheet Location Commodity (a) Commodity (a) Interest Rate (a) (in millions) Current Risk Management Assets $ 621.1 $ 85.0 $ 8.9 $ 715.0 $ (524.4) $ 190.6 Long-term Risk Management Assets 494.3 117.0 — 611.3 (293.1) 318.2 Total Assets 1,115.4 202.0 8.9 1,326.3 (817.5) 508.8 Current Risk Management Liabilities 562.5 87.5 39.5 689.5 (523.5) 166.0 Long-term Risk Management Liabilities 402.6 31.4 82.7 516.7 (201.3) 315.4 Total Liabilities 965.1 118.9 122.2 1,206.2 (724.8) 481.4 Total MTM Derivative Contract Net Assets (Liabilities) (d) $ 150.3 $ 83.1 $ (113.3) $ 120.1 $ (92.7) $ 27.4 December 31, 2022 Risk Hedging Contracts Gross Amounts Gross Net Amounts of Balance Sheet Location Commodity (a) Commodity (a) Interest Rate (a) (in millions) Current Risk Management Assets $ 965.4 $ 212.2 $ 1.8 $ 1,179.4 $ (830.6) $ 348.8 Long-term Risk Management Assets 565.6 148.9 14.3 728.8 (444.7) 284.1 Total Assets 1,531.0 361.1 16.1 1,908.2 (1,275.3) 632.9 Current Risk Management Liabilities 663.8 60.4 41.4 765.6 (620.4) 145.2 Long-term Risk Management Liabilities 412.0 17.4 91.1 520.5 (175.3) 345.2 Total Liabilities 1,075.8 77.8 132.5 1,286.1 (795.7) 490.4 Total MTM Derivative Contract Net Assets (Liabilities) $ 455.2 $ 283.3 $ (116.4) $ 622.1 $ (479.6) $ 142.5 AEP Texas March 31, 2023 Risk Management Contracts - Hedging Contracts Gross Amounts of Risk Management Assets/Liabilities Recognized Gross Amounts Offset in the Statement of Financial Position (b) Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position (c) Balance Sheet Location Commodity (a) Interest Rate (a) (in millions) Current Risk Management Assets $ — $ 0.5 $ 0.5 $ — $ 0.5 Long-term Risk Management Assets — — — — — Total Assets — 0.5 0.5 — 0.5 Current Risk Management Liabilities 0.4 0.8 1.2 (0.4) 0.8 Long-term Risk Management Liabilities — — — — — Total Liabilities 0.4 0.8 1.2 (0.4) 0.8 Total MTM Derivative Contract Net Assets (Liabilities) (d) $ (0.4) $ (0.3) $ (0.7) $ 0.4 $ (0.3) December 31, 2022 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ — $ — $ — Long-term Risk Management Assets — — — Total Assets — — — Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — — — Total Liabilities — — — Total MTM Derivative Contract Net Assets $ — $ — $ — APCo March 31, 2023 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 12.8 $ (0.4) $ 12.4 Long-term Risk Management Assets 0.5 (0.5) — Total Assets 13.3 (0.9) 12.4 Current Risk Management Liabilities 7.6 (0.6) 7.0 Long-term Risk Management Liabilities 0.5 (0.5) — Total Liabilities 8.1 (1.1) 7.0 Total MTM Derivative Contract Net Assets (d) $ 5.2 $ 0.2 $ 5.4 December 31, 2022 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 69.3 $ (0.2) $ 69.1 Long-term Risk Management Assets 0.7 (0.7) — Total Assets 70.0 (0.9) 69.1 Current Risk Management Liabilities 4.1 (0.5) 3.6 Long-term Risk Management Liabilities 0.7 (0.6) 0.1 Total Liabilities 4.8 (1.1) 3.7 Total MTM Derivative Contract Net Assets $ 65.2 $ 0.2 $ 65.4 I&M March 31, 2023 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 8.1 $ (2.2) $ 5.9 Long-term Risk Management Assets 5.5 (4.4) 1.1 Total Assets 13.6 (6.6) 7.0 Current Risk Management Liabilities 2.7 (2.3) 0.4 Long-term Risk Management Liabilities 4.4 (4.4) — Total Liabilities 7.1 (6.7) 0.4 Total MTM Derivative Contract Net Assets (d) $ 6.5 $ 0.1 $ 6.6 December 31, 2022 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 16.0 $ (0.8) $ 15.2 Long-term Risk Management Assets 0.5 (0.3) 0.2 Total Assets 16.5 (1.1) 15.4 Current Risk Management Liabilities 0.9 (0.9) — Long-term Risk Management Liabilities 0.3 (0.3) — Total Liabilities 1.2 (1.2) — Total MTM Derivative Contract Net Assets $ 15.3 $ 0.1 $ 15.4 OPCo March 31, 2023 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ — $ — $ — Long-term Risk Management Assets — — — Total Assets — — — Current Risk Management Liabilities 6.2 (0.2) 6.0 Long-term Risk Management Liabilities 40.9 — 40.9 Total Liabilities 47.1 (0.2) 46.9 Total MTM Derivative Contract Net Assets (Liabilities) (d) $ (47.1) $ 0.2 $ (46.9) December 31, 2022 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ — $ — $ — Long-term Risk Management Assets — — — Total Assets — — — Current Risk Management Liabilities 2.1 (0.3) 1.8 Long-term Risk Management Liabilities 37.9 — 37.9 Total Liabilities 40.0 (0.3) 39.7 Total MTM Derivative Contract Net Assets (Liabilities) $ (40.0) $ 0.3 $ (39.7) PSO March 31, 2023 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 9.9 $ (0.5) $ 9.4 Long-term Risk Management Assets — — — Total Assets 9.9 (0.5) 9.4 Current Risk Management Liabilities 1.8 (0.7) 1.1 Long-term Risk Management Liabilities — — — Total Liabilities 1.8 (0.7) 1.1 Total MTM Derivative Contract Net Assets (d) $ 8.1 $ 0.2 $ 8.3 December 31, 2022 Risk Management Contracts – Hedging Contracts Gross Amounts of Risk Management Assets/Liabilities Recognized Gross Amounts Offset in the Statement of Financial Position (b) Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position (c) Balance Sheet Location Commodity (a) Interest Rate (a) (in millions) Current Risk Management Assets $ 24.1 $ 1.6 $ 25.7 $ (0.4) $ 25.3 Long-term Risk Management Assets — — — — — Total Assets 24.1 1.6 25.7 (0.4) 25.3 Current Risk Management Liabilities 2.1 — 2.1 (0.5) 1.6 Long-term Risk Management Liabilities — — — — — Total Liabilities 2.1 — 2.1 (0.5) 1.6 Total MTM Derivative Contract Net Assets $ 22.0 $ 1.6 $ 23.6 $ 0.1 $ 23.7 SWEPCo March 31, 2023 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 6.4 $ (0.1) $ 6.3 Long-term Risk Management Assets — — — Total Assets 6.4 (0.1) 6.3 Current Risk Management Liabilities 1.4 (0.3) 1.1 Long-term Risk Management Liabilities — — — Total Liabilities 1.4 (0.3) 1.1 Total MTM Derivative Contract Net Assets (d) $ 5.0 $ 0.2 $ 5.2 December 31, 2022 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 16.8 $ (0.4) $ 16.4 Long-term Risk Management Assets — — — Total Assets 16.8 (0.4) 16.4 Current Risk Management Liabilities 2.0 (0.6) 1.4 Long-term Risk Management Liabilities — — — Total Liabilities 2.0 (0.6) 1.4 Total MTM Derivative Contract Net Assets $ 14.8 $ 0.2 $ 15.0 (a) Derivative instruments within these categories are disclosed as gross. These instruments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with the accounting guidance for “Derivatives and Hedging.” (b) Amounts include counterparty netting of risk management and hedging contracts and associated cash collateral in accordance with the accounting guidance for “Derivatives and Hedging.” (c) All derivative contracts subject to a master netting arrangement or similar agreement are offset in the statement of financial position. (d) Decrease in amounts as of March 31, 2023 are primarily due to decreases in commodity prices for power and natural gas and a decrease in value of FTRs.
Amount of Gain (Loss) Recognized on Risk Management Contracts	Amount of Gain (Loss) Recognized on Risk Management Contracts Three Months Ended 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 for Resale 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 (b) $ (178.2) $ (0.4) $ (32.7) $ (4.6) $ (12.3) $ 16.8 $ 10.4 Three Months Ended March 31, 2022 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Generation & Marketing Revenues $ 152.3 $ — $ — $ — $ — $ — $ — Electric Generation, Transmission and Distribution Revenues — — 0.1 (0.1) — — — Purchased Electricity for Resale 1.5 — 1.4 — — — — Other Operation 0.6 0.2 — 0.1 0.1 0.1 0.1 Maintenance 0.8 0.2 0.1 0.1 0.1 0.1 0.1 Regulatory Assets (a) 23.6 — (0.1) (1.6) 23.9 3.6 (2.1) Regulatory Liabilities (a) 36.5 0.9 (1.4) 1.7 — 12.7 20.9 Total Gain on Risk Management Contracts $ 215.3 $ 1.3 $ 0.1 $ 0.2 $ 24.1 $ 16.5 $ 19.0 (a) Represents realized and unrealized gains and losses subject to regulatory accounting treatment recorded as either current or noncurrent on the balance sheets. (b) Decrease in amounts as of March 31, 2023 are primarily due to decreases in commodity prices for power and natural gas and a decrease in value of FTRs.
Impact of Fair Value Hedges on the Condensed Balance Sheet	Carrying Amount of the Hedged Liabilities Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of the Hedged Liabilities March 31, 2023 December 31, 2022 March 31, 2023 December 31, 2022 (in millions) Long-term Debt (a) (b) $ (860.8) $ (855.5) $ 84.7 $ 89.7 (a) Amounts included on the Balance Sheet within Noncurrent Liabilities line item Long-term Debt.
Gain (Loss) on Hedging Instruments	Three Months Ended March 31, 2023 2022 (in millions) Gain (Loss) on Interest Rate Contracts: Fair Value Hedging Instruments (a) $ 6.9 $ (44.8) Fair Value Portion of Long-term Debt (a) (6.9) 44.8 (a) Gain (Loss) is included in Interest Expense on the statements of income.
Impact of Cash Flow Hedges on the Condensed Balance Sheet	Impact of Cash Flow Hedges on AEP’s Balance Sheets March 31, 2023 December 31, 2022 Commodity Interest Rate Commodity Interest Rate (in millions) AOCI Gain Net of Tax $ 65.3 $ 6.1 $ 223.5 $ 0.3 Portion Expected to be Reclassed to Net Income During the Next Twelve Months (2.0) 1.9 119.9 0.3 Impact of Cash Flow Hedges on the Registrant Subsidiaries’ Balance Sheets March 31, 2023 December 31, 2022 Interest Rate Expected to be Expected to be Reclassified to Reclassified to Net Income During Net Income During AOCI Gain (Loss) the Next AOCI Gain (Loss) the Next Company Net of Tax Twelve Months Net of Tax Twelve Months (in millions) AEP Texas $ (0.3) $ — $ (0.3) $ (0.2) APCo 6.5 0.8 6.7 0.8 I&M (5.8) (0.4) (5.1) (0.6) PSO (0.2) — 1.3 0.1 SWEPCo 1.5 0.3 1.1 0.2

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2023
Book Values and Fair Values of Long-term Debt	March 31, 2023 December 31, 2022 Company Book Value Fair Value Book Value Fair Value (in millions) AEP (a) $ 39,144.2 $ 36,126.4 $ 36,801.0 $ 32,915.9 AEP Texas 5,522.0 5,009.5 5,657.8 5,045.8 AEPTCo 5,472.1 4,836.2 4,782.8 3,940.5 APCo 5,398.7 5,227.7 5,410.5 5,079.2 I&M 3,489.0 3,249.1 3,260.8 2,929.0 OPCo 2,970.8 2,566.6 2,970.3 2,516.6 PSO 2,383.6 2,172.6 1,912.8 1,635.8 SWEPCo 3,644.8 3,195.9 3,391.6 2,870.9
Other Temporary Investments	March 31, 2023 Gross Gross Unrealized Unrealized Fair Other Temporary Investments and Restricted Cash Cost Gains Losses Value (in millions) Restricted Cash (a) $ 50.0 $ — $ — $ 50.0 Other Cash Deposits 11.4 — — 11.4 Fixed Income Securities – Mutual Funds (b) 153.4 — (7.2) 146.2 Equity Securities – Mutual Funds 15.2 21.8 — 37.0 Total Other Temporary Investments and Restricted Cash $ 230.0 $ 21.8 $ (7.2) $ 244.6 December 31, 2022 Gross Gross Unrealized Unrealized Fair Other Temporary Investments and Restricted Cash Cost Gains Losses Value (in millions) Restricted Cash (a) $ 47.1 $ — $ — $ 47.1 Other Cash Deposits 9.0 — — 9.0 Fixed Income Securities – Mutual Funds (b) 152.4 — (8.3) 144.1 Equity Securities – Mutual Funds 15.1 19.4 — 34.5 Total Other Temporary Investments and Restricted Cash $ 223.6 $ 19.4 $ (8.3) $ 234.7 (a) Primarily represents amounts held for the repayment of debt. (b) Primarily short and intermediate maturities which may be sold and do not contain maturity dates.
Debt and Equity Securities Within Other Temporary Investments	Three Months Ended March 31, 2023 2022 (in millions) Proceeds from Investment Sales $ — $ 3.9 Purchases of Investments 1.0 0.8 Gross Realized Gains on Investment Sales — 0.3 Gross Realized Losses on Investment Sales — 0.1
Nuclear Trust Fund Investments	March 31, 2023 December 31, 2022 Gross Gross Other-Than- Gross Gross Other-Than- Fair Unrealized Unrealized Temporary Fair Unrealized Unrealized Temporary Value Gains Losses Impairments Value Gains Losses Impairments (in millions) Cash and Cash Equivalents $ 26.5 $ — $ — $ — $ 21.2 $ — $ — $ — Fixed Income Securities: United States Government 1,207.6 20.9 (6.4) (28.3) 1,123.8 11.8 (14.9) (18.8) Corporate Debt 66.0 1.0 (6.1) (2.2) 61.6 0.7 (7.7) (9.6) State and Local Government 3.3 — — — 3.3 0.1 — (0.1) Subtotal Fixed Income Securities 1,276.9 21.9 (12.5) (30.5) 1,188.7 12.6 (22.6) (28.5) Equity Securities - Domestic 2,197.7 1,565.1 (2.9) — 2,131.3 1,483.7 (6.4) — Spent Nuclear Fuel and Decommissioning Trusts $ 3,501.1 $ 1,587.0 $ (15.4) $ (30.5) $ 3,341.2 $ 1,496.3 $ (29.0) $ (28.5)
Securities Activity Within the Decommissioning and SNF Trusts	Three Months Ended March 31, 2023 2022 (in millions) Proceeds from Investment Sales $ 517.6 $ 493.5 Purchases of Investments 536.3 507.7 Gross Realized Gains on Investment Sales 48.5 5.8 Gross Realized Losses on Investment Sales 8.6 7.2
Contractual Maturities, Fair Value of Debt Securities in Nuclear Trusts	Fair Value of Fixed Income Securities (in millions) Within 1 year $ 347.8 After 1 year through 5 years 489.1 After 5 years through 10 years 215.6 After 10 years 224.4 Total $ 1,276.9
Fair Value, Assets and Liabilities Measured on Recurring Basis	AEP Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments and Restricted Cash Restricted Cash $ 50.0 $ — $ — $ — $ 50.0 Other Cash Deposits (a) — — — 11.4 11.4 Fixed Income Securities – Mutual Funds 146.2 — — — 146.2 Equity Securities – Mutual Funds (b) 37.0 — — — 37.0 Total Other Temporary Investments and Restricted Cash 233.2 — — 11.4 244.6 Risk Management Assets Risk Management Commodity Contracts (c) (d) 13.0 861.2 209.2 (720.2) 363.2 Cash Flow Hedges: Commodity Hedges (c) — 177.8 20.3 (61.4) 136.7 Interest Rate Hedges — 8.9 — — 8.9 Total Risk Management Assets 13.0 1,047.9 229.5 (781.6) 508.8 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 17.1 — — 9.4 26.5 Fixed Income Securities: United States Government — 1,207.6 — — 1,207.6 Corporate Debt — 66.0 — — 66.0 State and Local Government — 3.3 — — 3.3 Subtotal Fixed Income Securities — 1,276.9 — — 1,276.9 Equity Securities – Domestic (b) 2,197.7 — — — 2,197.7 Total Spent Nuclear Fuel and Decommissioning Trusts 2,214.8 1,276.9 — 9.4 3,501.1 Total Assets $ 2,461.0 $ 2,324.8 $ 229.5 $ (760.8) $ 4,254.5 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (d) $ 33.5 $ 721.1 $ 178.5 $ (627.5) $ 305.6 Cash Flow Hedges: Commodity Hedges (c) — 109.1 5.9 (61.4) 53.6 Interest Rate Hedges — 1.7 — — 1.7 Fair Value Hedges — 120.5 — — 120.5 Total Risk Management Liabilities $ 33.5 $ 952.4 $ 184.4 $ (688.9) $ 481.4 AEP Assets and Liabilities Measured at Fair Value on a Recurring Basis December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments and Restricted Cash Restricted Cash $ 47.1 $ — $ — $ — $ 47.1 Other Cash Deposits (a) — — — 9.0 9.0 Fixed Income Securities – Mutual Funds 144.1 — — — 144.1 Equity Securities – Mutual Funds (b) 34.5 — — — 34.5 Total Other Temporary Investments and Restricted Cash 225.7 — — 9.0 234.7 Risk Management Assets Risk Management Commodity Contracts (c) (f) 15.0 1,197.5 314.4 (1,211.5) 315.4 Cash Flow Hedges: Commodity Hedges (c) — 332.6 26.7 (52.8) 306.5 Interest Rate Hedges — 11.0 — — 11.0 Total Risk Management Assets 15.0 1,541.1 341.1 (1,264.3) 632.9 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 11.3 — — 9.9 21.2 Fixed Income Securities: United States Government — 1,123.8 — — 1,123.8 Corporate Debt — 61.6 — — 61.6 State and Local Government — 3.3 — — 3.3 Subtotal Fixed Income Securities — 1,188.7 — — 1,188.7 Equity Securities – Domestic (b) 2,131.3 — — — 2,131.3 Total Spent Nuclear Fuel and Decommissioning Trusts 2,142.6 1,188.7 — 9.9 3,341.2 Total Assets $ 2,383.3 $ 2,729.8 $ 341.1 $ (1,245.4) $ 4,208.8 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (f) $ 21.8 $ 870.9 $ 179.0 $ (731.9) $ 339.8 Cash Flow Hedges: Commodity Hedges (c) — 74.3 1.7 (52.8) 23.2 Fair Value Hedges — 127.4 — — 127.4 Total Risk Management Liabilities $ 21.8 $ 1,072.6 $ 180.7 $ (784.7) $ 490.4 AEP Texas Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 42.5 $ — $ — $ — $ 42.5 Risk Management Assets Cash Flow Hedges: Interest Rate Hedges — 0.5 — — 0.5 Total Assets $ 42.5 $ 0.5 $ — $ — $ 43.0 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 0.4 $ — $ (0.4) $ — Cash Flow Hedges: Interest Rate Hedges — 0.8 — — 0.8 Total Liabilities $ — $ 1.2 $ — $ (0.4) $ 0.8 December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 32.7 $ — $ — $ — $ 32.7 APCo Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 7.5 $ — $ — $ — $ 7.5 Risk Management Assets Risk Management Commodity Contracts (c) (g) — 0.4 12.4 (0.4) 12.4 Total Assets $ 7.5 $ 0.4 $ 12.4 $ (0.4) $ 19.9 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 0.9 $ 6.7 $ (0.6) $ 7.0 December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 14.4 $ — $ — $ — $ 14.4 Risk Management Assets Risk Management Commodity Contracts (c) (g) — 0.7 69.4 (1.0) 69.1 Total Assets $ 14.4 $ 0.7 $ 69.4 $ (1.0) $ 83.5 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 4.6 $ 0.3 $ (1.4) $ 3.5 I&M Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 6.6 $ 1.6 $ (1.2) $ 7.0 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 17.1 — — 9.4 26.5 Fixed Income Securities: United States Government — 1,207.6 — — 1,207.6 Corporate Debt — 66.0 — — 66.0 State and Local Government — 3.3 — — 3.3 Subtotal Fixed Income Securities — 1,276.9 — — 1,276.9 Equity Securities - Domestic (b) 2,197.7 — — — 2,197.7 Total Spent Nuclear Fuel and Decommissioning Trusts 2,214.8 1,276.9 — 9.4 3,501.1 Total Assets $ 2,214.8 $ 1,283.5 $ 1.6 $ 8.2 $ 3,508.1 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 1.3 $ 0.5 $ (1.4) $ 0.4 December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 11.3 $ 5.3 $ (1.2) $ 15.4 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 11.3 — — 9.9 21.2 Fixed Income Securities: United States Government — 1,123.8 — — 1,123.8 Corporate Debt — 61.6 — — 61.6 State and Local Government — 3.3 — — 3.3 Subtotal Fixed Income Securities — 1,188.7 — — 1,188.7 Equity Securities - Domestic (b) 2,131.3 — — — 2,131.3 Total Spent Nuclear Fuel and Decommissioning Trusts 2,142.6 1,188.7 — 9.9 3,341.2 Total Assets $ 2,142.6 $ 1,200.0 $ 5.3 $ 8.7 $ 3,356.6 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 0.6 $ 0.7 $ (1.3) $ — OPCo Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (g) $ — $ — $ — $ — $ — Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 0.2 $ 46.9 $ (0.2) $ 46.9 December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (g) $ — $ — $ — $ — $ — Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 40.0 $ (0.3) $ 39.7 PSO Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ — $ 9.9 $ (0.5) $ 9.4 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 1.2 $ 0.6 $ (0.7) $ 1.1 December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ — $ 24.0 $ 1.3 $ 25.3 Cash Flow Hedges: Interest Rate Hedges — 1.6 — (1.6) — Total Assets $ — $ 1.6 $ 24.0 $ (0.3) $ 25.3 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 1.7 $ 0.3 $ (0.4) $ 1.6 SWEPCo Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ — $ 6.4 $ (0.1) $ 6.3 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 0.8 $ 0.6 $ (0.3) $ 1.1 December 31, 2022 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 2.2 $ 14.6 $ (0.4) $ 16.4 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 1.6 $ 0.4 $ (0.6) $ 1.4 (a) Amounts in “Other’’ column primarily represent cash deposits in bank accounts with financial institutions or third-parties. Level 1 and Level 2 amounts primarily represent investments in money market funds. (b) Amounts represent publicly traded equity securities and equity-based mutual funds. (c) Amounts in “Other’’ column primarily represent counterparty netting of risk management and hedging contracts and associated cash collateral under the accounting guidance for “Derivatives and Hedging.’’ (d) The March 31, 2023 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 2023 and $(6) million in periods 2024-2026; Level 2 matures $24 million in 2023, $105 million in periods 2024-2026, $9 million in periods 2027-2028 and $1 million in periods 2029-2033; Level 3 matures $18 million in 2023, $9 million in periods 2024-2026, $11 million in periods 2027-2028 and $(7) million in periods 2029-2033. Risk management commodity contracts are substantially comprised of power contracts. (e) Amounts in “Other’’ column primarily represent accrued interest receivables from financial institutions. Level 1 amounts primarily represent investments in money market funds. (f) The December 31, 2022 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $(7) million in 2023; Level 2 matures $182 million in 2023, $134 million in periods 2024-2026, $10 million in periods 2027-2028 and $1 million in periods 2029-2033; Level 3 matures $128 million in 2023, $6 million in periods 2024-2026, $6 million in periods 2027-2028 and $(5) million in periods 2029-2033. Risk management commodity contracts are substantially comprised of power contracts. (g) Substantially comprised of power contracts for the Registrant Subsidiaries.
Changes in Fair Value of Net Trading Derivatives and Other Investments	Three Months Ended 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 Three Months Ended March 31, 2022 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of December 31, 2021 $ 103.1 $ 41.7 $ (0.7) $ (92.5) $ 12.1 $ 10.9 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 18.2 (2.9) 3.8 0.5 12.1 9.8 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (19.0) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 19.3 — — — — — Settlements (51.6) (32.4) (2.3) 1.4 (19.8) (16.2) Transfers into Level 3 (d) (e) 2.5 — — — — — Transfers out of Level 3 (e) 2.9 — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 7.4 0.2 0.2 22.1 2.1 11.2 Balance as of March 31, 2022 $ 82.8 $ 6.6 $ 1.0 $ (68.5) $ 6.5 $ 15.7 (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	AEP Significant Unobservable Inputs March 31, 2023 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) Energy Contracts $ 190.7 $ 166.5 Discounted Cash Flow Forward Market Price $ 0.74 $ 101.65 $ 48.48 FTRs 38.8 17.9 Discounted Cash Flow Forward Market Price (55.98) 101.82 (0.45) Total $ 229.5 $ 184.4 December 31, 2022 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) Energy Contracts $ 204.0 $ 167.4 Discounted Cash Flow Forward Market Price $2.91 $ 187.34 $ 49.14 FTRs 137.1 13.3 Discounted Cash Flow Forward Market Price (36.45) 20.72 1.18 Total $ 341.1 $ 180.7 APCo Significant Unobservable Inputs March 31, 2023 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) FTRs $ 12.4 $ 6.7 Discounted Cash Flow Forward Market Price $ (1.67) $ 6.59 $ 0.79 December 31, 2022 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) FTRs $ 69.4 $ 0.3 Discounted Cash Flow Forward Market Price $ (2.82) $ 18.88 $ 3.89 I&M Significant Unobservable Inputs March 31, 2023 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) FTRs $ 1.6 $ 0.5 Discounted Cash Flow Forward Market Price $ 0.24 $ 4.75 $ 0.78 December 31, 2022 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) FTRs $ 5.3 $ 0.7 Discounted Cash Flow Forward Market Price $ 0.16 $ 18.79 $ 1.23 OPCo Significant Unobservable Inputs March 31, 2023 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) Energy Contracts $ — $ 46.9 Discounted Cash Flow Forward Market Price $ 14.41 $ 79.98 $ 45.92 December 31, 2022 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) Energy Contracts $ — $ 40.0 Discounted Cash Flow Forward Market Price $ 2.91 $ 187.34 $ 48.76 PSO Significant Unobservable Inputs March 31, 2023 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) FTRs $ 9.9 $ 0.6 Discounted Cash Flow Forward Market Price $ (21.10) $ 3.04 $ (4.75) December 31, 2022 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) FTRs $ 24.0 $ 0.3 Discounted Cash Flow Forward Market Price $ (36.45) $ 3.40 $ (7.55) SWEPCo Significant Unobservable Inputs March 31, 2023 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) FTRs $ 6.4 $ 0.6 Discounted Cash Flow Forward Market Price $ (21.10) $ 3.04 $ (4.75) December 31, 2022 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (b) (in millions) FTRs $ 14.6 $ 0.4 Discounted Cash Flow Forward Market Price $ (36.45) $ 3.40 $ (7.55) (a) Represents market prices in dollars per MWh. (b) The weighted average is the product of the forward market price of the underlying commodity and volume weighted by term.
Sensitivity of Fair Value Measurements	Uncertainty of Fair Value Measurements Significant Unobservable Input Position Change in Input Impact on Fair Value Forward Market Price Buy Increase (Decrease) Higher (Lower) Forward Market Price Sell Increase (Decrease) Lower (Higher)

