Southwestern Electric Power 10-K 13 Feb 25 2024 FY Annual report Financial data

Cover

Cover - USD ($)	12 Months Ended
	Dec. 31, 2024	Jun. 30, 2024
Entity Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2024
Current Fiscal Year End Date	--12-31
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
Title of 12(b) Security	Common Stock, $6.50 par value
Trading Symbol	AEP
Security Exchange Name	NASDAQ
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	true
Document Financial Statement Error Correction	false
Entity Shell Company	false
Entity Public Float		$ 46,757,322,914
Entity Common Stock, Shares Outstanding	532,907,715
Documents Incorporated by Reference	Description Part of Form 10-K into which Document is Incorporated Portions of Proxy Statement of American Electric Power Company, Inc. for 2025 Annual Meeting of Shareholders. Part III
Entity Central Index Key	0000004904
Amendment Flag	false
Document Fiscal Year Focus	2024
Document Fiscal Period Focus	FY
AEP TEXAS INC.
Entity Information [Line Items]
Entity File Number	333-221643
Entity Registrant Name	AEP TEXAS INC.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	51-0007707
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding	100
Entity Central Index Key	0001721781
AEP TRANSMISSION COMPANY, LLC
Entity Information [Line Items]
Entity File Number	333-217143
Entity Registrant Name	AEP TRANSMISSION COMPANY, LLC
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	46-1125168
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Central Index Key	0001702494
APPALACHIAN POWER COMPANY
Entity Information [Line Items]
Entity File Number	1-3457
Entity Registrant Name	APPALACHIAN POWER COMPANY
Entity Incorporation, State or Country Code	VA
Entity Tax Identification Number	54-0124790
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding	13,499,500
Entity Central Index Key	0000006879
INDIANA MICHIGAN POWER COMPANY
Entity Information [Line Items]
Entity File Number	1-3570
Entity Registrant Name	INDIANA MICHIGAN POWER COMPANY
Entity Incorporation, State or Country Code	IN
Entity Tax Identification Number	35-0410455
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding	1,400,000
Entity Central Index Key	0000050172
OHIO POWER COMPANY
Entity Information [Line Items]
Entity File Number	1-6543
Entity Registrant Name	OHIO POWER COMPANY
Entity Incorporation, State or Country Code	OH
Entity Tax Identification Number	31-4271000
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding	27,952,473
Entity Central Index Key	0000073986
PUBLIC SERVICE COMPANY OF OKLAHOMA
Entity Information [Line Items]
Entity File Number	0-343
Entity Registrant Name	PUBLIC SERVICE COMPANY OF OKLAHOMA
Entity Incorporation, State or Country Code	OK
Entity Tax Identification Number	73-0410895
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding	9,013,000
Entity Central Index Key	0000081027
SOUTHWESTERN ELECTRIC POWER COMPANY
Entity Information [Line Items]
Entity File Number	1-3146
Entity Registrant Name	SOUTHWESTERN ELECTRIC POWER COMPANY
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	72-0323455
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding	3,680
Entity Central Index Key	0000092487

Audit Information

Audit Information	12 Months Ended
	Dec. 31, 2024
Auditor [Line Item]
Auditor Name	PricewaterhouseCoopers LLP
Auditor Firm ID	238
Auditor Location	Columbus, Ohio
AEP TRANSMISSION COMPANY, LLC
Auditor [Line Item]
Auditor Name	PricewaterhouseCoopers LLP
Auditor Firm ID	238
Auditor Location	Columbus, Ohio
AEP TEXAS INC.
Auditor [Line Item]
Auditor Name	PricewaterhouseCoopers LLP
Auditor Firm ID	238
Auditor Location	Columbus, Ohio
APPALACHIAN POWER COMPANY
Auditor [Line Item]
Auditor Name	PricewaterhouseCoopers LLP
Auditor Firm ID	238
Auditor Location	Columbus, Ohio
INDIANA MICHIGAN POWER COMPANY
Auditor [Line Item]
Auditor Name	PricewaterhouseCoopers LLP
Auditor Firm ID	238
Auditor Location	Columbus, Ohio
OHIO POWER COMPANY
Auditor [Line Item]
Auditor Name	PricewaterhouseCoopers LLP
Auditor Firm ID	238
Auditor Location	Columbus, Ohio
PUBLIC SERVICE COMPANY OF OKLAHOMA
Auditor [Line Item]
Auditor Name	PricewaterhouseCoopers LLP
Auditor Firm ID	238
Auditor Location	Columbus, Ohio
SOUTHWESTERN ELECTRIC POWER COMPANY
Auditor [Line Item]
Auditor Name	PricewaterhouseCoopers LLP
Auditor Firm ID	238
Auditor Location	Columbus, Ohio