Income Taxes (Tables)

Income Taxes (Tables)	3 Months Ended
	Mar. 31, 2023
Schedule of Effective Income Tax Rate Reconciliation	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) % Three Months Ended March 31, 2022 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo U.S. Federal Statutory Rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % Increase (decrease) due to: State Income Tax, net of Federal Benefit 1.5 % 0.3 % 2.6 % 2.9 % 1.6 % 0.7 % 0.6 % 2.3 % Tax Reform Excess ADIT Reversal (6.6) % (2.0) % 0.3 % (5.8) % (17.3) % (7.8) % (15.3) % (4.9) % Production and Investment Tax Credits (8.0) % (0.2) % — % — % (1.4) % — % (26.2) % (23.1) % Flow Through 0.3 % 0.3 % 0.3 % 1.7 % (1.9) % 0.9 % 0.6 % (0.6) % AFUDC Equity (0.9) % (0.9) % (1.6) % (0.7) % (0.6) % (0.6) % (0.7) % (0.5) % Discrete Tax Adjustments (0.6) % — % — % (0.6) % — % — % — % — % Other 0.2 % (0.1) % — % — % (0.2) % — % (0.8) % 0.6 % Effective Income Tax Rate 6.9 % 18.4 % 22.6 % 18.5 % 1.2 % 14.2 % (20.8) % (5.2) %

Financing Activities (Tables)

Financing Activities (Tables)	3 Months Ended
	Mar. 31, 2023
Long-term Debt	Type of Debt March 31, 2023 December 31, 2022 (in millions) Senior Unsecured Notes $ 32,654.3 $ 30,174.8 Pollution Control Bonds 1,770.4 1,770.2 Notes Payable 190.0 269.7 Securitization Bonds 463.4 487.8 Spent Nuclear Fuel Obligation (a) 288.8 285.6 Junior Subordinated Notes (b) 2,383.3 2,381.3 Other Long-term Debt 1,394.0 1,431.6 Total Long-term Debt Outstanding 39,144.2 36,801.0 Long-term Debt Due Within One Year 2,905.1 2,486.4 Long-term Debt $ 36,239.1 $ 34,314.6 (a) Pursuant to the Nuclear Waste Policy Act of 1982, I&M, a nuclear licensee, has an obligation to the United States Department of Energy for SNF disposal. The obligation includes a one-time fee for nuclear fuel consumed prior to April 7, 1983. Trust fund assets related to this obligation were $335 million and $330 million as of March 31, 2023 and December 31, 2022, respectively, and are included in Spent Nuclear Fuel and Decommissioning Trusts on the balance sheets. (b) See “Equity Units” section below for additional information.
Long-term Debt Issuances	Principal Interest Company Type of Debt Amount (a) Rate Due Date Issuances: (in millions) (%) AEP Senior Unsecured Notes $ 850.0 5.63 2033 AEPTCo Senior Unsecured Notes 700.0 5.40 2053 I&M Senior Unsecured Notes 500.0 5.63 2053 PSO Senior Unsecured Notes 475.0 5.25 2033 SWEPCo Senior Unsecured Notes 350.0 5.30 2033 Non-Registrant: Transource Energy Other Long-term Debt 1.0 Variable 2025 Total Issuances $ 2,876.0 (a) Amounts indicated on the statements of cash flows are net of issuance costs and premium or discount and will not tie to the issuance amounts.
Retirements and Principal Payments	Principal Interest Company Type of Debt Amount Paid Rate Due Date Retirements and Principal Payments: (in millions) (%) AEP Texas Senior Unsecured Notes $ 125.0 3.09 2023 AEP Texas Securitization Bonds 11.7 2.06 2025 APCo Securitization Bonds 9.7 2.01 2023 APCo Securitization Bonds 3.3 3.77 2028 I&M Senior Unsecured Notes 250.0 3.20 2023 I&M Notes Payable 0.6 Variable 2023 I&M Notes Payable 1.2 Variable 2024 I&M Notes Payable 4.6 Variable 2025 I&M Notes Payable 3.9 0.93 2025 I&M Notes Payable 6.8 3.44 2026 I&M Notes Payable 6.7 5.93 2027 I&M Other Long-term Debt 0.5 6.00 2025 PSO Other Long-term Debt 0.1 3.00 2027 SWEPCo Notes Payable 25.0 6.37 2024 SWEPCo Notes Payable 30.9 4.58 2032 SWEPCo Other Long-term Debt 38.2 4.68 2028 Non-Registrant: Transource Energy Senior Unsecured Notes 1.3 2.75 2050 Total Retirements and Principal Payments $ 519.5
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, 2023 Limit (in millions) AEP Texas $ 453.7 $ — $ 285.3 $ — $ (450.8) $ 500.0 AEPTCo 471.3 309.4 272.9 45.7 260.5 820.0 (a) APCo 373.6 19.8 285.3 18.9 (291.5) 500.0 I&M 475.3 82.9 212.5 28.1 60.0 500.0 OPCo 483.0 — 292.6 — (414.6) 500.0 PSO 375.0 121.5 321.7 74.8 (130.7) 400.0 SWEPCo 401.6 (b) — 353.9 — (18.8) 400.0 (a) Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions.
Nonutility Money Pool Activity	Maximum Loans Average Loans Loans to the Nonutility to the Nonutility to the Nonutility Money Pool as of Company Money Pool Money Pool March 31, 2023 (in millions) AEP Texas $ 6.9 $ 6.8 $ 6.8 SWEPCo 2.1 2.1 2.1
Direct Borrowing Activity	Maximum Maximum Average Average Borrowings from Loans to Authorized Borrowings Loans Borrowings Loans AEP as of AEP as of Short-term from AEP to AEP from AEP to AEP March 31, 2023 March 31, 2023 Borrowing Limit (in millions) $ 29.4 $ 158.1 $ 3.1 $ 80.2 $ 1.6 $ 34.2 $ 50.0 (a) (a) Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions.
Maximum and Minimum Interest Rates for Funds Either Borrowed from or Loaned to Utility Money Pool	Three Months Ended March 31, 2023 2022 Maximum Interest Rate 5.42 % 1.00 % Minimum Interest Rate 4.66 % 0.10 %
Average Interest Rates for Funds Borrowed from and Loaned to Utility Money Pool	Average Interest Rate for Funds Average Interest Rate for Funds Borrowed from the Utility Money Pool Loaned to the Utility Money Pool for Three Months Ended March 31, for Three Months Ended March 31, Company 2023 2022 2023 2022 AEP Texas 5.18 % 0.70 % — % — % AEPTCo 5.09 % 0.66 % 5.29 % 0.60 % APCo 5.14 % 0.55 % 5.12 % 0.62 % I&M 5.12 % 0.63 % 5.16 % 0.62 % OPCo 5.17 % 0.77 % — % 0.48 % PSO 4.84 % 0.69 % 5.11 % 0.65 % SWEPCo 5.12 % 0.98 % — % 0.55 %
Maximum Minimum Average Interest Rates for Funds Borrowed from Loaned to Nonutility Money Pool	Three Months Ended March 31, 2023 Three Months Ended March 31, 2022 Maximum Minimum Average Maximum Minimum Average Interest Rate Interest Rate Interest Rate Interest Rate Interest Rate Interest Rate for Funds for Funds for Funds for Funds for Funds for Funds Loaned to Loaned to Loaned to Loaned to Loaned to Loaned to the Nonutility the Nonutility the Nonutility the Nonutility the Nonutility the Nonutility Company Money Pool Money Pool Money Pool Money Pool Money Pool Money Pool AEP Texas 5.42 % 4.66 % 5.12 % 1.00 % 0.46 % 0.62 % SWEPCo 5.42 % 4.66 % 5.13 % 1.00 % 0.46 % 0.62 %
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 2023 5.38 % 4.53 % 5.38 % 4.53 % 5.03 % 5.15 % 2022 1.00 % 0.46 % 1.00 % 0.46 % 0.66 % 0.60 %
Short Term Debt	March 31, 2023 December 31, 2022 Outstanding Interest Outstanding Interest Company Type of Debt Amount Rate (a) Amount Rate (a) (dollars in millions) AEP Securitized Debt for Receivables (b) $ 750.0 5.05 % $ 750.0 4.67 % AEP Commercial Paper 1,981.1 5.20 % 2,862.2 4.80 % AEP Term Loan 500.0 5.67 % — — % AEP Term Loan 150.0 5.63 % 150.0 5.17 % AEP Term Loan 125.0 5.64 % 125.0 5.17 % AEP Term Loan 100.0 5.64 % 100.0 5.23 % AEP Term Loan — — % 125.0 4.87 % SWEPCo Notes Payable 16.0 7.27 % — — % AEP Total Short-term Debt $ 3,622.1 $ 4,112.2 (a) Weighted-average rate as of March 31, 2023 and December 31, 2022, respectively. (b) Amount of securitized debt for receivables as accounted for under the “Transfers and Servicing” accounting guidance.
Comparative Accounts Receivable Information	Three Months Ended March 31, 2023 2022 (dollars in millions) Effective Interest Rates on Securitization of Accounts Receivable 4.86 % 0.31 % Net Uncollectible Accounts Receivable Written-Off $ 6.9 $ 7.4
Customer Accounts Receivable Managed Portfolio	March 31, 2023 December 31, 2022 (in millions) Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts $ 1,091.8 $ 1,167.7 Short-term – Securitized Debt of Receivables 750.0 750.0 Delinquent Securitized Accounts Receivable 49.3 44.2 Bad Debt Reserves Related to Securitization 41.2 39.7 Unbilled Receivables Related to Securitization 287.3 360.9
Accounts Receivable and Accrued Unbilled Revenues	Company March 31, 2023 December 31, 2022 (in millions) APCo $ 195.5 $ 194.4 I&M 167.9 166.9 OPCo 457.5 478.6 PSO 134.2 155.5 SWEPCo 157.8 194.0
Fees Paid to AEP Credit for Customer Accounts Receivable Sold	Three Months Ended March 31, Company 2023 2022 (in millions) APCo $ 4.9 $ 1.3 I&M 3.9 1.7 OPCo 7.3 7.4 PSO 3.2 0.9 SWEPCo 4.3 1.3
Proceeds on Sale of Receivables to AEP Credit	Three Months Ended March 31, Company 2023 2022 (in millions) APCo $ 506.2 $ 415.5 I&M 525.4 513.4 OPCo 884.4 716.6 PSO 416.3 363.4 SWEPCo 437.6 394.5

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	3 Months Ended	12 Months Ended
	Mar. 31, 2023	Dec. 31, 2022
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Consolidated Assets And Liabilities Of Variable Interest Entities	American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities March 31, 2023 Registrant Subsidiaries SWEPCo I&M AEP Texas Transition Funding AEP Texas Restoration Funding APCo (in millions) ASSETS Current Assets $ 23.0 $ 84.3 $ 43.0 $ 13.4 $ 6.1 Net Property, Plant and Equipment — 154.3 — — — Other Noncurrent Assets 135.1 76.0 125.2 (a) 163.0 (b) 157.4 (c) Total Assets $ 158.1 $ 314.6 $ 168.2 $ 176.4 $ 163.5 LIABILITIES AND EQUITY Current Liabilities $ 33.5 $ 84.2 $ 74.3 $ 30.5 $ 28.1 Noncurrent Liabilities 124.2 230.4 89.6 144.7 133.5 Equity 0.4 — 4.3 1.2 1.9 Total Liabilities and Equity $ 158.1 $ 314.6 $ 168.2 $ 176.4 $ 163.5 (a) Includes an intercompany item eliminated in consolidation of $14 million. (b) Includes an intercompany item eliminated in consolidation of $7 million . (c) Includes an intercompany item eliminated in consolidation of $2 million . American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities March 31, 2023 Other Consolidated VIEs AEP Credit Protected Transource Energy (in millions) ASSETS Current Assets $ 1,092.6 $ 203.2 $ 22.1 Net Property, Plant and Equipment — — 495.1 Other Noncurrent Assets 8.9 — 6.8 Total Assets $ 1,101.5 $ 203.2 $ 524.0 LIABILITIES AND EQUITY Current Liabilities $ 1,043.2 $ 50.2 $ 33.4 Noncurrent Liabilities 0.9 78.0 219.0 Equity 57.4 75.0 271.6 Total Liabilities and Equity $ 1,101.5 $ 203.2 $ 524.0	American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities December 31, 2022 Registrant Subsidiaries SWEPCo I&M AEP Texas Transition Funding AEP Texas Restoration Funding APCo (in millions) ASSETS Current Assets $ 108.3 $ 90.2 $ 27.0 $ 21.1 $ 13.5 Net Property, Plant and Equipment 7.2 179.1 — — — Other Noncurrent Assets 130.0 94.0 140.9 (a) 168.8 (b) 164.6 (c) Total Assets $ 245.5 $ 363.3 $ 167.9 $ 189.9 $ 178.1 LIABILITIES AND EQUITY Current Liabilities $ 25.4 $ 90.0 $ 73.2 $ 31.3 $ 29.3 Noncurrent Liabilities 219.4 273.3 90.4 157.4 146.9 Equity 0.7 — 4.3 1.2 1.9 Total Liabilities and Equity $ 245.5 $ 363.3 $ 167.9 $ 189.9 $ 178.1 (a) Includes an intercompany item eliminated in consolidation of $16 million . (b) Includes an intercompany item eliminated in consolidation of $7 million . (c) Includes an intercompany item eliminated in consolidation of $2 million . American Electric Power Company, Inc. and Subsidiary Companies Variable Interest Entities December 31, 2022 Other Consolidated VIEs AEP Credit Protected Transource Energy Apple Blossom and Black Oak Santa Rita East Dry Lake (in millions) ASSETS Current Assets $ 1,181.0 $ 194.5 $ 23.5 $ 8.3 $ 21.3 $ 4.0 Net Property, Plant and Equipment — — 482.3 216.5 421.6 142.6 Other Noncurrent Assets 9.0 0.3 2.7 13.6 0.1 0.3 Total Assets $ 1,190.0 $ 194.8 $ 508.5 $ 238.4 $ 443.0 $ 146.9 LIABILITIES AND EQUITY Current Liabilities $ 1,087.8 $ 46.4 $ 22.8 $ 4.5 $ 9.6 $ 1.0 Noncurrent Liabilities 0.9 79.1 218.6 5.4 7.3 0.7 Equity 101.3 69.3 267.1 228.5 426.1 145.2 Total Liabilities and Equity $ 1,190.0 $ 194.8 $ 508.5 $ 238.4 $ 443.0 $ 146.9

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	3 Months Ended
	Mar. 31, 2023
Disaggregated Revenues from Contracts with Customers	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, 2022 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation & Marketing Corporate and Other Reconciling Adjustments AEP Consolidated (in millions) Retail Revenues: Residential Revenues $ 1,150.8 $ 600.6 $ — $ — $ — $ — $ 1,751.4 Commercial Revenues 572.9 289.7 — — — — 862.6 Industrial Revenues 563.0 133.3 — — — (0.4) 695.9 Other Retail Revenues 47.4 11.6 — — — — 59.0 Total Retail Revenues 2,334.1 1,035.2 — — — (0.4) 3,368.9 Wholesale and Competitive Retail Revenues: Generation Revenues 187.2 — — 40.3 — — 227.5 Transmission Revenues (a) 105.3 154.9 414.5 — — (361.8) 312.9 Renewable Generation Revenues (b) — — — 22.4 — (0.8) 21.6 Retail, Trading and Marketing Revenues (c) — — — 388.8 3.2 (9.0) 383.0 Total Wholesale and Competitive Retail Revenues 292.5 154.9 414.5 451.5 3.2 (371.6) 945.0 Other Revenues from Contracts with Customers (b) 61.6 53.8 (0.2) 8.6 13.9 (18.6) 119.1 Total Revenues from Contracts with Customers 2,688.2 1,243.9 414.3 460.1 17.1 (390.6) 4,433.0 Other Revenues: Alternative Revenue Programs (d) (0.8) (3.4) (2.9) — — 1.3 (5.8) Other Revenues (b) (e) — 6.3 — 159.2 2.8 (2.9) 165.4 Total Other Revenues (0.8) 2.9 (2.9) 159.2 2.8 (1.6) 159.6 Total Revenues $ 2,687.4 $ 1,246.8 $ 411.4 $ 619.3 $ 19.9 $ (392.2) $ 4,592.6 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $327 million. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $9 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, 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. Three Months Ended March 31, 2022 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 141.9 $ — $ 458.0 $ 231.8 $ 458.7 $ 165.9 $ 175.9 Commercial Revenues 94.9 — 153.9 126.6 194.7 97.5 130.5 Industrial Revenues 30.6 — 153.8 136.5 102.7 78.6 84.7 Other Retail Revenues 8.2 — 20.6 1.3 3.3 21.2 2.4 Total Retail Revenues 275.6 — 786.3 496.2 759.4 363.2 393.5 Wholesale Revenues: Generation Revenues (a) — — 56.2 90.4 — 9.5 61.2 Transmission Revenues (b) 133.1 400.3 41.1 8.8 21.8 9.6 35.2 Total Wholesale Revenues 133.1 400.3 97.3 99.2 21.8 19.1 96.4 Other Revenues from Contracts with Customers (c) 9.3 (0.3) 24.3 29.9 44.6 5.4 5.3 Total Revenues from Contracts with Customers 418.0 400.0 907.9 625.3 825.8 387.7 495.2 Other Revenues: Alternative Revenue Programs (d) (1.3) 0.4 (0.7) — (2.1) (0.1) (0.4) Other Revenues (e) — — 0.1 (0.1) 6.3 — — Total Other Revenues (1.3) 0.4 (0.6) (0.1) 4.2 (0.1) (0.4) Total Revenues $ 416.7 $ 400.4 $ 907.3 $ 625.2 $ 830.0 $ 387.6 $ 494.8 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $36 million primarily related to the PPA with KGPCo. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $323 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $10 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 2023 2024-2025 2026-2027 After 2027 Total (in millions) AEP $ 63.4 $ 160.5 $ 137.1 $ 61.0 $ 422.0 APCo 12.1 32.2 24.3 11.7 80.3 I&M 3.4 9.2 9.2 4.6 26.4
Affiliated Accounts Receivable Contracts with Customers	Company March 31, 2023 December 31, 2022 (in millions) AEP Texas $ — $ 0.1 AEPTCo 122.5 113.8 APCo 65.1 64.5 I&M 56.4 75.3 OPCo 57.5 49.9 PSO 12.7 18.8 SWEPCo 19.6 19.1

Significant Accounting Matter_3

Significant Accounting Matters (Details) - USD ($) $ / shares in Units, $ in Thousands		3 Months Ended
		Mar. 31, 2023	Mar. 31, 2022	Dec. 31, 2022	Dec. 31, 2021
Amounts Attributable to AEP Common Shareholders
Earnings Attributable to Common Shareholders		$ 397,000	$ 714,700
Weighted Average Number of Basic AEP Common Shares Outstanding		514,176,648	506,050,147
Total Basic Earnings Per Share Attributable to AEP Common Shareholders		$ 0.77	$ 1.41
Weighted Average Dilutive Effect of:
Weighted Average Number of Diluted AEP Common Shares Outstanding		515,598,090	507,658,522
Total Diluted Earnings Per Share Attributable to AEP Common Shareholders		$ 0.77	$ 1.41
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		$ 343,500		$ 509,400
Restricted Cash		50,000		47,100
Total Cash, Cash Equivalents and Restricted Cash		393,500	$ 725,500	556,500	$ 451,400
Proceeds from Issuance of Debt	[1]	2,876,000
Securities Received as Collateral		108,000		481,000
AEP Texas Inc. [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		100		100
Restricted Cash		42,500		32,700
Total Cash, Cash Equivalents and Restricted Cash		42,600	40,000	32,800	30,500
AEP Transmission Co [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		0	0	0	0
Appalachian Power Co [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		7,100		7,500
Restricted Cash		7,500		14,400
Total Cash, Cash Equivalents and Restricted Cash		14,600	16,000	21,900	20,100
Indiana Michigan Power Co [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		8,500	3,300	4,200	1,300
Ohio Power Co [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		9,100		9,600
Total Cash, Cash Equivalents and Restricted Cash		9,100	7,400	9,600	3,000
Public Service Co Of Oklahoma [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		3,800	2,900	4,000	1,300
Southwestern Electric Power Co [Member]
Amounts Attributable to AEP Common Shareholders
Earnings Attributable to Common Shareholders		40,600	44,100
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		$ 8,200	$ 58,100	$ 88,400	$ 51,200
Restricted Stock Units and Performance Share Units [Member]
Weighted Average Dilutive Effect of:
Weighted Average Dilutive Effect of Shares		1,400,000	1,600,000
Dilutive Securities, Effect on Basic Earnings Per Share		$ 0	$ 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
		Mar. 31, 2023	Sep. 30, 2022	Mar. 31, 2022
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		$ 83.7		$ 184.8
Change in Fair Value Recognized in AOCI		(203)		285
Commodity
Generation & Marketing Revenues		4,690.9		4,592.6
Interest Rate
Interest Expense		415.7		313.4
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		43.6		(49.7)
Income Tax (Expense) Benefit		10.4		52.8
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		34.5		(39.2)
Net Current Period Other Comprehensive Income (Loss)		(151.8)		245.8
Ending Balance in AOCI		(68.1)		430.6
Reclassification of KPCo Pension and OPEB Regulatory Assets from AOCI
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		21.1
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		16.7
Cash Flow Hedges [Member] | Interest Rate [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		0.3		(21.3)
Change in Fair Value Recognized in AOCI		5.2		6.8
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0.7		1.1
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0.6		0.9
Net Current Period Other Comprehensive Income (Loss)		5.8		7.7
Ending Balance in AOCI		6.1		(13.6)
Cash Flow Hedges [Member] | Interest Rate [Member] | Reclassification of KPCo Pension and OPEB Regulatory Assets from AOCI
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0
Cash Flow Hedges [Member] | Commodity [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		223.5		163.7
Change in Fair Value Recognized in AOCI		(195.3)		278.2
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		47		(48)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		37.1		(37.9)
Net Current Period Other Comprehensive Income (Loss)		(158.2)		240.3
Ending Balance in AOCI		65.3		404
Cash Flow Hedges [Member] | Commodity [Member] | Reclassification of KPCo Pension and OPEB Regulatory Assets from AOCI
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0
Pension and OPEB [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(140.1)		42.4
Change in Fair Value Recognized in AOCI		(12.9)		0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(4.1)		(2.8)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(3.2)		(2.2)
Net Current Period Other Comprehensive Income (Loss)		0.6		(2.2)
Ending Balance in AOCI		(139.5)		40.2
Pension and OPEB [Member] | Reclassification of KPCo Pension and OPEB Regulatory Assets from AOCI
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		21.1
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		16.7
Accumulated Other Comprehensive Income [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Net Current Period Other Comprehensive Income (Loss)			$ (151.8)	245.8
Generation and Marketing [Member]
Commodity
Generation & Marketing Revenues		326.9		609.5
Reclassifications from Accumulated Other Comprehensive Income [Member]
Interest Rate
Interest Expense	[1]	0.7		1.1
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(5.3)		(4.9)
Amortization of Actuarial (Gains) Losses		1.2		2.1
Income Tax (Expense) Benefit		9.1		(10.5)
Reclassifications from Accumulated Other Comprehensive Income [Member] | Reclassification of KPCo Pension and OPEB Regulatory Assets from AOCI
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit		4.4
Reclassifications from Accumulated Other Comprehensive Income [Member] | Cash Flow Hedges [Member] | Interest Rate [Member]
Interest Rate
Interest Expense	[1]	0.7		1.1
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		0.1		0.2
Reclassifications from Accumulated Other Comprehensive Income [Member] | Cash Flow Hedges [Member] | Interest Rate [Member] | Reclassification of KPCo Pension and OPEB Regulatory Assets from AOCI
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit		0
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		9.9		(10.1)
Reclassifications from Accumulated Other Comprehensive Income [Member] | Cash Flow Hedges [Member] | Commodity [Member] | Reclassification of KPCo Pension and OPEB Regulatory Assets from AOCI
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit		0
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)		(5.3)		(4.9)
Amortization of Actuarial (Gains) Losses		1.2		2.1
Income Tax (Expense) Benefit		(0.9)		(0.6)
Reclassifications from Accumulated Other Comprehensive Income [Member] | Pension and OPEB [Member] | Reclassification of KPCo Pension and OPEB Regulatory Assets from AOCI
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit		4.4
Reclassifications from Accumulated Other Comprehensive Income [Member] | Generation and Marketing [Member]
Commodity
Generation & Marketing Revenues	[1]			(0.1)
Reclassifications from Accumulated Other Comprehensive Income [Member] | Generation and Marketing [Member] | Cash Flow Hedges [Member] | Interest Rate [Member]
Commodity
Generation & Marketing Revenues	[1]			0
Reclassifications from Accumulated Other Comprehensive Income [Member] | Generation and Marketing [Member] | Cash Flow Hedges [Member] | Commodity [Member]
Commodity
Generation & Marketing Revenues	[1]			(0.1)
Reclassifications from Accumulated Other Comprehensive Income [Member] | Generation and Marketing [Member] | Pension and OPEB [Member]
Commodity
Generation & Marketing Revenues	[1]			0
Reclassifications from Accumulated Other Comprehensive Income [Member] | Purchased Electricity for Resale [Member]
Commodity
Purchased Electricity for Resale	[1]	47		(47.9)
Reclassifications from Accumulated Other Comprehensive Income [Member] | Purchased Electricity for Resale [Member] | Cash Flow Hedges [Member] | Interest Rate [Member]
Commodity
Purchased Electricity for Resale	[1]	0		0
Reclassifications from Accumulated Other Comprehensive Income [Member] | Purchased Electricity for Resale [Member] | Cash Flow Hedges [Member] | Commodity [Member]
Commodity
Purchased Electricity for Resale	[1]	47		(47.9)
Reclassifications from Accumulated Other Comprehensive Income [Member] | Purchased Electricity for Resale [Member] | Pension and OPEB [Member]
Commodity
Purchased Electricity for Resale	[1]	0		0
AEP Texas Inc. [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(8.6)		(6.5)
Change in Fair Value Recognized in AOCI		(0.7)		0
Interest Rate
Interest Expense		56.9		45.5
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0.2		0.4
Income Tax (Expense) Benefit		10.7		15.7
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0.1		0.3
Net Current Period Other Comprehensive Income (Loss)		(0.6)		0.3
Ending Balance in AOCI		(9.2)		(6.2)
AEP Texas Inc. [Member] | Cash Flow Hedges [Member] | Interest Rate [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(0.3)		(1.3)
Change in Fair Value Recognized in AOCI		(0.2)		0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0.3		0.4
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0.2		0.3
Net Current Period Other Comprehensive Income (Loss)		0		0.3
Ending Balance in AOCI		(0.3)		(1)
AEP Texas Inc. [Member] | Pension and OPEB [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(8.3)		(5.2)
Change in Fair Value Recognized in AOCI		(0.5)		0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(0.1)		0
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(0.1)		0
Net Current Period Other Comprehensive Income (Loss)		(0.6)		0
Ending Balance in AOCI		(8.9)		(5.2)
AEP Texas Inc. [Member] | Accumulated Other Comprehensive Income [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Net Current Period Other Comprehensive Income (Loss)		(0.6)		0.3
AEP Texas Inc. [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member]
Interest Rate
Interest Expense	[1]	0.3		0.4
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(0.1)
Income Tax (Expense) Benefit		0.1		0.1
AEP Texas Inc. [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member] | Cash Flow Hedges [Member] | Interest Rate [Member]
Interest Rate
Interest Expense	[1]	0.3		0.4
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		0
Income Tax (Expense) Benefit		0.1		0.1
AEP Texas Inc. [Member] | 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)		(0.1)
Income Tax (Expense) Benefit		0		0
Appalachian Power Co [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(4.8)		24.4
Change in Fair Value Recognized in AOCI		(0.1)		0
Interest Rate
Interest Expense		65.3		54.3
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(1.2)		(1.7)
Income Tax (Expense) Benefit		31.6		27.3
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(0.9)		(1.3)
Net Current Period Other Comprehensive Income (Loss)		(1)		(1.3)
Ending Balance in AOCI		(5.8)		23.1
Appalachian Power Co [Member] | Cash Flow Hedges [Member] | Interest Rate [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		6.7		7.5
Change in Fair Value Recognized in AOCI		0		0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(0.3)		(0.3)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(0.2)		(0.2)
Net Current Period Other Comprehensive Income (Loss)		(0.2)		(0.2)
Ending Balance in AOCI		6.5		7.3
Appalachian Power Co [Member] | Pension and OPEB [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(11.5)		16.9
Change in Fair Value Recognized in AOCI		(0.1)		0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(0.9)		(1.4)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(0.7)		(1.1)
Net Current Period Other Comprehensive Income (Loss)		(0.8)		(1.1)
Ending Balance in AOCI		(12.3)		15.8
Appalachian Power Co [Member] | Accumulated Other Comprehensive Income [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Net Current Period Other Comprehensive Income (Loss)		(1)		(1.3)
Appalachian Power Co [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member]
Interest Rate
Interest Expense	[1]	(0.3)		(0.3)
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(1.2)		(1.4)
Amortization of Actuarial (Gains) Losses		0.3
Income Tax (Expense) Benefit		(0.3)		(0.4)
Appalachian Power Co [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member] | Cash Flow Hedges [Member] | Interest Rate [Member]
Interest Rate
Interest Expense	[1]	(0.3)		(0.3)
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		0		0
Amortization of Actuarial (Gains) Losses		0
Income Tax (Expense) Benefit		(0.1)		(0.1)
Appalachian Power Co [Member] | 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)		(1.2)		(1.4)
Amortization of Actuarial (Gains) Losses		0.3
Income Tax (Expense) Benefit		(0.2)		(0.3)
Indiana Michigan Power Co [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(0.3)		(1.3)
Change in Fair Value Recognized in AOCI		(2.8)		0
Interest Rate
Interest Expense		33.2		30.3
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0.3		0.4
Income Tax (Expense) Benefit		18.3		1.1
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0.2		0.3
Net Current Period Other Comprehensive Income (Loss)		(2.6)		0.3
Ending Balance in AOCI		(2.9)		(1)
Indiana Michigan Power Co [Member] | Cash Flow Hedges [Member] | Interest Rate [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(5.1)		(6.7)
Change in Fair Value Recognized in AOCI		(1.1)		0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0.5		0.5
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0.4		0.4
Net Current Period Other Comprehensive Income (Loss)		(0.7)		0.4
Ending Balance in AOCI		(5.8)		(6.3)
Indiana Michigan Power Co [Member] | Pension and OPEB [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		4.8		5.4
Change in Fair Value Recognized in AOCI		(1.7)		0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(0.2)		(0.1)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(0.2)		(0.1)
Net Current Period Other Comprehensive Income (Loss)		(1.9)		(0.1)
Ending Balance in AOCI		2.9		5.3
Indiana Michigan Power Co [Member] | Accumulated Other Comprehensive Income [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Net Current Period Other Comprehensive Income (Loss)		(2.6)		0.3
Indiana Michigan Power Co [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member]
Interest Rate
Interest Expense	[1]	0.5		0.5
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(0.3)		(0.2)
Amortization of Actuarial (Gains) Losses		0.1		0.1
Income Tax (Expense) Benefit		0.1		0.1
Indiana Michigan Power Co [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member] | Cash Flow Hedges [Member] | Interest Rate [Member]
Interest Rate
Interest Expense	[1]	0.5		0.5
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		0.1		0.1
Indiana Michigan Power Co [Member] | 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)		(0.3)		(0.2)
Amortization of Actuarial (Gains) Losses		0.1		0.1
Income Tax (Expense) Benefit		0		0
Public Service Co Of Oklahoma [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		1.3
Interest Rate
Interest Expense		25.2		18.9
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit		0.8		(1)
Net Current Period Other Comprehensive Income (Loss)		(1.5)
Ending Balance in AOCI		(0.2)
Public Service Co Of Oklahoma [Member] | Cash Flow Hedges [Member] | Interest Rate [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		1.3		0
Change in Fair Value Recognized in AOCI		(1.5)		0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0		0
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0		0
Net Current Period Other Comprehensive Income (Loss)		(1.5)		0
Ending Balance in AOCI		(0.2)		0
Public Service Co Of Oklahoma [Member] | Accumulated Other Comprehensive Income [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Net Current Period Other Comprehensive Income (Loss)		(1.5)
Public Service Co Of Oklahoma [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member] | Cash Flow Hedges [Member] | Interest Rate [Member]
Interest Rate
Interest Expense	[1]	0		0
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit		0		0
Southwestern Electric Power Co [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(4.2)		6.7
Change in Fair Value Recognized in AOCI		0.5		0
Interest Rate
Interest Expense		25		33.1
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(0.5)		(0.4)
Income Tax (Expense) Benefit		(4)		(2.2)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(0.4)		(0.3)
Net Current Period Other Comprehensive Income (Loss)		0.1		(0.3)
Ending Balance in AOCI		(4.1)		6.4
Southwestern Electric Power Co [Member] | Cash Flow Hedges [Member] | Interest Rate [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		1.1		1.2
Change in Fair Value Recognized in AOCI		0.5		0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(0.1)		0.1
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(0.1)		0.1
Net Current Period Other Comprehensive Income (Loss)		0.4		0.1
Ending Balance in AOCI		1.5		1.3
Southwestern Electric Power Co [Member] | Pension and OPEB [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(5.3)		5.5
Change in Fair Value Recognized in AOCI		0		0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(0.4)		(0.5)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(0.3)		(0.4)
Net Current Period Other Comprehensive Income (Loss)		(0.3)		(0.4)
Ending Balance in AOCI		(5.6)		5.1
Southwestern Electric Power Co [Member] | Accumulated Other Comprehensive Income [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Net Current Period Other Comprehensive Income (Loss)		0.1		(0.3)
Southwestern Electric Power Co [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member]
Interest Rate
Interest Expense	[1]	(0.1)		0.1
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(0.5)		(0.5)
Amortization of Actuarial (Gains) Losses		0.1
Income Tax (Expense) Benefit		(0.1)		(0.1)
Southwestern Electric Power Co [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member] | Cash Flow Hedges [Member] | Interest Rate [Member]
Interest Rate
Interest Expense	[1]	(0.1)		0.1
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		0		0
Amortization of Actuarial (Gains) Losses		0
Income Tax (Expense) Benefit		0		0
Southwestern Electric Power Co [Member] | 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)		(0.5)		(0.5)
Amortization of Actuarial (Gains) Losses		0.1
Income Tax (Expense) Benefit		$ (0.1)		$ (0.1)
[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
		Mar. 31, 2023	Dec. 31, 2022
Public Utilities, General Disclosures [Line Items]
Net Investment		$ 73,347	$ 73,339.1
Regulatory Assets, Noncurrent		4,578	4,762
Regulatory Assets, Current		1,380.1	1,310
AEP Texas Inc. [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		12,008	11,681.6
Regulatory Assets, Noncurrent		299.3	298.3
AEP Transmission Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		13,712	13,339.9
Regulatory Assets, Noncurrent		5.8	7.2
Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		12,506.1	12,379.2
Regulatory Assets, Noncurrent		920.4	1,058.6
Regulatory Assets, Current		574.5	473.1
Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		7,416.9	7,411.5
Regulatory Assets, Noncurrent		420.8	459.6
Regulatory Assets, Current		43.3	47.1
Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		8,807.3	8,609.3
Regulatory Assets, Noncurrent		352.8	327.3
Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		5,864.3	5,626.5
Regulatory Assets, Noncurrent		609.8	653.7
Regulatory Assets, Current		178.7	178.7
Public Service Co Of Oklahoma [Member] | Northeastern Plant, Unit 3 | Generating Units Probable of Abandonment [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		128.5
Accelerated Depreciation Regulatory Asset		150.3
Cost of Removal Regulatory Liability	[1]	$ 20.3
Expected Retirement Date	[2]	2026
Depreciation	[3]	$ 14.9
Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		8,342.6	8,262.2
Regulatory Assets, Noncurrent		1,040.9	1,042.4
Net Under-Recovered Fuel Costs		233
Regulatory Assets, Current		326.5	353
Southwestern Electric Power Co [Member] | Dolet Hills Power Station and Related Fuel Operations
Public Utilities, General Disclosures [Line Items]
Share of Net Investment in Dolet Hills Power Station		110
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		33
Recommended Disallowance from Staff or Intervenors		72
Southwestern Electric Power Co [Member] | Pirkey Power Plant and Related Fuel Operations
Public Utilities, General Disclosures [Line Items]
Share of Net Investment in Pirkey Power Plant		177
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		399.6
Accelerated Depreciation Regulatory Asset		95.5
Cost of Removal Regulatory Liability	[4]	$ 58.1
Expected Retirement Date	[5]	2028
Depreciation	[3]	$ 38.3
Southwestern Electric Power Co [Member] | Dolet Hills Power Station | Arkansas
Public Utilities, General Disclosures [Line Items]
Other Asset Impairment Charges		2
Southwestern Electric Power Co [Member] | Dolet Hills Power Station | Texas
Public Utilities, General Disclosures [Line Items]
Other Asset Impairment Charges		12
Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		774.5	919.3
Regulatory Assets Pending Final Regulatory Approval [Member] | AEP Texas Inc. [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		76.3	67
Regulatory Assets Pending Final Regulatory Approval [Member] | Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		143.6	144.5
Regulatory Assets Pending Final Regulatory Approval [Member] | Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		25.3	23.7
Regulatory Assets Pending Final Regulatory Approval [Member] | Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		36.3	33.8
Regulatory Assets Pending Final Regulatory Approval [Member] | Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		29.3	25.6
Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		386.1	547.3
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		21.4	19.3
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | February 2021 Severe Storm Fuel Costs
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	[6]	115.9	121.7
Regulatory Assets, Current		37	37
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Pirkey Power Plant Accelerated Depreciation
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		111.8	116.5
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Welsh Unit 1 and 3 Accelerated Depreciation
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		95.5	85.6
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Dolet Hills Power Station Fuel Costs - Louisiana
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		33.3	32
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Mobile Generation Lease Payments
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		24.6	17.6
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | AEP Texas Inc. [Member] | Mobile Generation Lease Payments
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		24.6	17.6
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Appalachian Power Co [Member] | COVID-19 - Virginia
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		7.1	7
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Indiana Michigan Power Co [Member] | Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		0.1	0.1
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member] | Dolet Hills Power Station Accelerated Depreciation [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		12.1	9.7
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member] | Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		2.1	2.5
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member] | February 2021 Severe Storm Fuel Costs
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	[7]	115.9	121.7
Regulatory Assets, Current		37	37
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member] | Pirkey Power Plant Accelerated Depreciation
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		111.8	116.5
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member] | Welsh Unit 1 and 3 Accelerated Depreciation
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		95.5	85.6
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member] | Dolet Hills Power Station Fuel Costs - Louisiana
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		33.3	32
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Plant Retirement Costs - Asset Retirement Obligation Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		25.9	25.9
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Storm Related Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	[8],[9]	265.1	407.2
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		43.1	55.6
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Storm-Related Costs Recovery Request [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		34
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | 2020-2022 Virginia Triennial Review [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		37.9	37.9
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | AEP Texas Inc. [Member] | Storm Related Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		28.9	26.7
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | AEP Texas Inc. [Member] | Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		13.5	13.4
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | AEP Texas Inc. [Member] | Texas Retail Electric Provider Bad Debt Expense
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		4.1	4.1
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | AEP Texas Inc. [Member] | Vegetation Management Programs
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		5.2	5.2
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Appalachian Power Co [Member] | Plant Retirement Costs - Asset Retirement Obligation Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		25.9	25.9
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Appalachian Power Co [Member] | Storm Related Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		72.1	72.6
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Appalachian Power Co [Member] | Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		0.6	1.1
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Appalachian Power Co [Member] | 2020-2022 Virginia Triennial Review [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		37.9	37.9
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Indiana Michigan Power Co [Member] | Storm Related Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		23	21.6
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Indiana Michigan Power Co [Member] | Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		2.2	2
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Ohio Power Co [Member] | Storm Related Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	[10]	36.3	33.8
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Ohio Power Co [Member] | Storm-Related Costs Recovery Request [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		34
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Public Service Co Of Oklahoma [Member] | Storm Related Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		29.2	25.5
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Public Service Co Of Oklahoma [Member] | Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		0.1	0.1
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	[11]	0	151.5
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member] | Asset Retirement Obligation - Louisiana [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		0	11.8
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member] | Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		$ 15.4	$ 16
[1]Includes Northeastern Plant, Unit 4, which was retired in 2016. Removal of Northeastern Plant, Unit 4, will be performed with the removal of Northeastern Plant, Unit 3, after retirement.[2]Northeastern Plant, Unit 3 is currently being recovered through 2040.[3]Represents the amount of annual depreciation that has been collected from customers over the prior 12-month period.[4]Includes Welsh Plant, Unit 2, which was retired in 2016. Removal of Welsh Plant, Unit 2, will be performed with the removal of Welsh Plant, Units 1 and 3, after retirement.[5]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.[6]Includes $37 million and $37 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of March 31, 2023 and December 31, 2022, respectively. See the “February 2021 Severe Winter Weather Impacts in SPP” section below for additional information.[7]Includes $37 million and $37 million of unrecovered winter storm fuel costs recorded as a current regulatory asset as of March 31, 2023 and December 31, 2022, respectively. See the “February 2021 Severe Winter Weather Impacts in SPP” section below for additional information.[8]In April 2023, OPCo filed a request with the PUCO for recovery of $34 million in Ohio storm-related costs.[9]In April 2023, the LPSC issued an order approving the prudence and future recovery of the Louisiana storm-related costs. See “2021 Louisiana Storm Cost Filing” section below for additional information.[10]In April 2023, OPCo filed a request with the PUCO for recovery of $34 million in storm costs.[11]In April 2023, the LPSC issued an order approving the prudence and future recovery of the Louisiana storm-related costs. See “2021 Louisiana Storm Cost Filing” section below for additional information.

Rate Matters East Companies (De

Rate Matters East Companies (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended
	Apr. 30, 2023	Mar. 31, 2023	Dec. 31, 2022
Public Utilities, General Disclosures [Line Items]
Net Property, Plant and Equipment		$ 73,347	$ 73,339.1
AEP Transmission Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Property, Plant and Equipment		13,712	13,339.9
Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Property, Plant and Equipment		12,506.1	12,379.2
Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Property, Plant and Equipment		7,416.9	7,411.5
Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Net Property, Plant and Equipment		8,807.3	$ 8,609.3
ENEC Filing | Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
2021 Requested Increase in ENEC Revenues		73
2021 Cumulative ENEC Under Recovery		55
2021 Projected ENEC Cost Incease		18
2021 Approved ENEC Rate Increase		7
2021 Approved Reduction in ENEC Projected Costs		48
2022 Requested Increase in ENEC Rates		155
Current Cumulative ENEC Under Recovery		539
2022 Requested Increase in ENEC Rates Second Filing		297
2022 Approved Projected ENEC Rate Increase		31
2022 Approved Overall ENEC Rate Increase		93
2022 Recommended ENEC Under-Recovery Disallowance		83
2022 Recommended Increase in ENEC Rates		$ 13
ENEC Filing | Appalachian Power Co [Member] | Subsequent Event [Member]
Public Utilities, General Disclosures [Line Items]
2023 Alt One Annual Increase in ENEC	$ 293
2023 Alt One Current Year ENEC Increase	89
2023 Alt One Under Recovery	200
2023 Alt Two Annual Increase in ENEC Rates	89
2023 Alt Two Asset Securitization	1,900
2023 Alt Two Under Recovery	553
2023 Alt Two Major Storm Expense Deferrals	88
2023 Alt Two WV Amos and Mountaineer Book Value and CCR and ELG Investments	$ 1,200
Opinion Coal Fired Plants Capacity Factor	69%
Opinion Recommended Disallowance Factor	52.90%
September 2022 Cumulative ENEC Under Recovery Balance	$ 430
Potential Cumulative ENEC Under Recovery Disallowance	285
Michigan Power Supply Cost Recovery Reconciliation | Indiana Michigan Power Co [Member] | Subsequent Event [Member]
Public Utilities, General Disclosures [Line Items]
Recommended Disallowance	$ 18
2020-2022 Virginia Triennial Review [Member] | Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Return on Equity		10.60%
Previously Incurred Costs Deferral Below Authorized ROE Band		$ 38
Requested Annual Base Rate Increase		213
Requested Annual Base Rate Increase Vegetation Management Portion		47
Requested annual Base Rate Incresae Depreciation Expense Portion		$ 35
Ohio ESP Filings [Member] | Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Proprosed ESP Return on Common Equity		10.65%

Rate Matters West Companies (De

Rate Matters West Companies (Details) $ in Millions	3 Months Ended
	Mar. 31, 2023 USD ($) MW	Dec. 31, 2022 USD ($)
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	$ 4,578	$ 4,762
Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	774.5	919.3
Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	609.8	653.7
Public Service Co Of Oklahoma [Member] | Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	29.3	25.6
Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	1,040.9	1,042.4
Southwestern Electric Power Co [Member] | Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	386.1	547.3
AEP Texas Inc. [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	299.3	298.3
AEP Texas Inc. [Member] | Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	$ 76.3	67
ETT Interim Transmission Rates [Member]
Public Utilities, General Disclosures [Line Items]
Parent Ownership Interest In ETT	50%
AEP Share Of ETT Cumulative Revenues Subject To Review	$ 1,600
February 2021 Severe Storm Fuel Costs | Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	312.1
February 2021 Severe Storm Fuel Costs | Southwestern Electric Power Co [Member] | Arkansas
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	$ 71.7	74.9
Remaining Recovery Period	6 years
February 2021 Severe Storm Fuel Costs | Southwestern Electric Power Co [Member] | Louisiana Jurisdiction [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	$ 115.9	121.7
February 2021 Severe Storm Fuel Costs | Southwestern Electric Power Co [Member] | Texas
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	$ 124.5	132.4
Approved Carrying Charge	1.65%
Remaining Recovery Period	5 years
February 2021 Severe Storm Fuel Costs | Southwestern Electric Power Co [Member] | Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		$ 329
2012 Texas Base Rate Case [Member] | Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
2013 Reversal Of Previously Recorded Regulatory Disallowances	$ 114
Estimated Reduced Annual Revenues	15
2012 Texas Base Rate Case [Member] | Southwestern Electric Power Co [Member] | Minimum [Member]
Public Utilities, General Disclosures [Line Items]
Estimated Turk AFUDC Disallowance	80
Estimated Turk AFUDC Refunds	0
2012 Texas Base Rate Case [Member] | Southwestern Electric Power Co [Member] | Maximum [Member]
Public Utilities, General Disclosures [Line Items]
Estimated Turk AFUDC Disallowance	90
Estimated Turk AFUDC Refunds	190
2016 Texas Base Rate Case [Member] | Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Net Increase in Texas Annual Revenues	$ 69
Requested Return on Equity	10%
Approved Net Increase in Texas Annual Revenues	$ 50
Approved Return on Common Equity	9.60%
Approved Additional Vegetation Management Expenses	$ 2
Impairment Charge Total	19
Impairment Charge Welsh Plant, Unit 2	7
Impairment Charge Disallowed Plant Investments	12
Additional Revenues Recognized to be Surcharged to Customers	32
Additional Recognized Expenses Consisting Primarily of Depreciation and Vegetation Management	$ 7
2020 Texas Base Rate Case [Member] | Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Approved Return on Common Equity	9.25%
Impairment Charge Total	$ 12
Requested Annual Increase	$ 105
Requested Return on Equity	10.35%
Requested Net Annual Increase	$ 90
Revised Requested Annual Increase	100
Revised Requested Net Annual Increase	85
Approved Annual Revenue Increase	39
Amount of Approved Increase Related to Vegetation Management	5
Amount of Approved Increase Related to Storm Catastrophe Reserve	$ 2
2020 Louisiana Base Rate Case | Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Return on Equity	10.35%
Approved Return on Common Equity	9.50%
Requested Annual Increase	$ 134
Revised Requested Annual Increase	95
Approved Annual Revenue Increase	27
Authorized Annual Base Rate Increase	21
Approved Rider to Recover Dolet Hills and Pirkey Costs	14
Reduction in Fuel Costs	$ 8
2021 Louisiana Storm Cost Filing | Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Interim WACC	3.125%
Approved Deferred Storm Costs	$ 150
AEP Texas Interim Transmission and Distribution Rates [Member] | AEP Texas Inc. [Member]
Public Utilities, General Disclosures [Line Items]
AEP Texas Cumulative Revenues Subject to Review	$ 702
2022 Oklahoma Base Rate Case [Member] | Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Requested Return on Equity	10.40%
Amount of Increase Related to Annual Depreciation Expense	$ 47
Requested Debt Capital Structure	45.40%
Requested Equity Capital Structure	54.60%
Requested Net Increase in Oklahoma Annual Revenues	$ 173
Amount of Increase Related to Annual Amortization Expense	$ 16
Wind Generation MWs | MW	154
OCC Staff and Intervenor Recommended Plant Investments	$ 9
2022 Oklahoma Base Rate Case [Member] | Public Service Co Of Oklahoma [Member] | Minimum [Member]
Public Utilities, General Disclosures [Line Items]
OCC Staff and Intervenor Recommended Annual Revenue Change Range	$ 42
OCC Staff and Intervenor Recommended ROE Range	8.60%
2022 Oklahoma Base Rate Case [Member] | Public Service Co Of Oklahoma [Member] | Maximum [Member]
Public Utilities, General Disclosures [Line Items]
OCC Staff and Intervenor Recommended Annual Revenue Change Range	$ 49
OCC Staff and Intervenor Recommended ROE Range	9.50%