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
REVENUES
TOTAL REVENUES	$ 19,721.3	$ 18,982.3	$ 19,639.5
EXPENSES
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	5,936.3	6,578.3	7,097.9
Other Operation	3,127.6	2,810.5	2,878.1
Maintenance	1,325.1	1,276.3	1,249.4
Loss on the Expected Sale of the Kentucky Operations	0	0	363.3
Asset Impairments and Other Related Charges	142.5	85.6	48.8
Establishment of 2017-2019 Virginia Triennial Review Regulatory Asset	0	0	(37)
Gain on the Sale of Mineral Rights	0	0	(116.3)
Loss on the Sale of the Competitive Contracted Renewables Portfolio	0	92.7	0
Depreciation and Amortization	3,289.9	3,090.4	3,202.8
Taxes Other Than Income Taxes	1,596.3	1,492.3	1,469.8
TOTAL EXPENSES	15,417.7	15,426.1	16,156.8
OPERATING INCOME	4,303.6	3,556.2	3,482.7
Other Income (Expense):
Other Income	65.1	63.4	11.6
Allowance for Equity Funds Used During Construction	211	174.9	133.7
Non-Service Cost Components of Net Periodic Benefit Cost	126	221.1	188.5
Interest Expense	(1,862.8)	(1,806.9)	(1,396.1)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	2,842.9	2,208.7	2,420.4
Income Tax Expense (Benefit)	(39.2)	54.6	5.4
Equity Earnings (Loss) of Unconsolidated Subsidiaries	93.7	58.5	(109.4)
NET INCOME	2,975.8	2,212.6	2,305.6
Net Income (Loss) Attributable to Noncontrolling Interests	8.7	4.5	(1.6)
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS, Basic	2,967.1	2,208.1	2,307.2
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS, Diluted	$ 2,967.1	$ 2,208.1	$ 2,307.2
WEIGHTED AVERAGE NUMBER OF BASIC AEP COMMON SHARES OUTSTANDING (in shares)	530,092,672	518,903,682	511,841,946
TOTAL BASIC EARNINGS PER SHARE ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS (in USD per share)	$ 5.60	$ 4.26	$ 4.51
WEIGHTED AVERAGE NUMBER OF DILUTED AEP COMMON SHARES OUTSTANDING (in shares)	531,337,703	520,206,258	513,484,609
TOTAL DILUTED EARNINGS PER SHARE ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS (in USD per share)	$ 5.58	$ 4.24	$ 4.49
Vertically Integrated Utilities Revenues
REVENUES
TOTAL REVENUES	$ 11,414	$ 11,303.7	$ 11,292.8
Transmission and Distribution Utilities
REVENUES
TOTAL REVENUES	5,879.6	5,677.2	5,489.6
Generation & Marketing
REVENUES
TOTAL REVENUES	1,944.7	1,543.3	2,448.9
Other Revenues
REVENUES
TOTAL REVENUES	$ 483	$ 458.1	$ 408.2

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Statement of Comprehensive Income [Abstract]
Net Income	$ 2,975.8	$ 2,212.6	$ 2,305.6
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES
Cash Flow Hedges, Net of Tax	5	(127)	81.4
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(2.5)	(12.6)	(10.4)
Pension and OPEB Funded Status, Net of Tax	41	(16.3)	(155.4)
Recognition of Pension Settlement Costs, Net of Tax	8.9	0	0
Reclassification of KPCo Pension and OPEB Regulatory Assets, Net of Tax	0	16.7	(16.7)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)	52.4	(139.2)	(101.1)
TOTAL COMPREHENSIVE INCOME	3,028.2	2,073.4	2,204.5
Total Comprehensive Income (Loss) Attributable To Noncontrolling Interests	8.7	4.5	(1.6)
TOTAL COMPREHENSIVE INCOME ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS	$ 3,019.5	$ 2,068.9	$ 2,206.1