Rate Matters FERC (Details)

Rate Matters FERC (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Mar. 31, 2021
FERC PJM Transmission Formula Rate Challenge [Member]
Public Utilities, General Disclosures [Line Items]
Stand Alone Treatment of NOLCs Annual Revenue Increase	$ 60	$ 60	$ 78
PJM Portion of Annual Revenue Increase	40	$ 53	$ 56
FERC RTO Incentive Complaint [Member]
Public Utilities, General Disclosures [Line Items]
Estimated Pretax Income Reduction	20
Independence Energy Connection Project [Member]
Public Utilities, General Disclosures [Line Items]
AEP Share of Independence Energy Connection Capital Costs	$ 90
Ohio Power Co [Member] | Ohio Transmission Company [Member] | FERC RTO Incentive Complaint [Member]
Public Utilities, General Disclosures [Line Items]
Basis Point RTO Incentive	50%

Commitments, Guarantees and C_3

Commitments, Guarantees and Contingencies (Details)	3 Months Ended
	Mar. 31, 2023 USD ($)
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	$ 46,400,000
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Damages Representing Lost Mining Fees for Sabine	85,000,000
AEP Wind Holdings LLC [Member] | Generation And Marketing [Member]
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Maximum Potential Amount of Future Payments Associated with Guarantee	78,000,000
Guarantor Obligations, Current Carrying Value	5,000,000
Guarantor Obligations, Current Carrying Value, Contingent Portion	1,000,000
AEP Texas Inc. [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	11,200,000
Appalachian Power Co [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	6,000,000
Indiana Michigan Power Co [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	4,300,000
Ohio Power Co [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	7,400,000
Public Service Co Of Oklahoma [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	4,900,000
Southwestern Electric Power Co [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	5,700,000
Letters of Credit [Member]
Maximum Future Payments for Letters of Credit [Abstract]
Maximum Future Payments for Letters of Credit Issued Under the Uncommitted Facility	299,000,000
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Letters of Credit Limit	1,200,000,000
Uncommitted Facility	450,000,000
Letters of Credit [Member] | AEP Texas Inc. [Member]
Maximum Future Payments for Letters of Credit [Abstract]
Maximum Future Payments for Letters of Credit Issued Under the Uncommitted Facility	1,800,000
March 2027 | Letters of Credit [Member]
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Revolving Credit Facilities	4,000,000,000
March 2024 | Letters of Credit [Member]
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Revolving Credit Facilities	$ 1,000,000,000

Acquisitions and Dispositions (

Acquisitions and Dispositions (Details) $ in Millions	3 Months Ended
	Mar. 31, 2023 USD ($) GWh MW	Mar. 31, 2022 USD ($)	Dec. 31, 2022 USD ($)
Customers	$ 949.8		$ 1,145.1
Net Property, Plant and Equipment	73,347		73,339.1
Assets Held for Sale	1,396.3		0
Accounts Payable, Current	2,269.3		2,670.8
Liabilities Held for Sale	67.2		0
North Central Wind Energy Facilities
Payments to Acquire Property, Plant, and Equipment	2,000
Transmission Operations [Member]
Enterprise Value	2,850
Transmission Operations [Member] | Proceeds for KY Operations
Enterprise Value	2,646
Generation And Marketing [Member] | Competitive Contracted Renewable Portfolio
gain (loss) on Disposition of Business net of Tax	(88.5)
Customers	16.9
Net Property, Plant and Equipment	1,404.7
Disposal Group, Including Discontinued Operation, Other Assets	63.2
Disposal Group, Including Discontinued Operation, Assets	1,484.8
Assets Held for Sale	1,396.3
Accounts Payable, Current	6.8
Asset Retirement Obligation	30.6
Operating Lease, Liability	20.1
Disposal Group, Including Discontinued Operation, Other Liabilities, Current	9.7
Liabilities Held for Sale	67.2
Generation And Marketing [Member] | Competitive Contracted Renewables
Enterprise Value	$ 1,500
Contracted Renewables GWs | GWh	1.4
Competitive Contracted Renewables NBV	$ 1,200
Equity Method Investment, Ownership Percentage	50%
Equity Method Investments	$ 247
Indemnification	70
Proceeds from Sale of Productive Assets	1,200
Gain (Loss) on Disposition of Business	112
gain (loss) on Disposition of Business net of Tax	88
Deferred Tax Assets, Gross	23.5
Other Noncontrolling Interests	192
EQ Method Investments	247
Vertically Integrated Utilities [Member]
Enterprise Value	2,850
Pretax Reduction in Investment Basis	$ 335		363
Vertically Integrated Utilities [Member] | Sundance [Member]
Wind Generation MWs | MW	199
Vertically Integrated Utilities [Member] | Maverick [Member]
Wind Generation MWs | MW	287
Vertically Integrated Utilities [Member] | Traverse [Member]
Wind Generation MWs | MW	998
Vertically Integrated Utilities [Member] | Traverse [Member] | North Central Wind Energy Facilities
Payments to Acquire Property, Plant, and Equipment	$ 1,200
Vertically Integrated Utilities [Member] | North Central Wind Energy Facilities
Wind Generation MWs | MW	1,484
Public Service Co Of Oklahoma [Member]
Percentage of an Asset Acquired	45.50%
Payments to Acquire Property, Plant, and Equipment	$ 146
Customers	61.4		70.1
Net Property, Plant and Equipment	5,864.3		5,626.5
Accounts Payable, Current	$ 155.7		202.9
Southwestern Electric Power Co [Member]
Percentage of an Asset Acquired	54.50%
Payments to Acquire Property, Plant, and Equipment	$ 0	$ (658)
Customers	33.9		38.8
Net Property, Plant and Equipment	8,342.6		8,262.2
Accounts Payable, Current	188.9		213.1
AEP Transmission Co [Member]
Customers	51.9		46.9
Net Property, Plant and Equipment	13,712		13,339.9
Accounts Payable, Current	$ 421.7		$ 427.8

Benefit Plans (Details)

Benefit Plans (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Pension Plans [Member]
Components of Net Periodic Benefit Cost
Service Cost	$ 23.6	$ 30.8
Interest Cost	54.8	37
Expected Return on Plan Assets	(84.8)	(63.4)
Amortization of Prior Service Cost (Credit)	0	0
Amortization of Net Actuarial Loss	0.3	15.8
Net Periodic Benefit Cost (Credit)	(6.1)	20.2
Pension Plans [Member] | AEP Texas Inc. [Member]
Components of Net Periodic Benefit Cost
Service Cost	2	2.8
Interest Cost	4.6	3
Expected Return on Plan Assets	(7)	(5.3)
Amortization of Prior Service Cost (Credit)	0	0
Amortization of Net Actuarial Loss	0	1.3
Net Periodic Benefit Cost (Credit)	(0.4)	1.8
Pension Plans [Member] | Appalachian Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	2.3	2.9
Interest Cost	6.6	4.4
Expected Return on Plan Assets	(11.2)	(8.1)
Amortization of Prior Service Cost (Credit)	0	0
Amortization of Net Actuarial Loss	0	1.8
Net Periodic Benefit Cost (Credit)	(2.3)	1
Pension Plans [Member] | Indiana Michigan Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	3	4
Interest Cost	6.2	4.2
Expected Return on Plan Assets	(11)	(8)
Amortization of Prior Service Cost (Credit)	0	0
Amortization of Net Actuarial Loss	0	1.8
Net Periodic Benefit Cost (Credit)	(1.8)	2
Pension Plans [Member] | Ohio Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	2.1	2.7
Interest Cost	4.9	3.4
Expected Return on Plan Assets	(8.5)	(6.2)
Amortization of Prior Service Cost (Credit)	0	0
Amortization of Net Actuarial Loss	0	1.4
Net Periodic Benefit Cost (Credit)	(1.5)	1.3
Pension Plans [Member] | Public Service Co Of Oklahoma [Member]
Components of Net Periodic Benefit Cost
Service Cost	1.4	1.9
Interest Cost	2.7	1.8
Expected Return on Plan Assets	(4.6)	(3.4)
Amortization of Prior Service Cost (Credit)	0	0
Amortization of Net Actuarial Loss	0	0.7
Net Periodic Benefit Cost (Credit)	(0.5)	1
Pension Plans [Member] | Southwestern Electric Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	1.9	2.6
Interest Cost	3.5	2.3
Expected Return on Plan Assets	(4.8)	(3.7)
Amortization of Prior Service Cost (Credit)	0	0
Amortization of Net Actuarial Loss	0	1
Net Periodic Benefit Cost (Credit)	0.6	2.2
Other Postretirement Benefit Plans [Member]
Components of Net Periodic Benefit Cost
Service Cost	1.1	1.8
Interest Cost	11.6	7.3
Expected Return on Plan Assets	(27.4)	(27.5)
Amortization of Prior Service Cost (Credit)	(15.8)	(17.8)
Amortization of Net Actuarial Loss	3.7	0
Net Periodic Benefit Cost (Credit)	(26.8)	(36.2)
Other Postretirement Benefit Plans [Member] | AEP Texas Inc. [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.1	0.1
Interest Cost	0.9	0.6
Expected Return on Plan Assets	(2.3)	(2.3)
Amortization of Prior Service Cost (Credit)	(1.3)	(1.5)
Amortization of Net Actuarial Loss	0.3	0
Net Periodic Benefit Cost (Credit)	(2.3)	(3.1)
Other Postretirement Benefit Plans [Member] | Appalachian Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.1	0.2
Interest Cost	1.8	1.2
Expected Return on Plan Assets	(4)	(4.1)
Amortization of Prior Service Cost (Credit)	(2.3)	(2.6)
Amortization of Net Actuarial Loss	0.6	0
Net Periodic Benefit Cost (Credit)	(3.8)	(5.3)
Other Postretirement Benefit Plans [Member] | Indiana Michigan Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.2	0.2
Interest Cost	1.3	0.8
Expected Return on Plan Assets	(3.4)	(3.4)
Amortization of Prior Service Cost (Credit)	(2.2)	(2.4)
Amortization of Net Actuarial Loss	0.5	0
Net Periodic Benefit Cost (Credit)	(3.6)	(4.8)
Other Postretirement Benefit Plans [Member] | Ohio Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.1	0.2
Interest Cost	1.2	0.7
Expected Return on Plan Assets	(2.9)	(3)
Amortization of Prior Service Cost (Credit)	(1.6)	(1.8)
Amortization of Net Actuarial Loss	0.4	0
Net Periodic Benefit Cost (Credit)	(2.8)	(3.9)
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	0.6	0.4
Expected Return on Plan Assets	(1.5)	(1.5)
Amortization of Prior Service Cost (Credit)	(1)	(1.1)
Amortization of Net Actuarial Loss	0.2	0
Net Periodic Benefit Cost (Credit)	(1.6)	(2.1)
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	0.5
Expected Return on Plan Assets	(1.8)	(1.9)
Amortization of Prior Service Cost (Credit)	(1.2)	(1.3)
Amortization of Net Actuarial Loss	0.2	0
Net Periodic Benefit Cost (Credit)	$ (2)	$ (2.6)

Business Segments (Details)

Business Segments (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2023		Mar. 31, 2022		Dec. 31, 2022
Reportable Segment Information
Interest Expense		$ 415.7		$ 313.4
Revenue from Contracts with Customers		4,690.9		4,592.6
Revenue from Related Parties		0		0
Revenues		4,690.9		4,592.6
Net Income (Loss)		400.4		718.1
Income Tax (Expense) Benefit		10.4		52.8
Balance Sheet Information
Total Property, Plant and Equipment		96,708.1				$ 97,021.4
Accumulated Depreciation and Amortization		23,361.1				23,682.3
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		73,347				73,339.1
Total Assets		94,517.9	[1]			93,403.3
Long-term Debt Due Within One Year		2,905.1				2,486.4
Long-term Debt		36,239.1				34,314.6
Total Long-term Debt Outstanding		39,144.2				36,801
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reportable Segment Information
Interest Expense	[2]	0.7		1.1
Income Tax (Expense) Benefit		9.1		(10.5)
Interest Rate [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Reportable Segment Information
Interest Expense	[2]	0.7		1.1
Income Tax (Expense) Benefit		0.1		0.2
Vertically Integrated Utilities [Member]
Reportable Segment Information
Revenue from Contracts with Customers		2,816.3		2,646.8
Transmission and Distribution Utilities Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		1,455.3		1,242.2
Generation and Marketing Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		326.9		609.5
Generation and Marketing Revenues [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reportable Segment Information
Revenue from Contracts with Customers	[2]			(0.1)
Generation and Marketing Revenues [Member] | Interest Rate [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Reportable Segment Information
Revenue from Contracts with Customers	[2]			0
Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		92.4		94.1
Revenues		(129.9)	[3]	165.4	[4],[5]
AEP Transmission Co [Member]
Reportable Segment Information
Interest Expense		45.2		37.7
Interest Income		1.5		0.1
Revenues from Related Parties, Net of Provisions for Refund		352.6		324.7
Revenue from Related Parties		357.4		325
Revenues		441.6		400.4
Net Income (Loss)		162.7		155.4
Income Tax (Expense) Benefit		47.7		45.5
Balance Sheet Information
Total Property, Plant and Equipment		14,803.2				14,366.9
Accumulated Depreciation and Amortization		1,091.2				1,027
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		13,712				13,339.9
Total Assets		14,454.7				13,814.2
Long-term Debt Due Within One Year		60				60
Long-term Debt		5,412.1				4,722.8
Total Long-term Debt Outstanding		5,472.1				4,782.8
AEP Transmission Co [Member] | Other Revenues [Member]
Reportable Segment Information
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		89		75.7
Revenue from Contracts with Customers		90		87
Reconciling Adjustments [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0		0
Revenue from Related Parties		(443.7)		(392.2)
Revenues		(443.7)		(392.2)
Net Income (Loss)		0		0
Balance Sheet Information
Total Assets	[8]	(5,583.3)	[1]			(5,783)
Reconciling Adjustments [Member] | Other Revenues [Member]
Reportable Segment Information
Revenues		(0.9)	[3]	(2.9)	[4],[5]
Reconciling Adjustments [Member] | AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0		0
Revenue from Related Parties		0		0
Revenues		0		0
Net Income (Loss)		0		0
Balance Sheet Information
Total Assets	[9]	(5,620.5)				(4,878.8)
Vertically Integrated Utilities [Member]
Reportable Segment Information
Revenue from Related Parties		41.5		40.6
Revenues		2,857.8		2,687.4
Net Income (Loss)		262.2		299.2
Balance Sheet Information
Total Assets		50,164.1	[1]			49,761.8
Vertically Integrated Utilities [Member] | Vertically Integrated Utilities [Member]
Reportable Segment Information
Revenue from Contracts with Customers		2,816.3		2,646.8
Vertically Integrated Utilities [Member] | Other Revenues [Member]
Reportable Segment Information
Revenues		(0.1)	[3]	0	[4],[5]
Transmission And Distribution Utilities [Member]
Reportable Segment Information
Revenue from Related Parties		8.9		4.6
Revenues		1,464.2		1,246.8
Net Income (Loss)		125.7		152.8
Balance Sheet Information
Total Assets		23,437	[1]			22,920.2
Transmission And Distribution Utilities [Member] | Transmission and Distribution Utilities Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		1,455.3		1,242.2
Transmission And Distribution Utilities [Member] | Other Revenues [Member]
Reportable Segment Information
Revenues		11.1	[3]	6.3	[4],[5]
AEP Transmission Holdco [Member]
Reportable Segment Information
Revenue from Related Parties		365.4		328
Revenues		455.5		411.4
Net Income (Loss)		182.4		173.7
Balance Sheet Information
Total Assets		15,883.1	[1]			15,215.8
AEP Transmission Holdco [Member] | Transmission [Member]
Reportable Segment Information
Revenue from Contracts with Customers		90.1		83.4
Generation And Marketing [Member]
Reportable Segment Information
Revenue from Related Parties		0.1		9.8
Revenues		327		619.3
Net Income (Loss)		(156.4)		116
Balance Sheet Information
Total Assets		4,159.8	[1]			4,520.1
Generation And Marketing [Member] | Generation and Marketing Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		326.9		609.5
Generation And Marketing [Member] | Other Revenues [Member]
Reportable Segment Information
Revenues		(141)	[3],[10]	159.2	[4],[5]
All Other [Member]
Reportable Segment Information
Revenue from Related Parties	[11]	27.8		9.2
Revenues	[11]	30.1		19.9
Net Income (Loss)	[11]	(13.5)		(23.6)
Balance Sheet Information
Total Assets	[11],[12]	6,457.2	[1]			6,768.4
All Other [Member] | Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers	[11]	2.3		10.7
Revenues		1	[3]	2.8	[4],[5]
State Transcos [Member] | AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Related Parties		352.6		324.7
Revenues		441.6		400.4
Net Income (Loss)		161.6		155.4
Balance Sheet Information
Total Assets		14,493.6				13,875.6
State Transcos [Member] | AEP Transmission Co [Member] | Transmission [Member]
Reportable Segment Information
Revenue from Contracts with Customers		89		75.7
AEPTCo Parent [Member] | AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0		0
Revenue from Related Parties		0		0
Revenues		0		0
Net Income (Loss)	[13]	1.1		$ 0
Balance Sheet Information
Total Assets	[14]	$ 5,581.6				$ 4,817.4
[1]Amount includes Assets Held for Sale on the balance sheet. See “Planned Disposition of the Competitive Contracted Renewables Portfolio” section of Note 6 for additional information.[2]Amounts reclassified to the referenced line item on the statements of income.[3]Amounts include affiliated and nonaffiliated revenues.[4]Amounts include affiliated and nonaffiliated revenues[5]Generation & Marketing includes economic hedge activity.[6]Amounts include affiliated and nonaffiliated revenues.[7]Amounts include affiliated and nonaffiliated revenues.[8]Reconciling Adjustments for Total Assets primarily include elimination of intercompany advances to affiliates and intercompany accounts receivable.[9]Primarily relates to the elimination of Notes Receivable from the State Transcos.[10]Generation & Marketing includes economic hedge activity.[11]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.[12]Includes elimination of AEP Parent’s investments in wholly-owned subsidiary companies.[13]Includes the elimination of AEPTCo Parent’s equity earnings in the State Transcos.[14]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, 2023 USD ($) MWh MMBTU gal		Mar. 31, 2022 USD ($)	Dec. 31, 2022 USD ($) MMBTU MWh gal
Cash Collateral Netting
Cash Collateral Received Netted Against Risk Management Assets		$ 108,000,000			$ 481,000,000
Fair Value of Derivative Instruments
Current Risk Management Assets		190,600,000			348,800,000
Long-term Risk Management Assets		318,200,000			284,100,000
Total Assets		508,800,000			632,900,000
Current Risk Management Liabilities		166,000,000			145,200,000
Long-term Risk Management Liabilities		315,400,000			345,200,000
Total Liabilities		481,400,000			490,400,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(178,200,000)	[1]	$ 215,300,000
Carrying Amount of Hedged Asset (Liability)	[2],[3]	(860,800,000)			(855,500,000)
Cumulative Fair Value Hedging Adjustment in the Carrying Amount of the Hedged Asset (Liability)	[2],[3]	84,700,000			89,700,000
Gain (Loss) on Hedging Instruments
Gain (Loss) on Fair Value Hedging Instruments	[4]	6,900,000		(44,800,000)
Gain (Loss) on Fair Value Portion of Long Term Debt	[4]	(6,900,000)		44,800,000
Collateral Triggering Events [Abstract]
Fair Value Of Derivative Liabilities Subject To Cross Acceleration Provisions		121,000,000			127,000,000
Fair Value Of Derivative Liabilities Subject To Cross Default Provisions		193,000,000			217,000,000
Derivatives and Hedging (Textuals) [Abstract]
Hedged Liability, Discontinued Fair Value Hedge, Cumulative Increase (Decrease)		(36,000,000)			(38,000,000)
Credit Downgrade Trigger Exposure		0			2,000,000
AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Total Liabilities		800,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(400,000)	[1]	1,300,000
Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		12,400,000			69,100,000
Current Risk Management Liabilities		7,000,000			3,600,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(32,700,000)	[1]	100,000
Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		5,900,000			15,200,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(4,600,000)	[1]	200,000
Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Liabilities		6,000,000			1,800,000
Long-term Risk Management Liabilities		40,900,000			37,900,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(12,300,000)	[1]	24,100,000
Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		9,400,000			25,300,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		16,800,000	[1]	16,500,000
Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		6,300,000			16,400,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		10,400,000	[1]	19,000,000
Risk Management Contracts [Member]
Fair Value of Derivative Instruments
Total Assets	[5]	363,200,000	[6]		315,400,000	[7]
Total Liabilities	[5]	305,600,000	[6]		339,800,000	[7]
Risk Management Contracts [Member] | AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Total Liabilities	[5]	0
Risk Management Contracts [Member] | Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[5],[8]	12,400,000			69,100,000
Total Liabilities	[5],[8]	7,000,000			3,500,000
Risk Management Contracts [Member] | Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[5],[8]	7,000,000			15,400,000
Total Liabilities	[5],[8]	400,000			0
Risk Management Contracts [Member] | Ohio Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[5],[8]	0			0
Total Liabilities	[8]	46,900,000			39,700,000
Risk Management Contracts [Member] | Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Total Assets	[5],[8]	9,400,000			25,300,000
Total Liabilities	[5],[8]	1,100,000			1,600,000
Risk Management Contracts [Member] | Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[5],[8]	6,300,000			16,400,000
Total Liabilities	[5],[8]	1,100,000			1,400,000
Commodity [Member]
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		65,300,000			223,500,000
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		$ (2,000,000)			119,900,000
Derivatives and Hedging (Textuals) [Abstract]
Maximum Term for Exposure to Variability of Future Cash Flows		96 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] | Risk Management Contracts [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	621,100,000			965,400,000
Long-term Risk Management Assets	[9]	494,300,000			565,600,000
Total Assets	[9]	1,115,400,000			1,531,000,000
Current Risk Management Liabilities	[9]	562,500,000			663,800,000
Long-term Risk Management Liabilities	[9]	402,600,000			412,000,000
Total Liabilities	[9]	965,100,000			1,075,800,000
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	150,300,000	[10]		455,200,000
Commodity [Member] | Risk Management Contracts [Member] | AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	0			0
Long-term Risk Management Assets	[9]	0			0
Total Assets	[9]	0			0
Current Risk Management Liabilities	[9]	400,000			0
Long-term Risk Management Liabilities	[9]	0			0
Total Liabilities	[9]	400,000			0
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	(400,000)			0
Commodity [Member] | Risk Management Contracts [Member] | Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	12,800,000			69,300,000
Long-term Risk Management Assets	[9]	500,000			700,000
Total Assets	[9]	13,300,000			70,000,000
Current Risk Management Liabilities	[9]	7,600,000			4,100,000
Long-term Risk Management Liabilities	[9]	500,000			700,000
Total Liabilities	[9]	8,100,000			4,800,000
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	5,200,000	[10]		65,200,000
Commodity [Member] | Risk Management Contracts [Member] | Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	8,100,000			16,000,000
Long-term Risk Management Assets	[9]	5,500,000			500,000
Total Assets	[9]	13,600,000			16,500,000
Current Risk Management Liabilities	[9]	2,700,000			900,000
Long-term Risk Management Liabilities	[9]	4,400,000			300,000
Total Liabilities	[9]	7,100,000			1,200,000
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	6,500,000	[10]		15,300,000
Commodity [Member] | Risk Management Contracts [Member] | Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	0			0
Long-term Risk Management Assets	[9]	0			0
Total Assets	[9]	0			0
Current Risk Management Liabilities	[9]	6,200,000			2,100,000
Long-term Risk Management Liabilities	[9]	40,900,000			37,900,000
Total Liabilities	[9]	47,100,000			40,000,000
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	(47,100,000)	[10]		(40,000,000)
Commodity [Member] | Risk Management Contracts [Member] | Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	9,900,000			24,100,000
Long-term Risk Management Assets	[9]	0			0
Total Assets	[9]	9,900,000			24,100,000
Current Risk Management Liabilities	[9]	1,800,000			2,100,000
Long-term Risk Management Liabilities	[9]	0			0
Total Liabilities	[9]	1,800,000			2,100,000
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	8,100,000	[10]		22,000,000
Commodity [Member] | Risk Management Contracts [Member] | Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	6,400,000			16,800,000
Long-term Risk Management Assets	[9]	0			0
Total Assets	[9]	6,400,000			16,800,000
Current Risk Management Liabilities	[9]	1,400,000			2,000,000
Long-term Risk Management Liabilities	[9]	0			0
Total Liabilities	[9]	1,400,000			2,000,000
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	5,000,000	[10]		14,800,000
Commodity [Member] | Hedging Contracts [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	85,000,000			212,200,000
Long-term Risk Management Assets	[9]	117,000,000			148,900,000
Total Assets	[9]	202,000,000			361,100,000
Current Risk Management Liabilities	[9]	87,500,000			60,400,000
Long-term Risk Management Liabilities	[9]	31,400,000			17,400,000
Total Liabilities	[9]	118,900,000			77,800,000
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	83,100,000	[10]		283,300,000
Interest Rate [Member]
Commodity:
Derivative, Notional Amount		1,700,000,000			1,650,000,000
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		6,100,000			300,000
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		$ 1,900,000			300,000
Derivatives and Hedging (Textuals) [Abstract]
Maximum Term for Exposure to Variability of Future Cash Flows		93 months
Interest Rate [Member] | AEP Texas Inc. [Member]
Commodity:
Derivative, Notional Amount		$ 150,000,000			0
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		(300,000)			(300,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		0			(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		6,500,000			6,700,000
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		800,000			800,000
Interest Rate [Member] | Indiana Michigan Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		(5,800,000)			(5,100,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		(400,000)			(600,000)
Interest Rate [Member] | Ohio Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0
Interest Rate [Member] | Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Notional Amount		0			200,000,000
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		(200,000)			1,300,000
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		0			100,000
Interest Rate [Member] | Southwestern Electric Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		1,500,000			1,100,000
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		300,000			200,000
Interest Rate [Member] | Hedging Contracts [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	8,900,000			1,800,000
Long-term Risk Management Assets	[9]	0			14,300,000
Total Assets	[9]	8,900,000			16,100,000
Current Risk Management Liabilities	[9]	39,500,000			41,400,000
Long-term Risk Management Liabilities	[9]	82,700,000			91,100,000
Total Liabilities	[9]	122,200,000			132,500,000
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	(113,300,000)			(116,400,000)
Interest Rate [Member] | Hedging Contracts [Member] | AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	500,000
Long-term Risk Management Assets	[9]	0
Total Assets	[9]	500,000
Current Risk Management Liabilities	[9]	800,000
Long-term Risk Management Liabilities	[9]	0
Total Liabilities	[9]	800,000
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	(300,000)
Interest Rate [Member] | Hedging Contracts [Member] | Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]				1,600,000
Long-term Risk Management Assets	[9]				0
Total Assets	[9]				1,600,000
Current Risk Management Liabilities	[9]				0
Long-term Risk Management Liabilities	[9]				0
Total Liabilities	[9]				0
Total MTM Derivative Contract Net Assets (Liabilities)	[9]				1,600,000
Gross Amounts of Risk Management Assets/Liabilities Recognized [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		715,000,000			1,179,400,000
Long-term Risk Management Assets		611,300,000			728,800,000
Total Assets		1,326,300,000			1,908,200,000
Current Risk Management Liabilities		689,500,000			765,600,000
Long-term Risk Management Liabilities		516,700,000			520,500,000
Total Liabilities		1,206,200,000			1,286,100,000
Total MTM Derivative Contract Net Assets (Liabilities)		120,100,000	[10]		622,100,000
Gross Amounts of Risk Management Assets/Liabilities Recognized [Member] | AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		500,000
Long-term Risk Management Assets		0
Total Assets		500,000
Current Risk Management Liabilities		1,200,000
Long-term Risk Management Liabilities		0
Total Liabilities		1,200,000
Total MTM Derivative Contract Net Assets (Liabilities)		(700,000)
Gross Amounts of Risk Management Assets/Liabilities Recognized [Member] | Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets					25,700,000
Long-term Risk Management Assets					0
Total Assets					25,700,000
Current Risk Management Liabilities					2,100,000
Long-term Risk Management Liabilities					0
Total Liabilities					2,100,000
Total MTM Derivative Contract Net Assets (Liabilities)					23,600,000
Gross Amounts Offset in the Statement of Financial Position [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[11]	(524,400,000)			(830,600,000)
Long-term Risk Management Assets	[11]	(293,100,000)			(444,700,000)
Total Assets	[11]	(817,500,000)			(1,275,300,000)
Current Risk Management Liabilities	[11]	(523,500,000)			(620,400,000)
Long-term Risk Management Liabilities	[11]	(201,300,000)			(175,300,000)
Total Liabilities	[11]	(724,800,000)			(795,700,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[11]	(92,700,000)	[10]		(479,600,000)
Gross Amounts Offset in the Statement of Financial Position [Member] | AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[11]	0			0
Long-term Risk Management Assets	[11]	0			0
Total Assets	[11]	0			0
Current Risk Management Liabilities	[11]	(400,000)			0
Long-term Risk Management Liabilities	[11]	0			0
Total Liabilities	[11]	(400,000)			0
Total MTM Derivative Contract Net Assets (Liabilities)	[11]	400,000			0
Gross Amounts Offset in the Statement of Financial Position [Member] | Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[11]	(400,000)			(200,000)
Long-term Risk Management Assets	[11]	(500,000)			(700,000)
Total Assets	[11]	(900,000)			(900,000)
Current Risk Management Liabilities	[11]	(600,000)			(500,000)
Long-term Risk Management Liabilities	[11]	(500,000)			(600,000)
Total Liabilities	[11]	(1,100,000)			(1,100,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[11]	200,000			200,000
Gross Amounts Offset in the Statement of Financial Position [Member] | Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[11]	(2,200,000)			(800,000)
Long-term Risk Management Assets	[11]	(4,400,000)			(300,000)
Total Assets	[11]	(6,600,000)			(1,100,000)
Current Risk Management Liabilities	[11]	(2,300,000)			(900,000)
Long-term Risk Management Liabilities	[11]	(4,400,000)			(300,000)
Total Liabilities	[11]	(6,700,000)			(1,200,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[11]	100,000			100,000
Gross Amounts Offset in the Statement of Financial Position [Member] | Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[11]	0			0
Long-term Risk Management Assets	[11]	0			0
Total Assets	[11]	0			0
Current Risk Management Liabilities	[11]	(200,000)			(300,000)
Long-term Risk Management Liabilities	[11]	0			0
Total Liabilities	[11]	(200,000)			(300,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[11]	200,000			300,000
Gross Amounts Offset in the Statement of Financial Position [Member] | Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[11]	(500,000)			(400,000)
Long-term Risk Management Assets	[11]	0			0
Total Assets	[11]	(500,000)			(400,000)
Current Risk Management Liabilities	[11]	(700,000)			(500,000)
Long-term Risk Management Liabilities	[11]	0			0
Total Liabilities	[11]	(700,000)			(500,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[11]	200,000			100,000
Gross Amounts Offset in the Statement of Financial Position [Member] | Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[11]	(100,000)			(400,000)
Long-term Risk Management Assets	[11]	0			0
Total Assets	[11]	(100,000)			(400,000)
Current Risk Management Liabilities	[11]	(300,000)			(600,000)
Long-term Risk Management Liabilities	[11]	0			0
Total Liabilities	[11]	(300,000)			(600,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[11]	200,000			200,000
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[12]	190,600,000			348,800,000
Long-term Risk Management Assets	[12]	318,200,000			284,100,000
Total Assets	[12]	508,800,000			632,900,000
Current Risk Management Liabilities	[12]	166,000,000			145,200,000
Long-term Risk Management Liabilities	[12]	315,400,000			345,200,000
Total Liabilities	[12]	481,400,000			490,400,000
Total MTM Derivative Contract Net Assets (Liabilities)	[12]	27,400,000	[10]		142,500,000
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member] | AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[12]	500,000			0
Long-term Risk Management Assets	[12]	0			0
Total Assets	[12]	500,000			0
Current Risk Management Liabilities	[12]	800,000			0
Long-term Risk Management Liabilities	[12]	0			0
Total Liabilities	[12]	800,000			0
Total MTM Derivative Contract Net Assets (Liabilities)	[12]	(300,000)			0
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member] | Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[12]	12,400,000			69,100,000
Long-term Risk Management Assets	[12]	0			0
Total Assets	[12]	12,400,000			69,100,000
Current Risk Management Liabilities	[12]	7,000,000			3,600,000
Long-term Risk Management Liabilities	[12]	0			100,000
Total Liabilities	[12]	7,000,000			3,700,000
Total MTM Derivative Contract Net Assets (Liabilities)	[12]	5,400,000	[10]		65,400,000
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member] | Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[12]	5,900,000			15,200,000
Long-term Risk Management Assets	[12]	1,100,000			200,000
Total Assets	[12]	7,000,000			15,400,000
Current Risk Management Liabilities	[12]	400,000			0
Long-term Risk Management Liabilities	[12]	0			0
Total Liabilities	[12]	400,000			0
Total MTM Derivative Contract Net Assets (Liabilities)	[12]	6,600,000	[10]		15,400,000
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member] | Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[12]	0			0
Long-term Risk Management Assets	[12]	0			0
Total Assets	[12]	0			0
Current Risk Management Liabilities	[12]	6,000,000			1,800,000
Long-term Risk Management Liabilities	[12]	40,900,000			37,900,000
Total Liabilities	[12]	46,900,000			39,700,000
Total MTM Derivative Contract Net Assets (Liabilities)	[12]	(46,900,000)	[10]		(39,700,000)
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member] | Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[12]	9,400,000			25,300,000
Long-term Risk Management Assets	[12]	0			0
Total Assets	[12]	9,400,000			25,300,000
Current Risk Management Liabilities	[12]	1,100,000			1,600,000
Long-term Risk Management Liabilities	[12]	0			0
Total Liabilities	[12]	1,100,000			1,600,000
Total MTM Derivative Contract Net Assets (Liabilities)	[12]	8,300,000	[10]		23,700,000
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member] | Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[12]	6,300,000			16,400,000
Long-term Risk Management Assets	[12]	0			0
Total Assets	[12]	6,300,000			16,400,000
Current Risk Management Liabilities	[12]	1,100,000			1,400,000
Long-term Risk Management Liabilities	[12]	0			0
Total Liabilities	[12]	1,100,000			1,400,000
Total MTM Derivative Contract Net Assets (Liabilities)	[12]	$ 5,200,000	[10]		$ 15,000,000
Power [Member]
Commodity:
Derivative, Energy Notional Amount | MWh		213.5			226.8
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		7.3			17.9
Power [Member] | Indiana Michigan Power Co [Member]
Commodity:
Derivative, Energy Notional Amount | MWh		4.1			4.2
Power [Member] | Ohio Power Co [Member]
Commodity:
Derivative, Energy Notional Amount | MWh		2.4			2.5
Power [Member] | Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Energy Notional Amount | MWh		1.8			2.9
Power [Member] | Southwestern Electric Power Co [Member]
Commodity:
Derivative, Energy Notional Amount | MWh		1.3			2.2
Natural Gas [Member]
Commodity:
Derivative, Energy Notional Amount | MMBTU		92.8			77.1
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		2.9			1.9
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		3.1			1.9
Natural Gas [Member] | Southwestern Electric Power Co [Member]
Commodity:
Derivative, Energy Notional Amount | MMBTU		1.8			2.1
Heating Oil and Gasoline [Member]
Commodity:
Derivative, Volume Notional Amount | gal		5			6.9
Heating Oil and Gasoline [Member] | AEP Texas Inc. [Member]
Commodity:
Derivative, Volume Notional Amount | gal		1.4			1.9
Heating Oil and Gasoline [Member] | Appalachian Power Co [Member]
Commodity:
Derivative, Volume Notional Amount | gal		0.8			1
Heating Oil and Gasoline [Member] | Indiana Michigan Power Co [Member]
Commodity:
Derivative, Volume Notional Amount | gal		0.5			0.7
Heating Oil and Gasoline [Member] | Ohio Power Co [Member]
Commodity:
Derivative, Volume Notional Amount | gal		1			1.4
Heating Oil and Gasoline [Member] | Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Volume Notional Amount | gal		0.7			0.9
Heating Oil and Gasoline [Member] | Southwestern Electric Power Co [Member]
Commodity:
Derivative, Volume Notional Amount | gal		0.7			1
Interest Rate Contract [Member]
Commodity:
Derivative, Notional Amount		$ 91,400,000			$ 99,900,000
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		(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
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
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
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
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
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
Generation and Marketing Revenues [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(147,400,000)		152,300,000
Generation and Marketing Revenues [Member] | AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
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		0		100,000
Electric Generation, Transmission and Distribution Revenues [Member] | Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(5,300,000)		(100,000)
Electric Generation, Transmission and Distribution Revenues [Member] | Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
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 for Resale [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		700,000		1,500,000
Purchased Electricity for Resale [Member] | AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Purchased Electricity for Resale [Member] | Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		600,000		1,400,000
Purchased Electricity for Resale [Member] | Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Purchased Electricity for Resale [Member] | Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Purchased Electricity for Resale [Member] | Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Purchased Electricity for Resale [Member] | Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Other Operation Expense [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts				600,000
Other Operation Expense [Member] | AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts				200,000
Other Operation Expense [Member] | Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts				0
Other Operation Expense [Member] | Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts				100,000
Other Operation Expense [Member] | Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts				100,000
Other Operation Expense [Member] | Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts				100,000
Other Operation Expense [Member] | Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts				100,000
Maintenance Expense [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		100,000		800,000
Maintenance Expense [Member] | AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		200,000
Maintenance Expense [Member] | Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		100,000
Maintenance Expense [Member] | Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		100,000
Maintenance Expense [Member] | Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		100,000
Maintenance Expense [Member] | Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		100,000
Maintenance Expense [Member] | Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		100,000
Regulatory Assets [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(24,800,000)	[13]	23,600,000
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		(400,000)	[13]	0
Regulatory Assets [Member] | Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(7,100,000)	[13]	(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		(500,000)	[13]	(1,600,000)
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		(12,300,000)	[13]	23,900,000
Regulatory Assets [Member] | Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(1,200,000)	[13]	3,600,000
Regulatory Assets [Member] | Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(1,500,000)	[13]	(2,100,000)
Regulatory Liabilities [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(1,500,000)	[13]	36,500,000
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		0	[13]	900,000
Regulatory Liabilities [Member] | Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(26,200,000)	[13]	(1,400,000)
Regulatory Liabilities [Member] | Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		1,200,000	[13]	1,700,000
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		0	[13]	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		18,000,000	[13]	12,700,000
Regulatory Liabilities [Member] | Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		$ 11,900,000	[13]	$ 20,900,000
[1]Decrease in amounts as of March 31, 2023 are primarily due to decreases in commodity prices for power and natural gas and a decrease in value of FTRs.[2]Amounts include $(36) million and $(38) million as of March 31, 2023 and December 31, 2022, respectively, for the fair value hedge adjustment of hedged debt obligations for which hedge accounting has been discontinued.[3]Amounts included on the Balance Sheet within Noncurrent Liabilities line item Long-term Debt.[4]Gain (Loss) is included in Interest Expense on the statements of income.[5]Amounts in “Other’’ column primarily represent counterparty netting of risk management and hedging contracts and associated cash collateral under the accounting guidance for “Derivatives and Hedging.’’[6]The March 31, 2023 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 2023 and $(6) million in periods 2024-2026; Level 2 matures $24 million in 2023, $105 million in periods 2024-2026, $9 million in periods 2027-2028 and $1 million in periods 2029-2033; Level 3 matures $18 million in 2023, $9 million in periods 2024-2026, $11 million in periods 2027-2028 and $(7) million in periods 2029-2033.  Risk management commodity contracts are substantially comprised of power contracts.[7]The December 31, 2022 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $(7) million in 2023; Level 2 matures $182 million in 2023, $134 million in periods 2024-2026, $10 million in periods 2027-2028 and $1 million in periods 2029-2033; Level 3 matures $128 million in 2023, $6 million in periods 2024-2026, $6 million in periods 2027-2028 and $(5) million in periods 2029-2033.  Risk management commodity contracts are substantially comprised of power contracts.[8]Substantially comprised of power contracts for the Registrant Subsidiaries.[9]Derivative instruments within these categories are disclosed as gross.  These instruments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with the accounting guidance for “Derivatives and Hedging.”[10]Decrease in amounts as of March 31, 2023 are primarily due to decreases in commodity prices for power and natural gas and a decrease in value of FTRs.[11]Amounts include counterparty netting of risk management and hedging contracts and associated cash collateral in accordance with the accounting guidance for “Derivatives and Hedging.”[12]All derivative contracts subject to a master netting arrangement or similar agreement are offset in the statement of financial position.[13]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, 2023	Mar. 31, 2022	Dec. 31, 2022
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		$ 39,144,200,000		$ 36,801,000,000
Long Term Debt, Fair Value	[1]	36,126,400,000		32,915,900,000
Other Temporary Investments
Cost		230,000,000		223,600,000
Gross Unrealized Gains		21,800,000		19,400,000
Gross Unrealized Losses		(7,200,000)		(8,300,000)
Other Short-term Investments		244,600,000		234,700,000
Debt and Equity Securities Within Other Temporary Investments
Proceeds from Investment Sales		0	$ 3,900,000
Purchases of Investments		1,000,000	800,000
Gross Realized Gains on Investment Sales		0	300,000
Gross Realized Losses on Investment Sales		0	100,000
Nuclear Trust Fund Investments
Fair Value		3,501,100,000		3,341,200,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		3,501,100,000		3,341,200,000
Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		1,587,000,000		1,496,300,000
Gross Unrealized Loss		(15,400,000)		(29,000,000)
Securities Activity Within Decommissioning and SNF Trusts
Proceeds from Investment Sales		517,600,000	493,500,000
Purchases of Investments		536,300,000	507,700,000
Gross Realized Gains on Investment Sales		48,500,000	5,800,000
Gross Realized Losses on Investment Sales		8,600,000	7,200,000
Contractual Maturities, Fair Value of Debt Securities
Within 1 year		347,800,000
After 1 year through 5 years		489,100,000
After 5 years through 10 years		215,600,000
After 10 years		224,400,000
Fair Value Measurements (Textuals)
Adjusted Cost of Debt Securities		1,300,000,000		1,200,000,000
Adjusted Cost of Domestic Equity Securities		635,000,000		654,000,000
Other than Temporary Impairment Losses, Investments		(30,500,000)		(28,500,000)
Cash [Member]
Other Temporary Investments
Cost	[2]	50,000,000		47,100,000
Gross Unrealized Gains	[2]	0		0
Gross Unrealized Losses	[2]	0		0
Other Short-term Investments	[2]	50,000,000		47,100,000
Fixed Income Funds [Member]
Nuclear Trust Fund Investments
Fair Value		1,276,900,000		1,188,700,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,276,900,000		1,188,700,000
Fixed Income Funds [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		21,900,000		12,600,000
Gross Unrealized Loss		(12,500,000)		(22,600,000)
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments		(30,500,000)		(28,500,000)
Mutual Funds Fixed Income [Member]
Other Temporary Investments
Cost	[3]	153,400,000		152,400,000
Gross Unrealized Gains	[3]	0		0
Gross Unrealized Losses	[3]	(7,200,000)		(8,300,000)
Other Short-term Investments	[3]	146,200,000		144,100,000
Domestic [Member]
Nuclear Trust Fund Investments
Fair Value	[4]	2,197,700,000		2,131,300,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[4]	2,197,700,000		2,131,300,000
Domestic [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		1,565,100,000		1,483,700,000
Gross Unrealized Loss		(2,900,000)		(6,400,000)
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments		0		0
Mutual Funds Equity [Member]
Other Temporary Investments
Cost		15,200,000		15,100,000
Gross Unrealized Gains		21,800,000		19,400,000
Gross Unrealized Losses		0		0
Other Short-term Investments	[4]	37,000,000		34,500,000
Cash and Cash Equivalents [Member]
Nuclear Trust Fund Investments
Fair Value	[5]	26,500,000		21,200,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[5]	26,500,000		21,200,000
Cash and Cash Equivalents [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		0		0
Gross Unrealized Loss		0		0
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments		0		0
US Government Agencies Debt Securities [Member]
Nuclear Trust Fund Investments
Fair Value		1,207,600,000		1,123,800,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,207,600,000		1,123,800,000
US Government Agencies Debt Securities [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		20,900,000		11,800,000
Gross Unrealized Loss		(6,400,000)		(14,900,000)
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments		(28,300,000)		(18,800,000)
Corporate Debt [Member]
Nuclear Trust Fund Investments
Fair Value		66,000,000		61,600,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		66,000,000		61,600,000
Corporate Debt [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		1,000,000		700,000
Gross Unrealized Loss		(6,100,000)		(7,700,000)
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments		(2,200,000)		(9,600,000)
State and Local Jurisdiction [Member]
Nuclear Trust Fund Investments
Fair Value		3,300,000		3,300,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		3,300,000		3,300,000
State and Local Jurisdiction [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		0		100,000
Gross Unrealized Loss		0		0
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments		0		(100,000)
Other Cash Deposits [Member]
Other Temporary Investments
Cost		11,400,000		9,000,000
Gross Unrealized Gains		0		0
Gross Unrealized Losses		0		0
Other Short-term Investments		11,400,000		9,000,000
AEP Texas Inc. [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		5,522,000,000		5,657,800,000
Long Term Debt, Fair Value		5,009,500,000		5,045,800,000
AEP Transmission Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		5,472,100,000		4,782,800,000
Long Term Debt, Fair Value		4,836,200,000		3,940,500,000
Appalachian Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		5,398,700,000		5,410,500,000
Long Term Debt, Fair Value		5,227,700,000		5,079,200,000
Indiana Michigan Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		3,489,000,000		3,260,800,000
Long Term Debt, Fair Value		3,249,100,000		2,929,000,000
Nuclear Trust Fund Investments
Fair Value		3,501,100,000		3,341,200,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		3,501,100,000		3,341,200,000
Indiana Michigan Power Co [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		1,587,000,000		1,496,300,000
Gross Unrealized Loss		(15,400,000)		(29,000,000)
Securities Activity Within Decommissioning and SNF Trusts
Proceeds from Investment Sales		517,600,000	493,500,000
Purchases of Investments		536,300,000	507,700,000
Gross Realized Gains on Investment Sales		48,500,000	5,800,000
Gross Realized Losses on Investment Sales		8,600,000	$ 7,200,000
Contractual Maturities, Fair Value of Debt Securities
Within 1 year		347,800,000
After 1 year through 5 years		489,100,000
After 5 years through 10 years		215,600,000
After 10 years		224,400,000
Fair Value Measurements (Textuals)
Adjusted Cost of Debt Securities		1,300,000,000		1,200,000,000
Adjusted Cost of Domestic Equity Securities		635,000,000		654,000,000
Other than Temporary Impairment Losses, Investments		(30,500,000)		(28,500,000)
Indiana Michigan Power Co [Member] | Fixed Income Funds [Member]
Nuclear Trust Fund Investments
Fair Value		1,276,900,000		1,188,700,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,276,900,000		1,188,700,000
Indiana Michigan Power Co [Member] | Fixed Income Funds [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		21,900,000		12,600,000
Gross Unrealized Loss		(12,500,000)		(22,600,000)
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments		(30,500,000)		(28,500,000)
Indiana Michigan Power Co [Member] | Domestic [Member]
Nuclear Trust Fund Investments
Fair Value	[4]	2,197,700,000		2,131,300,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[4]	2,197,700,000		2,131,300,000
Indiana Michigan Power Co [Member] | Domestic [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		1,565,100,000		1,483,700,000
Gross Unrealized Loss		(2,900,000)		(6,400,000)
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments		0		0
Indiana Michigan Power Co [Member] | Cash and Cash Equivalents [Member]
Nuclear Trust Fund Investments
Fair Value	[5]	26,500,000		21,200,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[5]	26,500,000		21,200,000
Indiana Michigan Power Co [Member] | Cash and Cash Equivalents [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		0		0
Gross Unrealized Loss		0		0
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments		0		0
Indiana Michigan Power Co [Member] | US Government Agencies Debt Securities [Member]
Nuclear Trust Fund Investments
Fair Value		1,207,600,000		1,123,800,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,207,600,000		1,123,800,000
Indiana Michigan Power Co [Member] | US Government Agencies Debt Securities [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		20,900,000		11,800,000
Gross Unrealized Loss		(6,400,000)		(14,900,000)
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments		(28,300,000)		(18,800,000)
Indiana Michigan Power Co [Member] | Corporate Debt [Member]
Nuclear Trust Fund Investments
Fair Value		66,000,000		61,600,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		66,000,000		61,600,000
Indiana Michigan Power Co [Member] | Corporate Debt [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		1,000,000		700,000
Gross Unrealized Loss		(6,100,000)		(7,700,000)
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments		(2,200,000)		(9,600,000)
Indiana Michigan Power Co [Member] | State and Local Jurisdiction [Member]
Nuclear Trust Fund Investments
Fair Value		3,300,000		3,300,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		3,300,000		3,300,000
Indiana Michigan Power Co [Member] | State and Local Jurisdiction [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		0		100,000
Gross Unrealized Loss		0		0
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments		0		(100,000)
Ohio Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		2,970,800,000		2,970,300,000
Long Term Debt, Fair Value		2,566,600,000		2,516,600,000
Public Service Co Of Oklahoma [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		2,383,600,000		1,912,800,000
Long Term Debt, Fair Value		2,172,600,000		1,635,800,000
Southwestern Electric Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		3,644,800,000		3,391,600,000
Long Term Debt, Fair Value		3,195,900,000		2,870,900,000
Equity Units [Member]
Book Values and Fair Values of Long - term Debt
Long Term Debt, Fair Value		$ 856,000,000		$ 877,000,000
[1]The fair value amounts include debt related to AEP’s Equity Units and had a fair value of $856 million and $877 million as of March 31, 2023 and December 31, 2022, respectively. See “Equity Units” section of Note 12 for additional information.[2]Primarily represents amounts held for the repayment of debt.[3]Primarily short and intermediate maturities which may be sold and do not contain maturity dates.[4]Amounts represent publicly traded equity securities and equity-based mutual funds.[5]Amounts in “Other’’ column primarily represent accrued interest receivables from financial institutions.  Level 1 amounts primarily represent investments in money market funds.