CONSOLIDATED STATEMENTS OF CO_2

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Statement of Comprehensive Income [Abstract]
Cash Flow Hedges, Tax	$ 1.3	$ (33.8)	$ 21.6
Amortization of Pension and OPEB Deferred Costs, Tax	(0.7)	(3.4)	(2.8)
Pension and OPEB Funded Status, Tax	10.9	(4.3)	(41.3)
Recognition of Pension Settlement Costs, Tax	2.4	0	0
Reclassifications of KPCo Pension and OPEB Regulatory Assets, Tax	$ 0	$ 4.4	$ (4.4)

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Millions	Total	Common Stock	Paid-in Capital	Retained Earnings		Accumulated Other Comprehensive Income (Loss)	Noncontrolling Interests
Beginning balance (in shares) at Dec. 31, 2021	524,416,175	524,400,000
Beginning balance at Dec. 31, 2021	$ 22,680.2	$ 3,408.7	$ 7,172.6	$ 11,667.1		$ 184.8	$ 247
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of Common Stock (in shares)	683,146	700,000
Issuance of Common Stock	$ 826.5	$ 4.4	822.1
Common Stock Dividends	(1,645.2)			(1,628.7)	[1]		(16.5)
Other Changes in Equity	56.4		56.3				0.1
Net Income (Loss)	2,305.6			2,307.2			(1.6)
Other Comprehensive Income (Loss)	$ (101.1)					(101.1)
Ending balance (in shares) at Dec. 31, 2022	525,099,321	525,100,000
Ending balance at Dec. 31, 2022	$ 24,122.4	$ 3,413.1	8,051	12,345.6		83.7	229
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of Common Stock (in shares)	2,269,836	2,300,000
Issuance of Common Stock	$ 999.6	$ 14.8	984.8
Common Stock Dividends	(1,760.4)			(1,752.3)	[1]		(8.1)
Other Changes in Equity	37.3		38.1	(1)			0.2
Disposition of Competitive Contracted Renewables Portfolio	(186.4)						(186.4)
Net Income (Loss)	2,212.6			2,208.1			4.5
Other Comprehensive Income (Loss)	$ (139.2)					(139.2)
Ending balance (in shares) at Dec. 31, 2023	527,369,157	527,400,000
Ending balance at Dec. 31, 2023	$ 25,285.9	$ 3,427.9	9,073.9	12,800.4		(55.5)	39.2
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of Common Stock (in shares)	6,725,373	6,700,000
Issuance of Common Stock	$ 552.1	$ 43.7	508.4
Common Stock Dividends	(1,903.9)			(1,898.3)	[1]		(5.6)
Other Changes in Equity	23.8		23.8
Net Income (Loss)	2,975.8			2,967.1			8.7
Other Comprehensive Income (Loss)	$ 52.4					52.4
Ending balance (in shares) at Dec. 31, 2024	534,094,530	534,100,000
Ending balance at Dec. 31, 2024	$ 26,986.1	$ 3,471.6	$ 9,606.1	$ 13,869.2		$ (3.1)	$ 42.3
[1]Cash dividends declared per AEP common share were $3.57, $3.37 and $3.17 for the years ended December 31, 2024, 2023 and 2022, respectively.

CONSOLIDATED STATEMENTS OF CH_2

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Statement of Stockholders' Equity [Abstract]
Cash dividends declared (in USD per share)	$ 3.57	$ 3.37	$ 3.17