Fair Value Assets and Liabiliti

Fair Value Assets and Liabilities (Details) - USD ($)		3 Months Ended
		Mar. 31, 2023		Mar. 31, 2022	Dec. 31, 2022
Other [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		$ 11,400,000			$ 9,000,000
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		9,400,000			9,900,000
Total Assets		(760,800,000)			(1,245,400,000)
Risk Management Assets
Risk Management Assets		(781,600,000)			(1,264,300,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities		(688,900,000)			(784,700,000)
Other Short-term Investments		244,600,000			234,700,000
Spent Nuclear Fuel and Decommissioning Trusts		3,501,100,000			3,341,200,000
Total Assets		4,254,500,000			4,208,800,000
Risk Management Assets		508,800,000			632,900,000
Risk Management Liabilities		481,400,000			490,400,000
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		160,400,000		$ 103,100,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	(7,100,000)		18,200,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	14,800,000		(19,000,000)
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	(13,900,000)		19,300,000
Settlements		(96,600,000)		(51,600,000)
Transfers into Level 3	[4],[5]	(6,100,000)		2,500,000
Transfers out of Level 3	[5]	1,000,000		2,900,000
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	(7,400,000)		7,400,000
Ending Balance		45,100,000		82,800,000
Fair Value Measurements 1 (Textuals)
Assets Held for Sale		1,396,300,000			0
Liabilities Held for Sale		67,200,000			0
Total Long-term Debt Outstanding		39,144,200,000			36,801,000,000
Level 1 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		233,200,000			225,700,000
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		2,214,800,000			2,142,600,000
Total Assets		2,461,000,000			2,383,300,000
Risk Management Assets
Risk Management Assets		13,000,000			15,000,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		33,500,000			21,800,000
Level 2 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,276,900,000			1,188,700,000
Total Assets		2,324,800,000			2,729,800,000
Risk Management Assets
Risk Management Assets		1,047,900,000			1,541,100,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		952,400,000			1,072,600,000
Level 3 [Member]
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		229,500,000			341,100,000
Risk Management Assets
Risk Management Assets		229,500,000			341,100,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		184,400,000			180,700,000
2023 [Member] | Level 1 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		(14,000,000)			(7,000,000)
2023 [Member] | Level 2 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		24,000,000			182,000,000
2023 [Member] | Level 3 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		18,000,000			128,000,000
2024 - 2026 [Member] | Level 1 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		(6,000,000)
2024 - 2026 [Member] | Level 2 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		105,000,000			134,000,000
2024 - 2026 [Member] | Level 3 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		9,000,000			6,000,000
2027 - 2028 [Member] | Level 2 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		9,000,000			10,000,000
2027 - 2028 [Member] | Level 3 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		11,000,000			6,000,000
2029 - 2033 [Member] | Level 2 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		1,000,000			1,000,000
2029 - 2033 [Member] | Level 3 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		(7,000,000)			(5,000,000)
Risk Management Commodity Contracts [Member] | Other [Member]
Risk Management Assets
Risk Management Assets	[7]	(720,200,000)	[8]		(1,211,500,000)	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	(627,500,000)	[8]		(731,900,000)	[9]
Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[7]	363,200,000	[8]		315,400,000	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	305,600,000	[8]		339,800,000	[9]
Risk Management Commodity Contracts [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets	[7]	13,000,000	[8]		15,000,000	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	33,500,000	[8]		21,800,000	[9]
Risk Management Commodity Contracts [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[7]	861,200,000	[8]		1,197,500,000	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	721,100,000	[8]		870,900,000	[9]
Risk Management Commodity Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[7]	209,200,000	[8]		314,400,000	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	178,500,000	[8]		179,000,000	[9]
Energy Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		190,700,000			204,000,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		166,500,000			167,400,000
Energy Contracts [Member] | Level 3 [Member] | Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	0.74			2.91
Energy Contracts [Member] | Level 3 [Member] | High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	101.65			187.34
Energy Contracts [Member] | Level 3 [Member] | Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	48.48			49.14
FTRs [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		38,800,000			137,100,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		17,900,000			13,300,000
FTRs [Member] | Level 3 [Member] | Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	(55.98)			(36.45)
FTRs [Member] | Level 3 [Member] | High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	101.82			20.72
FTRs [Member] | Level 3 [Member] | Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	(0.45)			1.18
Commodity Hedges [Member] | Other [Member]
Risk Management Assets
Risk Management Assets	[7]	(61,400,000)			(52,800,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	(61,400,000)			(52,800,000)
Commodity Hedges [Member]
Risk Management Assets
Risk Management Assets	[7]	136,700,000			306,500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	53,600,000			23,200,000
Commodity Hedges [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets	[7]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	0			0
Commodity Hedges [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[7]	177,800,000			332,600,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	109,100,000			74,300,000
Commodity Hedges [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[7]	20,300,000			26,700,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	5,900,000			1,700,000
Interest Rate [Member] | Other [Member]
Risk Management Assets
Risk Management Assets		0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0
Interest Rate [Member]
Risk Management Assets
Risk Management Assets		8,900,000			11,000,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		1,700,000
Interest Rate [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets		0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0
Interest Rate [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets		8,900,000			11,000,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		1,700,000
Interest Rate [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0
Fair Value Hedges [Member] | Other [Member]
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0
Fair Value Hedges [Member]
Liabilities, Fair Value Disclosure
Risk Management Liabilities		120,500,000			127,400,000
Fair Value Hedges [Member] | Level 1 [Member]
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0
Fair Value Hedges [Member] | Level 2 [Member]
Liabilities, Fair Value Disclosure
Risk Management Liabilities		120,500,000			127,400,000
Fair Value Hedges [Member] | Level 3 [Member]
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0
AEP Texas Inc. [Member] | Other [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		(400,000)
AEP Texas Inc. [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		42,500,000			32,700,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		43,000,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		800,000
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		5,522,000,000			5,657,800,000
AEP Texas Inc. [Member] | Level 1 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		42,500,000			32,700,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		42,500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0
AEP Texas Inc. [Member] | Level 2 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		1,200,000
AEP Texas Inc. [Member] | Level 3 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0
AEP Texas Inc. [Member] | Risk Management Commodity Contracts [Member] | Other [Member]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	(400,000)
AEP Texas Inc. [Member] | Risk Management Commodity Contracts [Member]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	0
AEP Texas Inc. [Member] | Risk Management Commodity Contracts [Member] | Level 1 [Member]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	0
AEP Texas Inc. [Member] | Risk Management Commodity Contracts [Member] | Level 2 [Member]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	400,000
AEP Texas Inc. [Member] | Risk Management Commodity Contracts [Member] | Level 3 [Member]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	0
AEP Texas Inc. [Member] | Interest Rate [Member] | Other [Member]
Risk Management Assets
Risk Management Assets		0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0
AEP Texas Inc. [Member] | Interest Rate [Member]
Risk Management Assets
Risk Management Assets		500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		800,000
AEP Texas Inc. [Member] | Interest Rate [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets		0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0
AEP Texas Inc. [Member] | Interest Rate [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets		500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		800,000
AEP Texas Inc. [Member] | Interest Rate [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0
AEP Transmission Co [Member]
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		5,472,100,000			4,782,800,000
Appalachian Power Co [Member] | Other [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		(400,000)			(1,000,000)
Appalachian Power Co [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		7,500,000			14,400,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		19,900,000			83,500,000
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		69,100,000		41,700,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	(31,900,000)		(2,900,000)
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	0		0
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	0		0
Settlements		(27,300,000)		(32,400,000)
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]	(4,200,000)		200,000
Ending Balance		5,700,000		6,600,000
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		5,398,700,000			5,410,500,000
Appalachian Power Co [Member] | Level 1 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		7,500,000			14,400,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		7,500,000			14,400,000
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		400,000			700,000
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		12,400,000			69,400,000
Appalachian Power Co [Member] | Risk Management Commodity Contracts [Member] | Other [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	(400,000)			(1,000,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[12]	(600,000)			(1,400,000)
Appalachian Power Co [Member] | Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	12,400,000			69,100,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[12]	7,000,000			3,500,000
Appalachian Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[12]	0			0
Appalachian Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	400,000			700,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[12]	900,000			4,600,000
Appalachian Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	12,400,000			69,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[12]	6,700,000			300,000
Appalachian Power Co [Member] | FTRs [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		12,400,000			69,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		6,700,000			300,000
Appalachian Power Co [Member] | FTRs [Member] | Level 3 [Member] | Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	(1.67)			(2.82)
Appalachian Power Co [Member] | FTRs [Member] | Level 3 [Member] | High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	6.59			18.88
Appalachian Power Co [Member] | FTRs [Member] | Level 3 [Member] | Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	0.79			3.89
Indiana Michigan Power Co [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		9,400,000			9,900,000
Total Assets		8,200,000			8,700,000
Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		3,501,100,000			3,341,200,000
Total Assets		3,508,100,000			3,356,600,000
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		4,600,000		(700,000)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	1,200,000		3,800,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	0		0
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	0		0
Settlements		(4,200,000)		(2,300,000)
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]	(500,000)		200,000
Ending Balance		1,100,000		1,000,000
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		3,489,000,000			3,260,800,000
Indiana Michigan Power Co [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		2,214,800,000			2,142,600,000
Total Assets		2,214,800,000			2,142,600,000
Indiana Michigan Power Co [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,276,900,000			1,188,700,000
Total Assets		1,283,500,000			1,200,000,000
Indiana Michigan Power Co [Member] | Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Total Assets		1,600,000			5,300,000
Indiana Michigan Power Co [Member] | Risk Management Commodity Contracts [Member] | Other [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	(1,200,000)			(1,200,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[12]	(1,400,000)			(1,300,000)
Indiana Michigan Power Co [Member] | Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	7,000,000			15,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[12]	400,000			0
Indiana Michigan Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[12]	0			0
Indiana Michigan Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	6,600,000			11,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[12]	1,300,000			600,000
Indiana Michigan Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	1,600,000			5,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[12]	500,000			700,000
Indiana Michigan Power Co [Member] | FTRs [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		1,600,000			5,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		500,000			700,000
Indiana Michigan Power Co [Member] | FTRs [Member] | Level 3 [Member] | Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	0.24			0.16
Indiana Michigan Power Co [Member] | FTRs [Member] | Level 3 [Member] | High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	4.75			18.79
Indiana Michigan Power Co [Member] | FTRs [Member] | Level 3 [Member] | Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	0.78			1.23
Ohio Power Co [Member]
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		(40,000,000)		(92,500,000)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	(1,300,000)		500,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	0		0
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	0		0
Settlements		1,000,000		1,400,000
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]	(6,600,000)		22,100,000
Ending Balance		(46,900,000)		(68,500,000)
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		2,970,800,000			2,970,300,000
Ohio Power Co [Member] | Risk Management Commodity Contracts [Member] | Other [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[12]	(200,000)			(300,000)
Ohio Power Co [Member] | Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[12]	46,900,000			39,700,000
Ohio Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[12]	0			0
Ohio Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[12]	200,000			0
Ohio Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[12]	46,900,000			40,000,000
Ohio Power Co [Member] | Energy Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		46,900,000			40,000,000
Ohio Power Co [Member] | Energy Contracts [Member] | Level 3 [Member] | Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	14.41			2.91
Ohio Power Co [Member] | Energy Contracts [Member] | Level 3 [Member] | High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	79.98			187.34
Ohio Power Co [Member] | Energy Contracts [Member] | Level 3 [Member] | Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	45.92			48.76
Public Service Co Of Oklahoma [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets					(300,000)
Public Service Co Of Oklahoma [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets					25,300,000
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		23,700,000		12,100,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	16,600,000		12,100,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	0		0
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	0		0
Settlements		(34,300,000)		(19,800,000)
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]	3,300,000		2,100,000
Ending Balance		9,300,000		6,500,000
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		2,383,600,000			1,912,800,000
Public Service Co Of Oklahoma [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets					0
Public Service Co Of Oklahoma [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets					1,600,000
Public Service Co Of Oklahoma [Member] | Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets					24,000,000
Public Service Co Of Oklahoma [Member] | Risk Management Commodity Contracts [Member] | Other [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	(500,000)			1,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[12]	(700,000)			(400,000)
Public Service Co Of Oklahoma [Member] | Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	9,400,000			25,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[12]	1,100,000			1,600,000
Public Service Co Of Oklahoma [Member] | Risk Management Commodity Contracts [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[12]	0			0
Public Service Co Of Oklahoma [Member] | Risk Management Commodity Contracts [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[12]	1,200,000			1,700,000
Public Service Co Of Oklahoma [Member] | Risk Management Commodity Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	9,900,000			24,000,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[12]	600,000			300,000
Public Service Co Of Oklahoma [Member] | FTRs [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		9,900,000			24,000,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		600,000			300,000
Public Service Co Of Oklahoma [Member] | FTRs [Member] | Level 3 [Member] | Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	(21.10)			(36.45)
Public Service Co Of Oklahoma [Member] | FTRs [Member] | Level 3 [Member] | High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	3.04			3.40
Public Service Co Of Oklahoma [Member] | FTRs [Member] | Level 3 [Member] | Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	(4.75)			(7.55)
Public Service Co Of Oklahoma [Member] | Interest Rate [Member] | Other [Member]
Risk Management Assets
Risk Management Assets					(1,600,000)
Public Service Co Of Oklahoma [Member] | Interest Rate [Member]
Risk Management Assets
Risk Management Assets					0
Public Service Co Of Oklahoma [Member] | Interest Rate [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets					0
Public Service Co Of Oklahoma [Member] | Interest Rate [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets					1,600,000
Public Service Co Of Oklahoma [Member] | Interest Rate [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets					0
Southwestern Electric Power Co [Member]
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		14,200,000		10,900,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	12,900,000		9,800,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	0		0
Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income	[3]	0		0
Settlements		(23,000,000)		(16,200,000)
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]	1,700,000		11,200,000
Ending Balance		5,800,000		$ 15,700,000
Fair Value Measurements 1 (Textuals)
Total Long-term Debt Outstanding		3,644,800,000			3,391,600,000
Southwestern Electric Power Co [Member] | Risk Management Commodity Contracts [Member] | Other [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	(100,000)			(400,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[12]	(300,000)			(600,000)
Southwestern Electric Power Co [Member] | Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	6,300,000			16,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[12]	1,100,000			1,400,000
Southwestern Electric Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[12]	0			0
Southwestern Electric Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	0			2,200,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[12]	800,000			1,600,000
Southwestern Electric Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[7],[12]	6,400,000			14,600,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[12]	600,000			400,000
Southwestern Electric Power Co [Member] | FTRs [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		6,400,000			14,600,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		600,000			400,000
Southwestern Electric Power Co [Member] | FTRs [Member] | Level 3 [Member] | Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	(21.10)			(36.45)
Southwestern Electric Power Co [Member] | FTRs [Member] | Level 3 [Member] | High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	3.04			3.40
Southwestern Electric Power Co [Member] | FTRs [Member] | Level 3 [Member] | Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	(4.75)			(7.55)
Cash [Member] | Other [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents	[13]	0			0
Cash [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents	[13]	50,000,000			47,100,000
Other Short-term Investments	[14]	50,000,000			47,100,000
Cash [Member] | Level 1 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents	[13]	50,000,000			47,100,000
Cash [Member] | Level 2 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents	[13]	0			0
Cash [Member] | Level 3 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents	[13]	0			0
Other Cash Deposits [Member] | Other [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		11,400,000			9,000,000
Other Cash Deposits [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		11,400,000			9,000,000
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]	146,200,000			144,100,000
Mutual Funds Fixed Income [Member] | Level 1 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		146,200,000			144,100,000
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]	37,000,000			34,500,000
Mutual Funds Equity [Member] | Level 1 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[16]	37,000,000			34,500,000
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]	9,400,000			9,900,000
Cash and Cash Equivalents [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[17]	26,500,000			21,200,000
Cash and Cash Equivalents [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[17]	17,100,000			11,300,000
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]	9,400,000			9,900,000
Cash and Cash Equivalents [Member] | Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[17]	26,500,000			21,200,000
Cash and Cash Equivalents [Member] | Indiana Michigan Power Co [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[17]	17,100,000			11,300,000
Cash and Cash Equivalents [Member] | Indiana Michigan Power Co [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[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		1,207,600,000			1,123,800,000
US Government Agencies Debt Securities [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
US Government Agencies Debt Securities [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,207,600,000			1,123,800,000
US Government Agencies Debt Securities [Member] | Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
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		1,207,600,000			1,123,800,000
US Government Agencies Debt Securities [Member] | Indiana Michigan Power Co [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
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		1,207,600,000			1,123,800,000
US Government Agencies Debt Securities [Member] | Indiana Michigan Power Co [Member] | Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
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		66,000,000			61,600,000
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		66,000,000			61,600,000
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		66,000,000			61,600,000
Corporate Debt [Member] | Indiana Michigan Power Co [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Corporate Debt [Member] | Indiana Michigan Power Co [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		66,000,000			61,600,000
Corporate Debt [Member] | Indiana Michigan Power Co [Member] | Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
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		3,300,000			3,300,000
State and Local Jurisdiction [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
State and Local Jurisdiction [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		3,300,000			3,300,000
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		3,300,000			3,300,000
State and Local Jurisdiction [Member] | Indiana Michigan Power Co [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
State and Local Jurisdiction [Member] | Indiana Michigan Power Co [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		3,300,000			3,300,000
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		1,276,900,000			1,188,700,000
Fixed Income Funds [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Fixed Income Funds [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,276,900,000			1,188,700,000
Fixed Income Funds [Member] | Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
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		1,276,900,000			1,188,700,000
Fixed Income Funds [Member] | Indiana Michigan Power Co [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Fixed Income Funds [Member] | Indiana Michigan Power Co [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,276,900,000			1,188,700,000
Fixed Income Funds [Member] | Indiana Michigan Power Co [Member] | Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
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]	2,197,700,000			2,131,300,000
Domestic [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[16]	2,197,700,000			2,131,300,000
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]	2,197,700,000			2,131,300,000
Domestic [Member] | Indiana Michigan Power Co [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[16]	2,197,700,000			2,131,300,000
Domestic [Member] | Indiana Michigan Power Co [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[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]Included in revenues on the statements of income.[2]Represents the change in fair value between the beginning of the reporting period and the settlement of the risk management commodity contract.[3]Included in cash flow hedges on the statements of comprehensive income.[4]Represents existing assets or liabilities that were previously categorized as Level 2.[5]Transfers are recognized based on their value at the beginning of the reporting period that the transfer occurred.[6]Relates to the net gains (losses) of those contracts that are not reflected on the statements of income.  These changes in fair value are recorded as regulatory liabilities for net gains and as regulatory assets for net losses or accounts payable.[7]Amounts in “Other’’ column primarily represent counterparty netting of risk management and hedging contracts and associated cash collateral under the accounting guidance for “Derivatives and Hedging.’’[8]The March 31, 2023 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 2023 and $(6) million in periods 2024-2026; Level 2 matures $24 million in 2023, $105 million in periods 2024-2026, $9 million in periods 2027-2028 and $1 million in periods 2029-2033; Level 3 matures $18 million in 2023, $9 million in periods 2024-2026, $11 million in periods 2027-2028 and $(7) million in periods 2029-2033.  Risk management commodity contracts are substantially comprised of power contracts.[9]The December 31, 2022 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $(7) million in 2023; Level 2 matures $182 million in 2023, $134 million in periods 2024-2026, $10 million in periods 2027-2028 and $1 million in periods 2029-2033; Level 3 matures $128 million in 2023, $6 million in periods 2024-2026, $6 million in periods 2027-2028 and $(5) million in periods 2029-2033.  Risk management commodity contracts are substantially comprised of power contracts.[10]Represents market prices in dollars per MWh.[11]The weighted average is the product of the forward market price of the underlying commodity and volume weighted by term.[12]Substantially comprised of power contracts for the Registrant Subsidiaries.[13]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.[14]Primarily represents amounts held for the repayment of debt.[15]Primarily short and intermediate maturities which may be sold and do not contain maturity dates.[16]Amounts represent publicly traded equity securities and equity-based mutual funds.[17]Amounts in “Other’’ column primarily represent accrued interest receivables from financial institutions.  Level 1 amounts primarily represent investments in money market funds.