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
CURRENT ASSETS
Cash and Cash Equivalents	$ 202.9	$ 330.1
Restricted Cash	43.1	48.9
Other Temporary Investments	215.4	214.3
Accounts Receivable:
Customers	1,100.1	1,029.9
Accrued Unbilled Revenues	367	179.5
Pledged Accounts Receivable – AEP Credit	1,161.5	1,249.4
Miscellaneous	64.1	48.7
Allowance for Credit Losses	(60.8)	(60.1)
Total Accounts Receivable	2,631.9	2,447.4
Fuel	748.9	853.7
Materials and Supplies	966.2	1,025.8
Risk Management Assets	210.4	217.5
Accrued Tax Benefits	38.2	156.2
Regulatory Asset for Under-Recovered Fuel Costs	445.9	514
Prepayments and Other Current Assets	285.9	274.2
TOTAL CURRENT ASSETS	5,788.8	6,082.1
PROPERTY, PLANT AND EQUIPMENT
Generation	24,829.7	24,329.5
Transmission	38,871.9	35,934.1
Distribution	31,061.9	28,989.9
Other Property, Plant and Equipment (Including Coal Mining and Nuclear Fuel)	7,491.6	6,484.9
Construction Work in Progress	6,346.9	5,508
Total Property, Plant and Equipment	108,602	101,246.4
Accumulated Depreciation and Amortization	26,186.4	24,553
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	82,415.6	76,693.4
OTHER NONCURRENT ASSETS
Regulatory Assets	5,129.2	5,092.4
Securitized Assets	554.3	336.3
Spent Nuclear Fuel and Decommissioning Trusts	4,395.1	3,860.2
Goodwill	52.5	52.5
Long-term Risk Management Assets	289.1	321.2
Operating Lease Assets	580.1	620.2
Deferred Charges and Other Noncurrent Assets	3,873.3	3,625.7
TOTAL OTHER NONCURRENT ASSETS	14,873.6	13,908.5
TOTAL ASSETS	103,078	96,684
CURRENT LIABILITIES
Accounts Payable	2,637.6	2,032.5
Short-term Debt:
Securitized Debt for Receivables – AEP Credit	900	888
Other Short-term Debt	1,623.8	1,942.2
Total Short-term Debt	2,523.8	2,830.2
Long-term Debt Due Within One Year	3,335	2,490.5
Risk Management Liabilities	100	229.6
Customer Deposits	454.7	423.7
Accrued Taxes	1,922.1	1,800.1
Accrued Interest	453.3	410.2
Obligations Under Operating Leases	91.9	115.7
Other Current Liabilities	1,490.9	1,251.1
TOTAL CURRENT LIABILITIES	13,009.3	11,583.6
NONCURRENT LIABILITIES
Long-term Debt	39,307.8	37,652.7
Long-term Risk Management Liabilities	224.4	241.8
Deferred Income Taxes	9,972.4	9,415.7
Regulatory Liabilities and Deferred Investment Tax Credits	8,344	8,182.4
Asset Retirement Obligations	3,530.6	2,972.5
Employee Benefits and Pension Obligations	360.7	241.7
Obligations Under Operating Leases	504.3	519.4
Deferred Credits and Other Noncurrent Liabilities	800.6	545.8
TOTAL NONCURRENT LIABILITIES	63,044.8	59,772
TOTAL LIABILITIES	76,054.1	71,355.6
Rate Matters (Note 4)
Commitments and Contingencies (Note 6)
MEZZANINE EQUITY
Contingently Redeemable Performance Share Awards	37.8	42.5
TOTAL MEZZANINE EQUITY	37.8	42.5
EQUITY
Common Stock	3,471.6	3,427.9
Paid-in Capital	9,606.1	9,073.9
Retained Earnings	13,869.2	12,800.4
Accumulated Other Comprehensive Income (Loss)	(3.1)	(55.5)
TOTAL COMMON SHAREHOLDER’S EQUITY	26,943.8	25,246.7
Noncontrolling Interests	42.3	39.2
TOTAL EQUITY	26,986.1	25,285.9
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	$ 103,078	$ 96,684

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Restricted Cash	$ 43.1	$ 48.9
Other Temporary Investments	215.4	214.3
Long-term Debt Due Within One Year	3,335	2,490.5
Long-term Debt	$ 39,307.8	$ 37,652.7
Common Stock – Par Value (in USD per share)	$ 6.50	$ 6.50
Common Stock – Shares Authorized (in shares)	600,000,000	600,000,000
Common Stock – Shares Issued (in shares)	534,094,530	527,369,157
Shares were Held in Treasury (in shares)	1,186,815	1,184,572
Subsidiaries
Restricted Cash	$ 43.1	$ 48.9
Other Temporary Investments	206.7	205
Long-term Debt Due Within One Year	216.5	207.2
Long-term Debt	$ 826.5	$ 556.3