Income Taxes (Details)

Income Taxes (Details)	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21%	21%
State Income Tax, net of Federal Benefit	1.90%	1.50%
Tax Reform Excess ADIT Reversal	(6.20%)	(6.60%)
Production and Investment Tax Credits	(9.70%)	(8.00%)
Flow Through	0.10%	0.30%
AFUDC Equity	(1.40%)	(0.90%)
Discrete Tax Adjustments	(3.20%)	(0.60%)
Other	0.10%	0.20%
Effective Income Tax Rate	2.60%	6.90%
Income Taxes (Textuals) [Abstract]
corporate alternative minimum tax	15%
AEP Texas Inc. [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21%	21%
State Income Tax, net of Federal Benefit	0.30%	0.30%
Tax Reform Excess ADIT Reversal	(1.50%)	(2.00%)
Production and Investment Tax Credits	(0.20%)	(0.20%)
Flow Through	0.20%	0.30%
AFUDC Equity	(1.50%)	(0.90%)
Discrete Tax Adjustments	0%	0%
Other	0.10%	(0.10%)
Effective Income Tax Rate	18.40%	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	0.30%	0.30%
Production and Investment Tax Credits	0%	0%
Flow Through	0.30%	0.30%
AFUDC Equity	(1.60%)	(1.60%)
Discrete Tax Adjustments	0%	0%
Other	0.10%	0%
Effective Income Tax Rate	22.70%	22.60%
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%	2.90%
Tax Reform Excess ADIT Reversal	(4.60%)	(5.80%)
Production and Investment Tax Credits	0%	0%
Flow Through	0.60%	1.70%
AFUDC Equity	(0.70%)	(0.70%)
Discrete Tax Adjustments	3.20%	(0.60%)
Other	0%	0%
Effective Income Tax Rate	21.90%	18.50%
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	3.60%	1.60%
Tax Reform Excess ADIT Reversal	(7.90%)	(17.30%)
Production and Investment Tax Credits	(1.10%)	(1.40%)
Flow Through	(1.80%)	(1.90%)
AFUDC Equity	(0.50%)	(0.60%)
Discrete Tax Adjustments	1.80%	0%
Other	0%	(0.20%)
Effective Income Tax Rate	15.10%	1.20%
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%	0.70%
Tax Reform Excess ADIT Reversal	(6.80%)	(7.80%)
Production and Investment Tax Credits	0%	0%
Flow Through	0.50%	0.90%
AFUDC Equity	(0.80%)	(0.60%)
Discrete Tax Adjustments	0%	0%
Other	0%	0%
Effective Income Tax Rate	14.90%	14.20%
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	3.20%	0.60%
Tax Reform Excess ADIT Reversal	(18.70%)	(15.30%)
Production and Investment Tax Credits	(55.70%)	(26.20%)
Flow Through	0.30%	0.60%
AFUDC Equity	(1.40%)	(0.70%)
Discrete Tax Adjustments	0%	0%
Other	(2.00%)	(0.80%)
Effective Income Tax Rate	(53.30%)	(20.80%)
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	(0.40%)	2.30%
Tax Reform Excess ADIT Reversal	(3.80%)	(4.90%)
Production and Investment Tax Credits	(26.40%)	(23.10%)
Flow Through	0.50%	(0.60%)
AFUDC Equity	(0.80%)	(0.50%)
Discrete Tax Adjustments	0%	0%
Other	(0.80%)	0.60%
Effective Income Tax Rate	(10.70%)	(5.20%)

Financing Activities (Details)

Financing Activities (Details) - USD ($)			1 Months Ended	3 Months Ended
		Mar. 15, 2023	Apr. 30, 2023	Mar. 31, 2023		Mar. 31, 2022		Dec. 31, 2022
Long-term Debt
Senior Unsecured Notes				$ 32,654,300,000				$ 30,174,800,000
Pollution Control Bonds				1,770,400,000				1,770,200,000
Notes Payable				190,000,000				269,700,000
Securitization Bonds				463,400,000				487,800,000
Spent Nuclear Fuel Obligation	[1]			288,800,000				285,600,000
Junior Subordinated Notes	[2]			2,383,300,000				2,381,300,000
Other Long-term Debt				1,394,000,000				1,431,600,000
Total Long-term Debt Outstanding				39,144,200,000				36,801,000,000
Long-term Debt Due Within One Year				2,905,100,000				2,486,400,000
Long-term Debt				36,239,100,000				34,314,600,000
Liabilities Held for Sale				67,200,000				0
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]			2,876,000,000
Repayments of Long-term Debt				519,500,000		$ 51,000,000
Short-term Debt:
Securitized Debt for Receivables	[4]			750,000,000				750,000,000
Commercial Paper				1,981,100,000				2,862,200,000
Total Short-term Debt				$ 3,622,100,000				$ 4,112,200,000
Securitized Debt for Receivables	[4],[5]			5.05%				4.67%
Comparative Accounts Receivable Information
Effective Interest Rates on Securitization of Accounts Receivable				4.86%		0.31%
Net Uncollectible Accounts Receivable Written Off				$ 6,900,000		$ 7,400,000
Customer Accounts Receivable Managed Portfolio
Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts				1,091,800,000				$ 1,167,700,000
Total Principal Outstanding				750,000,000				750,000,000
Delinquent Securitized Accounts Receivable				49,300,000				44,200,000
Bad Debt Reserves Related to Securitization, Sale of Accounts Receivable				41,200,000				39,700,000
Unbilled Receivables Related to Securitization, Sale of Accounts Receivable				287,300,000				360,900,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				4,690,900,000		4,592,600,000
Financing Activities (Textuals)
Maximum Value of Shares to be Issued Under ATM Program				$ 1,000,000,000
Maximum Percentage Paid to Selling Agents				2%
Issuance of Common Stock				$ 41,100,000		809,500,000
Trust Fund Assets One Time Fee Obligation for Nuclear Fuel Disposition								330,000,000
Maximum Percentage Debt to Capitalization				67.50%
Total Commitment from Bank Conduits to Finance Receivables				$ 750,000,000
Forward Equity Purchase Contract Included in Current and Noncurrent Liabilities as of September 30,				12,500,000		16,700,000
Commitment from Bank Conduits to Finance Receivables				125,000,000
Commitment from Bank Conduits to Finance Receivables Two				625,000,000
Assets Held for Sale				1,396,300,000				$ 0
Issuance of Long-term Debt				2,847,300,000		499,600,000
Revenue from Related Parties				0		0
Wholesale Transmission [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				327,200,000	[6]	312,900,000	[7]
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				450,100,000	[6]	414,500,000	[7]
Financing Activities (Textuals)
Revenue from Related Parties				357,000,000		327,000,000
Other Revenues [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				65,300,000	[8]	119,100,000	[9]
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				3,600,000	[8]	(200,000)	[9]
Other Revenues [Member] | Corporate and Other
Financing Activities (Textuals)
Revenue from Related Parties				29,000,000
Wholesale Generation [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				215,200,000		227,500,000
Wholesale Generation [Member] | AEP Transmission Holdco [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				$ 0		0
2020 Equity Units [Member]
Financing Activities (Textuals)
Equity Units Issued				17,000,000
Per Unit Conversion for Equity Units				$ 50
Net Equity Units Issuance Proceeds				833,000,000
Principal Amounts of Junior Subordinated Debt				$ 1,000
Forward Equity Purchase Contract Date				2023
Equity Units Annual Distribution Rate				6.125%
Forward Equity Contract Payment Rate				4.825%
Maximum Shares Issued Under Equity Units Conversion				10,205,100
Corporate unit ownership share of an equity unit				5%
Junior Subordinated Debt [Member] | 2020 Equity Units [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt				$ 850,000,000
Interest Rate (Percentage)				1.30%
Senior Unsecured Notes [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]			$ 850,000,000
Due Date				2033
Interest Rate (Percentage)				5.63%
Commercial Paper [Member]
Short-term Debt:
Weighted Average Interest Rate	[5]			5.20%				4.80%
Term Loan [Member]
Short-term Debt:
Weighted Average Interest Rate	[5]			5.64%				5.17%
Term Loan				$ 125,000,000				$ 125,000,000
Term Loan 2 [Member]
Short-term Debt:
Weighted Average Interest Rate	[5]			5.63%				5.17%
Term Loan				$ 150,000,000				$ 150,000,000
Term Loan 3
Short-term Debt:
Weighted Average Interest Rate	[5]			5.67%				0%
Term Loan				$ 500,000,000				$ 0
Term Loan 4
Short-term Debt:
Weighted Average Interest Rate	[5]			5.64%				5.23%
Term Loan				$ 100,000,000				$ 100,000,000
Term Loan 5
Short-term Debt:
Weighted Average Interest Rate	[5]			0%				4.87%
Term Loan				$ 0				$ 125,000,000
AEP Texas Inc. [Member]
Long-term Debt
Total Long-term Debt Outstanding				5,522,000,000				5,657,800,000
Long-term Debt Due Within One Year				153,700,000				278,500,000
Long-term Debt				5,368,300,000				5,379,300,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt				$ 136,700,000		11,400,000
Financing Activities (Textuals)
Maximum Percentage Debt to Capitalization				67.50%
Revenue from Related Parties				$ 1,200,000		900,000
AEP Texas Inc. [Member] | Wholesale Transmission [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				146,300,000	[10]	133,100,000	[11]
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				9,700,000	[12]	9,300,000	[13]
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	[14]	$ 0	[15]
AEP Texas Inc. [Member] | Utility [Member]
Maximum Interest Rate				5.42%		1%
Minimum Interest Rate				4.66%		0.10%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool				$ 453,700,000
Maximum Loans to Money Pool				0
Average Borrowings from Money Pool				285,300,000
Average Loans to Money Pool				0
Net Loans (Borrowings) to/from Money Pool				(450,800,000)
Authorized Short Term Borrowing Limit				$ 500,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed				5.18%		0.70%
Average Interest Rate For Funds Loaned				0%		0%
AEP Texas Inc. [Member] | Nonutility [Member]
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Loans to Money Pool				$ 6,900,000
Average Loans to Money Pool				6,800,000
Net Loans (Borrowings) to/from Money Pool				$ 6,800,000
Maximum and Minimum Interest Rates
Maximum Interest Rate For Funds Loaned				5.42%		1%
Minimum Interest Rate for Funds Loaned				4.66%		0.46%
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Loaned				5.12%		0.62%
AEP Texas Inc. [Member] | Securitization Bonds [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt				$ 11,700,000
Due Date				2025
Interest Rate (Percentage)				2.06%
AEP Texas Inc. [Member] | Senior Unsecured Notes Six
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt				$ 125,000,000
Due Date				2023
Interest Rate (Percentage)				3.09%
AEP Transmission Co [Member]
Long-term Debt
Total Long-term Debt Outstanding				$ 5,472,100,000				4,782,800,000
Long-term Debt Due Within One Year				60,000,000				60,000,000
Long-term Debt				5,412,100,000				4,722,800,000
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%
Maximum Percentage Debt to Capitalization				67.50%
Issuance of Long-term Debt				$ 689,200,000		$ 0
Revenue from Related Parties				357,400,000		325,000,000
AEP Transmission Co [Member] | Wholesale Transmission [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				438,700,000	[10]	400,300,000	[11]
Financing Activities (Textuals)
Revenue from Related Parties				349,000,000		323,000,000
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				3,700,000	[12]	(300,000)	[13]
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	[14]	$ 0	[15]
AEP Transmission Co [Member] | Utility [Member]
Maximum Interest Rate				5.42%		1%
Minimum Interest Rate				4.66%		0.10%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool				$ 471,300,000
Maximum Loans to Money Pool				309,400,000
Average Borrowings from Money Pool				272,900,000
Average Loans to Money Pool				45,700,000
Net Loans (Borrowings) to/from Money Pool				260,500,000
Authorized Short Term Borrowing Limit	[16]			$ 820,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed				5.09%		0.66%
Average Interest Rate For Funds Loaned				5.29%		0.60%
AEP Transmission Co [Member] | Direct Borrowing [Member]
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool				$ 29,400,000
Maximum Loans to Money Pool				158,100,000
Average Borrowings from Money Pool				3,100,000
Average Loans to Money Pool				80,200,000
Borrowings from Parent				1,600,000
Loans to Parent				34,200,000
Authorized Short Term Borrowing Limit	[17]			$ 50,000,000
Maximum and Minimum Interest Rates
Maximum Interest Rate for Funds Borrowed				5.38%		1%
Minimum Interest Rate For Funds Borrowed				4.53%		0.46%
Maximum Interest Rate For Funds Loaned				5.38%		1%
Minimum Interest Rate for Funds Loaned				4.53%		0.46%
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed				5.03%		0.66%
Average Interest Rate For Funds Loaned				5.15%		0.60%
AEP Transmission Co [Member] | Senior Unsecured Notes Two [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]			$ 700,000,000
Due Date				2053
Interest Rate (Percentage)				5.40%
Appalachian Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding				$ 5,398,700,000				5,410,500,000
Long-term Debt Due Within One Year				252,300,000				251,800,000
Long-term Debt				5,146,400,000				5,158,700,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt				13,000,000		$ 12,700,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues				195,500,000				194,400,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit				$ 506,200,000		415,500,000
Financing Activities (Textuals)
Maximum Percentage Debt to Capitalization				67.50%
Revenue from Related Parties				$ 69,600,000		56,900,000
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				41,400,000	[10]	41,100,000	[11]
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				13,000,000	[12]	24,300,000	[13]
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				80,200,000	[14]	56,200,000	[15]
Financing Activities (Textuals)
Revenue from Related Parties				47,000,000		36,000,000
Appalachian Power Co [Member] | Servicing Contracts [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				$ 4,900,000		$ 1,300,000
Appalachian Power Co [Member] | Utility [Member]
Maximum Interest Rate				5.42%		1%
Minimum Interest Rate				4.66%		0.10%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool				$ 373,600,000
Maximum Loans to Money Pool				19,800,000
Average Borrowings from Money Pool				285,300,000
Average Loans to Money Pool				18,900,000
Net Loans (Borrowings) to/from Money Pool				(291,500,000)
Authorized Short Term Borrowing Limit				$ 500,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed				5.14%		0.55%
Average Interest Rate For Funds Loaned				5.12%		0.62%
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				$ 9,700,000
Due Date				2023
Interest Rate (Percentage)				2.01%
Appalachian Power Co [Member] | Securitization Bonds Three
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt				$ 3,300,000
Due Date				2028
Interest Rate (Percentage)				3.77%
Indiana Michigan Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding				$ 3,489,000,000				3,260,800,000
Long-term Debt Due Within One Year				86,000,000				341,800,000
Long-term Debt				3,403,000,000				2,919,000,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt				274,300,000		$ 23,800,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues				167,900,000				166,900,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit				525,400,000		513,400,000
Financing Activities (Textuals)
Trust Fund Assets One Time Fee Obligation for Nuclear Fuel Disposition				$ 335,000,000				330,000,000
Maximum Percentage Debt to Capitalization				67.50%
Issuance of Long-term Debt				$ 499,800,000		0
Revenue from Related Parties				1,200,000		2,000,000
Indiana Michigan Power Co [Member] | Wholesale Transmission [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				8,100,000	[10]	8,800,000	[11]
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				21,400,000	[12]	29,900,000	[13]
Financing Activities (Textuals)
Revenue from Related Parties				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				104,000,000	[14]	90,400,000	[15]
Indiana Michigan Power Co [Member] | Servicing Contracts [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				$ 3,900,000		$ 1,700,000
Indiana Michigan Power Co [Member] | Utility [Member]
Maximum Interest Rate				5.42%		1%
Minimum Interest Rate				4.66%		0.10%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool				$ 475,300,000
Maximum Loans to Money Pool				82,900,000
Average Borrowings from Money Pool				212,500,000
Average Loans to Money Pool				28,100,000
Net Loans (Borrowings) to/from Money Pool				60,000,000
Authorized Short Term Borrowing Limit				$ 500,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed				5.12%		0.63%
Average Interest Rate For Funds Loaned				5.16%		0.62%
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				$ 3,900,000
Due Date				2025
Interest Rate (Percentage)				0.93%
Indiana Michigan Power Co [Member] | Notes Payable, Other Payable Five [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt				$ 6,800,000
Due Date				2026
Interest Rate (Percentage)				3.44%
Indiana Michigan Power Co [Member] | Notes Payable, Other Payable Six [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt				$ 6,700,000
Due Date				2027
Interest Rate (Percentage)				5.93%
Indiana Michigan 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				$ 500,000
Due Date				2025
Interest Rate (Percentage)				6%
Indiana Michigan Power Co [Member] | Senior Unsecured Notes Three
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]			$ 500,000,000
Due Date				2053
Interest Rate (Percentage)				5.63%
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				$ 600,000
Due Date				2023
Interest Rate (Variable)				Variable
Indiana Michigan Power Co [Member] | Senior Unsecured Notes Seven
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt				$ 250,000,000
Due Date				2023
Interest Rate (Percentage)				3.20%
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				$ 1,200,000
Due Date				2024
Interest Rate (Variable)				Variable
Indiana Michigan Power Co [Member] | Notes Payable, Other Payables [Member] | Subsequent Event [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 8,000,000
Indiana Michigan Power Co [Member] | Notes Payable, Other Payable Three [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt				$ 4,600,000
Due Date				2025
Interest Rate (Variable)				Variable
Ohio Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding				$ 2,970,800,000				2,970,300,000
Long-term Debt Due Within One Year				100,000				100,000
Long-term Debt				2,970,700,000				2,970,200,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues				457,500,000				478,600,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit				884,400,000		$ 716,600,000
Financing Activities (Textuals)
Revenue from Related Parties				7,600,000		3,700,000
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				17,900,000	[10]	21,800,000	[11]
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				33,200,000	[12]	44,600,000	[13]
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	[14]	0	[15]
Ohio Power Co [Member] | Servicing Contracts [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				$ 7,300,000		$ 7,400,000
Ohio Power Co [Member] | Utility [Member]
Maximum Interest Rate				5.42%		1%
Minimum Interest Rate				4.66%		0.10%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool				$ 483,000,000
Maximum Loans to Money Pool				0
Average Borrowings from Money Pool				292,600,000
Average Loans to Money Pool				0
Net Loans (Borrowings) to/from Money Pool				(414,600,000)
Authorized Short Term Borrowing Limit				$ 500,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed				5.17%		0.77%
Average Interest Rate For Funds Loaned				0%		0.48%
Public Service Co Of Oklahoma [Member]
Long-term Debt
Total Long-term Debt Outstanding				$ 2,383,600,000				1,912,800,000
Long-term Debt Due Within One Year				500,000				500,000
Long-term Debt				2,383,100,000				1,912,300,000
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				134,200,000				155,500,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit				$ 416,300,000		363,400,000
Financing Activities (Textuals)
Maximum Percentage Debt to Capitalization				67.50%
Issuance of Long-term Debt				$ 469,900,000		500,000,000
Revenue from Related Parties				700,000		600,000
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				11,300,000	[10]	9,600,000	[11]
Public Service Co Of Oklahoma [Member] | Other Revenues [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				2,300,000	[12]	5,400,000	[13]
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				900,000	[14]	9,500,000	[15]
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				$ 3,200,000		$ 900,000
Public Service Co Of Oklahoma [Member] | Utility [Member]
Maximum Interest Rate				5.42%		1%
Minimum Interest Rate				4.66%		0.10%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool				$ 375,000,000
Maximum Loans to Money Pool				121,500,000
Average Borrowings from Money Pool				321,700,000
Average Loans to Money Pool				74,800,000
Net Loans (Borrowings) to/from Money Pool				(130,700,000)
Authorized Short Term Borrowing Limit				$ 400,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed				4.84%		0.69%
Average Interest Rate For Funds Loaned				5.11%		0.65%
Public Service Co Of Oklahoma [Member] | OtherLongTermDebtThree
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%
Public Service Co Of Oklahoma [Member] | Senior Unsecured Notes Four
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]			$ 475,000,000
Due Date				2033
Interest Rate (Percentage)				5.25%
Southwestern Electric Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding				$ 3,644,800,000				3,391,600,000
Long-term Debt Due Within One Year				0				6,200,000
Long-term Debt				3,644,800,000				3,385,400,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt				94,100,000		$ 1,600,000
Short-term Debt:
Notes Payable				16,000,000				0
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues				157,800,000				$ 194,000,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit				$ 437,600,000		394,500,000
Financing Activities (Textuals)
Maximum Percentage Debt to Capitalization				67.50%
Issuance of Long-term Debt				$ 347,300,000		0
Revenue from Related Parties				11,700,000		10,000,000
Southwestern Electric Power Co [Member] | Wholesale Transmission [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				42,900,000	[10]	35,200,000	[11]
Southwestern Electric Power Co [Member] | Other Revenues [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold				7,900,000	[12]	5,300,000	[13]
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				39,600,000	[14]	61,200,000	[15]
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				$ 4,300,000		$ 1,300,000
Southwestern Electric Power Co [Member] | Utility [Member]
Maximum Interest Rate				5.42%		1%
Minimum Interest Rate				4.66%		0.10%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool	[18]			$ 401,600,000
Maximum Loans to Money Pool				0
Average Borrowings from Money Pool				353,900,000
Average Loans to Money Pool				0
Net Loans (Borrowings) to/from Money Pool				(18,800,000)
Authorized Short Term Borrowing Limit				$ 400,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed				5.12%		0.98%
Average Interest Rate For Funds Loaned				0%		0.55%
Financing Activities (Textuals)
Amount Exceeding Maximum Borrowings from Money Pool		$ 1,600,000
Southwestern Electric Power Co [Member] | Nonutility [Member]
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Loans to Money Pool				$ 2,100,000
Average Loans to Money Pool				2,100,000
Net Loans (Borrowings) to/from Money Pool				$ 2,100,000
Maximum and Minimum Interest Rates
Maximum Interest Rate For Funds Loaned				5.42%		1%
Minimum Interest Rate for Funds Loaned				4.66%		0.46%
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Loaned				5.13%		0.62%
Southwestern Electric Power Co [Member] | Notes Payable, Other Payable Seven [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt				$ 25,000,000
Due Date				2024
Interest Rate (Percentage)				6.37%
Southwestern Electric Power Co [Member] | Notes Payable, Other Payable Eight [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt				$ 30,900,000
Due Date				2032
Interest Rate (Percentage)				4.58%
Southwestern Electric Power Co [Member] | OtherLongTermDebtFour
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt				$ 38,200,000
Due Date				2028
Interest Rate (Percentage)				4.68%
Southwestern Electric Power Co [Member] | Senior Unsecured Notes Five
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]			$ 350,000,000
Due Date				2033
Interest Rate (Percentage)				5.30%
Southwestern Electric Power Co [Member] | Loans Payable [Member]
Short-term Debt:
Weighted Average Interest Rate	[5]			7.27%				0%
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	[3]			$ 1,000,000
Due Date				2025
Interest Rate (Variable)				Variable
Transource Energy [Member] | Senior Unsecured Notes Eight
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt				$ 1,300,000
Due Date				2050
Interest Rate (Percentage)				2.75%
Maximum [Member] | 2020 Equity Units [Member]
Financing Activities (Textuals)
AEP Share Price for Equity Unit Conversion				$ 99.95
Shares Per Equity Unit				0.5003
Minimum [Member] | 2020 Equity Units [Member]
Financing Activities (Textuals)
AEP Share Price for Equity Unit Conversion				$ 83.29
Shares Per Equity Unit				0.6003
Additional Paid-in Capital [Member]
Financing Activities (Textuals)
Forward Equity Purchase Contract Included in Current and Noncurrent Liabilities as of September 30,				$ 12,700,000		$ 15,200,000
Additional Paid-in Capital [Member] | 2020 Equity Units [Member]
Financing Activities (Textuals)
Forward Equity Purchase Contract Included in Current and Noncurrent Liabilities as of September 30,				$ 121,000,000
[1]Pursuant to the Nuclear Waste Policy Act of 1982, I&M, a nuclear licensee, has an obligation to the United States Department of Energy for SNF disposal. The obligation includes a one-time fee for nuclear fuel consumed prior to April 7, 1983. Trust fund assets related to this obligation were $335 million and $330 million as of March 31, 2023 and December 31, 2022, respectively, and are included in Spent Nuclear Fuel and Decommissioning Trusts on the balance sheets.[2]See “Equity Units” section below for additional information.[3]Amounts indicated on the statements of cash flows are net of issuance costs and premium or discount and will not tie to the issuance amounts.[4]Amount of securitized debt for receivables as accounted for under the “Transfers and Servicing” accounting guidance.[5]Weighted-average rate as of March 31, 2023 and December 31, 2022, respectively.[6]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $357 million. The remaining affiliated amounts were immaterial.[7]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $327 million. The remaining affiliated amounts were immaterial.[8]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $29 million. The remaining affiliated amounts were immaterial.[9]Amounts include affiliated and nonaffiliated revenues[10]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $349 million. The remaining affiliated amounts were immaterial.[11]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $323 million. The remaining affiliated amounts were immaterial.[12]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.[13]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $10 million primarily related to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial.[14]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $47 million primarily related to the PPA with KGPCo.[15]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $36 million primarily related to the PPA with KGPCo.[16](a)    Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions.[17](a)    Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions.[18]SWEPCo’s maximum borrowings from the Utility Money Pool exceeded the authorized short-term borrowing limit by $1.6 million on March 15, 2023. On March 16, 2023, SWEPCo’s borrowings from the Utility Money Pool were reduced below the $400 million authorized limit and borrowings have continued to remain below the authorized limit.

Variable Interest Entities (Det

Variable Interest Entities (Details) - USD ($) $ in Millions	Mar. 31, 2023		Dec. 31, 2022		Mar. 31, 2022	Dec. 31, 2021
ASSETS
Current Assets	$ 7,798.2		$ 6,775.5
Net Property, Plant and Equipment	73,347		73,339.1
Other Noncurrent Assets	13,372.7		13,288.7
Total Assets	94,517.9	[1]	93,403.3
LIABILITIES AND EQUITY
Current Liabilities	12,621.7		13,266.3
Noncurrent Liabilities	57,871.8		55,968.7
Equity	23,967.8		24,122.4		$ 24,038.1	$ 22,680.2
Total Liabilities and Equity	94,517.9		93,403.3
Southwestern Electric Power Co [Member]
ASSETS
Current Assets	678.5		812.2
Net Property, Plant and Equipment	8,342.6		8,262.2
Other Noncurrent Assets	1,375.5		1,304.4
Total Assets	10,396.6		10,378.8
LIABILITIES AND EQUITY
Current Liabilities	662.4		947.7
Noncurrent Liabilities	5,969		5,756.3
Equity	3,765.2		3,674.8		3,543.8	3,149.8
Total Liabilities and Equity	10,396.6		10,378.8
Indiana Michigan Power Co [Member]
ASSETS
Current Assets	571.4		571.8
Net Property, Plant and Equipment	7,416.9		7,411.5
Other Noncurrent Assets	4,254		4,135.6
Total Assets	12,242.3		12,118.9
LIABILITIES AND EQUITY
Current Liabilities	634.8		1,197.1
Noncurrent Liabilities	8,530.2		7,913.5
Equity	3,077.3		3,008.3		2,849.5	2,784.7
Total Liabilities and Equity	12,242.3		12,118.9
AEP Texas Inc. [Member]
ASSETS
Current Assets	429.1		446.9
Net Property, Plant and Equipment	12,008		11,681.6
Other Noncurrent Assets	835.1		763.7
Total Assets	13,272.2		12,892.2
LIABILITIES AND EQUITY
Current Liabilities	1,280.1		1,043.8
Noncurrent Liabilities	7,940.8		7,944.1
Equity	4,051.3		3,904.3		3,664.1	3,594.2
Total Liabilities and Equity	13,272.2		12,892.2
Appalachian Power Co [Member]
ASSETS
Current Assets	1,299		1,259.6
Net Property, Plant and Equipment	12,506.1		12,379.2
Other Noncurrent Assets	1,451.3		1,583.4
Total Assets	15,256.4		15,222.2
LIABILITIES AND EQUITY
Current Liabilities	1,350.1		1,390.2
Noncurrent Liabilities	8,819.4		8,856.6
Equity	5,086.9		4,975.4		$ 4,748	$ 4,647.9
Total Liabilities and Equity	15,256.4		15,222.2
Sabine Mining Co [Member] | Variable Interest Entities [Member] | Southwestern Electric Power Co [Member]
ASSETS
Current Assets	23		108.3
Net Property, Plant and Equipment	0		7.2
Other Noncurrent Assets	135.1		130
Total Assets	158.1		245.5
LIABILITIES AND EQUITY
Current Liabilities	33.5		25.4
Noncurrent Liabilities	124.2		219.4
Equity	0.4		0.7
Total Liabilities and Equity	158.1		245.5
DCC Fuel [Member] | Variable Interest Entities [Member] | Indiana Michigan Power Co [Member]
ASSETS
Current Assets	84.3		90.2
Net Property, Plant and Equipment	154.3		179.1
Other Noncurrent Assets	76		94
Total Assets	314.6		363.3
LIABILITIES AND EQUITY
Current Liabilities	84.2		90
Noncurrent Liabilities	230.4		273.3
Equity	0		0
Total Liabilities and Equity	314.6		363.3
AEP Texas Central Transition Funding Co [Member] | AEP Texas Inc. [Member] | Other Noncurrent Assets [Member]
LIABILITIES AND EQUITY
Unearned Revenue	14		16
AEP Texas Central Transition Funding Co [Member] | Variable Interest Entities [Member] | AEP Texas Inc. [Member]
ASSETS
Current Assets	43		27
Net Property, Plant and Equipment	0		0
Other Noncurrent Assets	125.2	[2]	140.9	[3]
Total Assets	168.2		167.9
LIABILITIES AND EQUITY
Current Liabilities	74.3		73.2
Noncurrent Liabilities	89.6		90.4
Equity	4.3		4.3
Total Liabilities and Equity	168.2		167.9
Restoration Funding [Member] | AEP Texas Inc. [Member] | Other Noncurrent Assets [Member]
LIABILITIES AND EQUITY
Unearned Revenue	7		7
Restoration Funding [Member] | Variable Interest Entities [Member] | AEP Texas Inc. [Member]
ASSETS
Current Assets	13.4		21.1
Net Property, Plant and Equipment	0		0
Other Noncurrent Assets	163	[4]	168.8	[5]
Total Assets	176.4		189.9
LIABILITIES AND EQUITY
Current Liabilities	30.5		31.3
Noncurrent Liabilities	144.7		157.4
Equity	1.2		1.2
Total Liabilities and Equity	176.4		189.9
Appalachian Consumer Rate Relief Funding [Member] | Appalachian Power Co [Member] | Other Noncurrent Assets [Member]
LIABILITIES AND EQUITY
Unearned Revenue	2		2
Appalachian Consumer Rate Relief Funding [Member] | Variable Interest Entities [Member] | Appalachian Power Co [Member]
ASSETS
Current Assets	6.1		13.5
Net Property, Plant and Equipment	0		0
Other Noncurrent Assets	157.4	[6]	164.6	[7]
Total Assets	163.5		178.1
LIABILITIES AND EQUITY
Current Liabilities	28.1		29.3
Noncurrent Liabilities	133.5		146.9
Equity	1.9		1.9
Total Liabilities and Equity	163.5		178.1
AEP Credit, Inc. [Member] | Variable Interest Entities [Member]
ASSETS
Current Assets	1,092.6		1,181
Net Property, Plant and Equipment	0		0
Other Noncurrent Assets	8.9		9
Total Assets	1,101.5		1,190
LIABILITIES AND EQUITY
Current Liabilities	1,043.2		1,087.8
Noncurrent Liabilities	0.9		0.9
Equity	57.4		101.3
Total Liabilities and Equity	1,101.5		1,190
Protected Cell Of Energy Insurance Services, Inc. [Member] | Variable Interest Entities [Member]
ASSETS
Current Assets	203.2		194.5
Net Property, Plant and Equipment	0		0
Other Noncurrent Assets	0		0.3
Total Assets	203.2		194.8
LIABILITIES AND EQUITY
Current Liabilities	50.2		46.4
Noncurrent Liabilities	78		79.1
Equity	75		69.3
Total Liabilities and Equity	203.2		194.8
Transource Energy [Member] | Variable Interest Entities [Member]
ASSETS
Current Assets	22.1		23.5
Net Property, Plant and Equipment	495.1		482.3
Other Noncurrent Assets	6.8		2.7
Total Assets	524		508.5
LIABILITIES AND EQUITY
Current Liabilities	33.4		22.8
Noncurrent Liabilities	219		218.6
Equity	271.6		267.1
Total Liabilities and Equity	$ 524		508.5
Apple Blossom and Black Oak [Member] | Variable Interest Entities [Member]
ASSETS
Current Assets			8.3
Net Property, Plant and Equipment			216.5
Other Noncurrent Assets			13.6
Total Assets			238.4
LIABILITIES AND EQUITY
Current Liabilities			4.5
Noncurrent Liabilities			5.4
Equity			228.5
Total Liabilities and Equity			238.4
Santa Rita East [Member] | Variable Interest Entities [Member]
ASSETS
Current Assets			21.3
Net Property, Plant and Equipment			421.6
Other Noncurrent Assets			0.1
Total Assets			443
LIABILITIES AND EQUITY
Current Liabilities			9.6
Noncurrent Liabilities			7.3
Equity			426.1
Total Liabilities and Equity			443
Dry Lake Solar Project [Member] | Variable Interest Entities [Member]
ASSETS
Current Assets			4
Net Property, Plant and Equipment			142.6
Other Noncurrent Assets			0.3
Total Assets			146.9
LIABILITIES AND EQUITY
Current Liabilities			1
Noncurrent Liabilities			0.7
Equity			145.2
Total Liabilities and Equity			$ 146.9
[1]Amount includes Assets Held for Sale on the balance sheet. See “Planned Disposition of the Competitive Contracted Renewables Portfolio” section of Note 6 for additional information.[2]Includes an intercompany item eliminated in consolidation of $14 million.[3] Includes an intercompany item eliminated in consolidation of $16 million . Includes an intercompany item eliminated in consolidation of $7 million . Includes an intercompany item eliminated in consolidation of $7 million . Includes an intercompany item eliminated in consolidation of $2 million . Includes an intercompany item eliminated in consolidation of $2 million

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Details) - USD ($)		3 Months Ended
		Mar. 31, 2023		Mar. 31, 2022		Dec. 31, 2022
Disaggregation of Revenue
Revenue from Contracts with Customers		$ 4,690,900,000		$ 4,592,600,000
Revenues		4,690,900,000		4,592,600,000
Revenue, Performance Obligation
Fixed Performance Obligations		422,000,000
Revenue Textuals
Revenue from Related Parties		0		0
Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		3,788,400,000		3,368,900,000
Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,827,200,000		1,751,400,000
Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,009,300,000		862,600,000
Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		883,000,000		695,900,000
Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		68,900,000		59,000,000
Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		977,100,000		945,000,000
Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		215,200,000		227,500,000
Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		327,200,000	[1]	312,900,000	[2]
Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		21,200,000	[3]	21,600,000	[4]
Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		413,500,000	[3]	383,000,000	[5]
Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		65,300,000	[6]	119,100,000	[4]
Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		4,830,800,000		4,433,000,000
Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(139,900,000)		159,600,000
Alternative [Member]
Disaggregation of Revenue
Revenues		(10,000,000)	[7]	(5,800,000)	[8]
Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		92,400,000		94,100,000
Revenues		(129,900,000)	[3]	165,400,000	[4],[9]
2023 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		63,400,000
2024-2025[Member]
Revenue, Performance Obligation
Fixed Performance Obligations		160,500,000
2026-2027 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		137,100,000
After 2027
Revenue, Performance Obligation
Fixed Performance Obligations		61,000,000
AEP Texas Inc. [Member]
Disaggregation of Revenue
Revenues		429,500,000		416,700,000
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		13,500,000				$ 11,900,000
Revenue Textuals
Revenue from Related Parties		1,200,000		900,000
AEP Texas Inc. [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		275,600,000		275,600,000
AEP Texas Inc. [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		130,700,000		141,900,000
AEP Texas Inc. [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		97,300,000		94,900,000
AEP Texas Inc. [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		39,300,000		30,600,000
AEP Texas Inc. [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		8,300,000		8,200,000
AEP Texas Inc. [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		146,300,000		133,100,000
AEP Texas Inc. [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[10]	0	[11]
AEP Texas Inc. [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		146,300,000	[12]	133,100,000	[13]
AEP Texas Inc. [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		9,700,000	[14]	9,300,000	[15]
AEP Texas Inc. [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		431,600,000		418,000,000
AEP Texas Inc. [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(2,100,000)		(1,300,000)
AEP Texas Inc. [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		(2,100,000)	[16]	(1,300,000)	[17]
AEP Texas Inc. [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		600,000		1,100,000
Revenues		0	[18]	0	[19]
AEP Texas Inc. [Member] | Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		0				100,000
AEP Transmission Co [Member]
Disaggregation of Revenue
Revenues		441,600,000		400,400,000
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		127,000,000				119,500,000
Revenue Textuals
Revenue from Related Parties		357,400,000		325,000,000
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		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		438,700,000		400,300,000
AEP Transmission Co [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[10]	0	[11]
AEP Transmission Co [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		438,700,000	[12]	400,300,000	[13]
Revenue Textuals
Revenue from Related Parties		349,000,000		323,000,000
AEP Transmission Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		3,700,000	[14]	(300,000)	[15]
AEP Transmission Co [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		442,400,000		400,000,000
AEP Transmission Co [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(800,000)		400,000
AEP Transmission Co [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		(800,000)	[16]	400,000	[17]
AEP Transmission Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenues		0	[18]	0	[19]
AEP Transmission Co [Member] | Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		122,500,000				113,800,000
Appalachian Power Co [Member]
Disaggregation of Revenue
Revenues		987,700,000		907,300,000
Revenue, Performance Obligation
Fixed Performance Obligations		80,300,000
Affiliated Companies - Contracts with Customers		91,500,000				94,000,000
Revenue Textuals
Revenue from Related Parties		69,600,000		56,900,000
Appalachian Power Co [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		853,800,000		786,300,000
Appalachian Power Co [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		470,500,000		458,000,000
Appalachian Power Co [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		171,300,000		153,900,000
Appalachian Power Co [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		185,800,000		153,800,000
Appalachian Power Co [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		26,200,000		20,600,000
Appalachian Power Co [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		121,600,000		97,300,000
Appalachian Power Co [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		80,200,000	[10]	56,200,000	[11]
Revenue Textuals
Revenue from Related Parties		47,000,000		36,000,000
Appalachian Power Co [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		41,400,000	[12]	41,100,000	[13]
Appalachian Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		13,000,000	[14]	24,300,000	[15]
Appalachian Power Co [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		988,400,000		907,900,000
Appalachian Power Co [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(700,000)		(600,000)
Appalachian Power Co [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		(700,000)	[16]	(700,000)	[17]
Appalachian Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		3,600,000		3,300,000
Revenues		0	[18]	100,000	[19]
Appalachian Power Co [Member] | Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		65,100,000				64,500,000
Appalachian Power Co [Member] | 2023 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		12,100,000
Appalachian Power Co [Member] | 2024-2025[Member]
Revenue, Performance Obligation
Fixed Performance Obligations		32,200,000
Appalachian Power Co [Member] | 2026-2027 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		24,300,000
Appalachian Power Co [Member] | After 2027
Revenue, Performance Obligation
Fixed Performance Obligations		11,700,000
Indiana Michigan Power Co [Member]
Disaggregation of Revenue
Revenues		663,000,000		625,200,000
Revenue, Performance Obligation
Fixed Performance Obligations		26,400,000
Affiliated Companies - Contracts with Customers		86,600,000				104,000,000
Revenue Textuals
Revenue from Related Parties		1,200,000		2,000,000
Indiana Michigan Power Co [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		532,400,000		496,200,000
Indiana Michigan Power Co [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		239,600,000		231,800,000
Indiana Michigan Power Co [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		138,900,000		126,600,000
Indiana Michigan Power Co [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		152,600,000		136,500,000
Indiana Michigan Power Co [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,300,000		1,300,000
Indiana Michigan Power Co [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		112,100,000		99,200,000
Indiana Michigan Power Co [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		104,000,000	[10]	90,400,000	[11]
Indiana Michigan Power Co [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		8,100,000	[12]	8,800,000	[13]
Indiana Michigan Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		21,400,000	[14]	29,900,000	[15]
Revenue Textuals
Revenue from Related Parties		18,000,000
Indiana Michigan Power Co [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		665,900,000		625,300,000
Indiana Michigan Power Co [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(2,900,000)		(100,000)
Indiana Michigan Power Co [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		(2,900,000)	[16]	0	[17]
Indiana Michigan Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		3,100,000		2,800,000
Revenues		0	[18]	(100,000)	[19]
Revenue Textuals
Revenue from Related Parties				10,000,000
Indiana Michigan Power Co [Member] | Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		56,400,000				75,300,000
Indiana Michigan Power Co [Member] | 2023 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		3,400,000
Indiana Michigan Power Co [Member] | 2024-2025[Member]
Revenue, Performance Obligation
Fixed Performance Obligations		9,200,000
Indiana Michigan Power Co [Member] | 2026-2027 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		9,200,000
Indiana Michigan Power Co [Member] | After 2027
Revenue, Performance Obligation
Fixed Performance Obligations		4,600,000
Ohio Power Co [Member]
Disaggregation of Revenue
Revenues		1,034,600,000		830,000,000
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		113,900,000				100,900,000
Revenue Textuals
Revenue from Related Parties		7,600,000		3,700,000
Ohio Power Co [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		981,900,000		759,400,000
Ohio Power Co [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		526,000,000		458,700,000
Ohio Power Co [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		278,500,000		194,700,000
Ohio Power Co [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		173,600,000		102,700,000
Ohio Power Co [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		3,800,000		3,300,000
Ohio Power Co [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		17,900,000		21,800,000
Ohio Power Co [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[10]	0	[11]
Ohio Power Co [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		17,900,000	[12]	21,800,000	[13]
Ohio Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		33,200,000	[14]	44,600,000	[15]
Ohio Power Co [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,033,000,000		825,800,000
Ohio Power Co [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		1,600,000		4,200,000
Ohio Power Co [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		(9,500,000)	[16]	(2,100,000)	[17]
Ohio Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		5,200,000		2,100,000
Revenues		11,100,000	[18]	6,300,000	[19]
Ohio Power Co [Member] | Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		57,500,000				49,900,000
Public Service Co Of Oklahoma [Member]
Disaggregation of Revenue
Revenues		417,000,000		387,600,000
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		33,500,000				52,200,000
Revenue Textuals
Revenue from Related Parties		700,000		600,000
Public Service Co Of Oklahoma [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		402,500,000		363,200,000
Public Service Co Of Oklahoma [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		170,900,000		165,900,000
Public Service Co Of Oklahoma [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		109,100,000		97,500,000
Public Service Co Of Oklahoma [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		98,300,000		78,600,000
Public Service Co Of Oklahoma [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		24,200,000		21,200,000
Public Service Co Of Oklahoma [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		12,200,000		19,100,000
Public Service Co Of Oklahoma [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		900,000	[10]	9,500,000	[11]
Public Service Co Of Oklahoma [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		11,300,000	[12]	9,600,000	[13]
Public Service Co Of Oklahoma [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,300,000	[14]	5,400,000	[15]
Public Service Co Of Oklahoma [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		417,000,000		387,700,000
Public Service Co Of Oklahoma [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		0		(100,000)
Public Service Co Of Oklahoma [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		0	[16]	(100,000)	[17]
Public Service Co Of Oklahoma [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,500,000		600,000
Revenues		0	[18]	0	[19]
Public Service Co Of Oklahoma [Member] | Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		12,700,000				18,800,000
Southwestern Electric Power Co [Member]
Disaggregation of Revenue
Revenues		515,900,000		494,800,000
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		38,900,000				65,400,000
Revenue Textuals
Revenue from Related Parties		11,700,000		10,000,000
Southwestern Electric Power Co [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		426,200,000		393,500,000
Southwestern Electric Power Co [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		175,900,000		175,900,000
Southwestern Electric Power Co [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		143,500,000		130,500,000
Southwestern Electric Power Co [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		104,200,000		84,700,000
Southwestern Electric Power Co [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,600,000		2,400,000
Southwestern Electric Power Co [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		82,500,000		96,400,000
Southwestern Electric Power Co [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		39,600,000	[10]	61,200,000	[11]
Southwestern Electric Power Co [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		42,900,000	[12]	35,200,000	[13]
Southwestern Electric Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		7,900,000	[14]	5,300,000	[15]
Southwestern Electric Power Co [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		516,600,000		495,200,000
Southwestern Electric Power Co [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(700,000)		(400,000)
Southwestern Electric Power Co [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		(700,000)	[16]	(400,000)	[17]
Southwestern Electric Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		500,000		600,000
Revenues		0	[18]	0	[19]
Southwestern Electric Power Co [Member] | Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		19,600,000				$ 19,100,000
Consolidation Eliminations [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Revenues		(443,700,000)		(392,200,000)
Revenue Textuals
Revenue from Related Parties		(443,700,000)		(392,200,000)
Consolidation Eliminations [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(200,000)		(400,000)
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		(200,000)		(400,000)
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		(401,800,000)		(371,600,000)
Consolidation Eliminations [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Consolidation Eliminations [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(401,800,000)	[1]	(361,800,000)	[2]
Consolidation Eliminations [Member] | Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(100,000)	[3]	(800,000)	[4]
Consolidation Eliminations [Member] | Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		100,000	[3]	(9,000,000)	[5]
Consolidation Eliminations [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(43,700,000)	[6]	(18,600,000)	[4]
Consolidation Eliminations [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(445,700,000)		(390,600,000)
Consolidation Eliminations [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		2,000,000		(1,600,000)
Consolidation Eliminations [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		2,900,000	[7]	1,300,000	[8]
Consolidation Eliminations [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenues		(900,000)	[3]	(2,900,000)	[4],[9]
Consolidation Eliminations [Member] | AEP Transmission Co [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Revenues		0		0
Revenue Textuals
Revenue from Related Parties		0		0
Vertically Integrated Utilities [Member]
Disaggregation of Revenue
Revenues		2,857,800,000		2,687,400,000
Revenue Textuals
Revenue from Related Parties		41,500,000		40,600,000
Vertically Integrated Utilities [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,530,900,000		2,334,100,000
Vertically Integrated Utilities [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,170,400,000		1,150,800,000
Vertically Integrated Utilities [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		633,400,000		572,900,000
Vertically Integrated Utilities [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		670,300,000		563,000,000
Vertically Integrated Utilities [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		56,800,000		47,400,000
Vertically Integrated Utilities [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		297,500,000		292,500,000
Vertically Integrated Utilities [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		182,800,000		187,200,000
Vertically Integrated Utilities [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		114,700,000	[1]	105,300,000	[2]
Vertically Integrated Utilities [Member] | Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[3]	0	[4]
Vertically Integrated Utilities [Member] | Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[3]	0	[5]
Vertically Integrated Utilities [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		32,600,000	[6]	61,600,000	[4]
Vertically Integrated Utilities [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,861,000,000		2,688,200,000
Vertically Integrated Utilities [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(3,200,000)		(800,000)
Vertically Integrated Utilities [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		(3,100,000)	[7]	(800,000)	[8]
Vertically Integrated Utilities [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenues		(100,000)	[3]	0	[4],[9]
Transmission And Distribution Utilities [Member]
Disaggregation of Revenue
Revenues		1,464,200,000		1,246,800,000
Revenue Textuals
Revenue from Related Parties		8,900,000		4,600,000
Transmission And Distribution Utilities [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,257,700,000		1,035,200,000
Transmission And Distribution Utilities [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		656,800,000		600,600,000
Transmission And Distribution Utilities [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		375,900,000		289,700,000
Transmission And Distribution Utilities [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		212,900,000		133,300,000
Transmission And Distribution Utilities [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		12,100,000		11,600,000
Transmission And Distribution Utilities [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		164,200,000		154,900,000
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		164,200,000	[1]	154,900,000	[2]
Transmission And Distribution Utilities [Member] | Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[3]	0	[4]
Transmission And Distribution Utilities [Member] | Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[3]	0	[5]
Transmission And Distribution Utilities [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		42,800,000	[6]	53,800,000	[4]
Transmission And Distribution Utilities [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,464,700,000		1,243,900,000
Transmission And Distribution Utilities [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(500,000)		2,900,000
Transmission And Distribution Utilities [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		(11,600,000)	[7]	(3,400,000)	[8]
Transmission And Distribution Utilities [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenues		11,100,000	[3]	6,300,000	[4],[9]
AEP Transmission Holdco [Member]
Disaggregation of Revenue
Revenues		455,500,000		411,400,000
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		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		450,100,000		414,500,000
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		450,100,000	[1]	414,500,000	[2]
Revenue Textuals
Revenue from Related Parties		357,000,000		327,000,000
AEP Transmission Holdco [Member] | Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[3]	0	[4]
AEP Transmission Holdco [Member] | Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[3]	0	[5]
AEP Transmission Holdco [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		3,600,000	[6]	(200,000)	[4]
AEP Transmission Holdco [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		453,700,000		414,300,000
AEP Transmission Holdco [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		1,800,000		(2,900,000)
AEP Transmission Holdco [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		1,800,000	[7]	(2,900,000)	[8]
AEP Transmission Holdco [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenues		0	[3]	0	[4],[9]
Generation And Marketing [Member]
Disaggregation of Revenue
Revenues		327,000,000		619,300,000
Revenue Textuals
Revenue from Related Parties		100,000		9,800,000
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		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		467,400,000		451,500,000
Generation And Marketing [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		32,400,000		40,300,000
Generation And Marketing [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[1]	0	[2]
Generation And Marketing [Member] | Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		21,300,000	[3]	22,400,000	[4]
Generation And Marketing [Member] | Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		413,700,000	[3]	388,800,000	[5]
Revenue Textuals
Revenue from Related Parties				9,000,000
Generation And Marketing [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		600,000	[6]	8,600,000	[4]
Generation And Marketing [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		468,000,000		460,100,000
Generation And Marketing [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(141,000,000)		159,200,000
Generation And Marketing [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		0	[7]	0	[8]
Generation And Marketing [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenues		(141,000,000)	[3],[20]	159,200,000	[4],[9]
Other Segments [Member]
Disaggregation of Revenue
Revenues	[21]	30,100,000		19,900,000
Revenue Textuals
Revenue from Related Parties	[21]	27,800,000		9,200,000
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		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		(300,000)		3,200,000
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	[1]	0	[2]
Other Segments [Member] | Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[3]	0	[4]
Other Segments [Member] | Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(300,000)	[3]	3,200,000	[5]
Other Segments [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		29,400,000	[6]	13,900,000	[4]
Other Segments [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		29,100,000		17,100,000
Other Segments [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		1,000,000		2,800,000
Other Segments [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		0	[7]	0	[8]
Other Segments [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers	[21]	2,300,000		10,700,000
Revenues		1,000,000	[3]	$ 2,800,000	[4],[9]
Corporate and Other | Other Revenues [Member]
Revenue Textuals
Revenue from Related Parties		$ 29,000,000
[1]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $357 million. The remaining affiliated amounts were immaterial.[2]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $327 million. The remaining affiliated amounts were immaterial.[3]Amounts include affiliated and nonaffiliated revenues.[4]Amounts include affiliated and nonaffiliated revenues[5]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $9 million. The remaining affiliated amounts were immaterial.[6]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $29 million. The remaining affiliated amounts were immaterial.[7]Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues.[8]Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues.[9]Generation & Marketing includes economic hedge activity.[10]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $47 million primarily related to the PPA with KGPCo.[11]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $36 million primarily related to the PPA with KGPCo.[12]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $349 million. The remaining affiliated amounts were immaterial.[13]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $323 million. The remaining affiliated amounts were immaterial.[14]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.[15]Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $10 million primarily related to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial.[16]Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues.[17]Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues.[18]Amounts include affiliated and nonaffiliated revenues.[19]Amounts include affiliated and nonaffiliated revenues.[20]Generation & Marketing includes economic hedge activity.[21]Corporate and Other primarily includes the purchasing of receivables from certain AEP utility subsidiaries. This segment also includes Parent’s guarantee revenue received from affiliates, investment income, interest income, interest expense and other nonallocated costs.