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
OPERATING ACTIVITIES
Net Income	$ 2,975.8	$ 2,212.6	$ 2,305.6
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities:
Depreciation and Amortization	3,289.9	3,090.4	3,202.8
Deferred Income Taxes	58.3	185.1	(137.2)
Loss on the Expected Sale of the Kentucky Operations	0	0	363.3
Loss on the Sale of the Competitive Contracted Renewables Portfolio	0	92.7	0
Asset Impairments and Other Related Charges	142.5	85.6	48.8
Impairment of Equity Method Investment	0	19	188
Allowance for Equity Funds Used During Construction	(211)	(174.9)	(133.7)
Mark-to-Market of Risk Management Contracts	(80.4)	8.8	15.5
Amortization of Nuclear Fuel	102.9	96.6	82.9
Property Taxes	(45.4)	(41.1)	(41.2)
Deferred Fuel Over/Under-Recovery, Net	277	892.8	(319.2)
Gain on the Sale of Mineral Rights	0	0	(116.3)
Establishment of 2017-2019 Virginia Triennial Review Regulatory Asset	0	0	(37)
Change in Regulatory Assets	(174.3)	(315.8)	(46.7)
Change in Other Noncurrent Assets	(347.6)	(465.1)	(187.7)
Change in Other Noncurrent Liabilities	306.3	29	337.8
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(156)	236.5	(681.7)
Fuel, Materials and Supplies	171.6	(504)	(313.9)
Accounts Payable	85.1	(253.2)	489.2
Accrued Taxes, Net	240.2	22.5	105.4
Other Current Assets	(13.2)	(43.9)	109
Other Current Liabilities	182.6	(161.4)	54.3
Net Cash Flows from Operating Activities	6,804.3	5,012.2	5,288
INVESTING ACTIVITIES
Construction Expenditures	(7,630.7)	(7,378.3)	(6,671.7)
Purchases of Investment Securities	(2,922.5)	(2,863.6)	(2,784.2)
Sales of Investment Securities	2,878	2,795.1	2,743.8
Acquisitions of Nuclear Fuel	(139.9)	(128.2)	(100.7)
Acquisitions of Renewable Energy Facilities	(399.5)	(155.2)	(1,207.3)
Proceeds from Sales of Assets	362.2	1,341.4	218
Proceeds from Sale of Equity Method Investment	114	0	0
Other Investing Activities	141.9	122.1	50.3
Net Cash Flows Used for Investing Activities	(7,596.5)	(6,266.7)	(7,751.8)
FINANCING ACTIVITIES
Issuance of Common Stock, Net	552.1	999.6	826.5
Issuance of Long-term Debt	5,117	5,462.8	4,649.7
Issuance of Short-term Debt with Original Maturities greater than 90 Days	723.8	1,069.9	833.9
Change in Short-term Debt with Original Maturities less than 90 Day, Net	(159.1)	(1,223.1)	1,650.4
Retirement of Long-term Debt	(2,685)	(2,196.1)	(2,345.4)
Redemption of Short-term Debt with Original Maturities greater than 90 Days	(871.1)	(1,128.8)	(986.1)
Principal Payments for Finance Lease Obligations	(64.8)	(68.3)	(309.5)
Dividends Paid on Common Stock	(1,903.9)	(1,760.4)	(1,645.2)
Other Financing Activities	(49.8)	(78.6)	(105.4)
Net Cash Flows from Financing Activities	659.2	1,077	2,568.9
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(133)	(177.5)	105.1
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	379	556.5	451.4
Cash, Cash Equivalents and Restricted Cash at End of Period	$ 246	$ 379	$ 556.5

CONSOLIDATED STATEMENTS OF IN_2

CONSOLIDATED STATEMENTS OF INCOME - AEP Texas - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
REVENUES
TOTAL REVENUES	$ 19,721.3	$ 18,982.3	$ 19,639.5
EXPENSES
Other Operation	3,127.6	2,810.5	2,878.1
Maintenance	1,325.1	1,276.3	1,249.4
Depreciation and Amortization	3,289.9	3,090.4	3,202.8
Taxes Other Than Income Taxes	1,596.3	1,492.3	1,469.8
TOTAL EXPENSES	15,417.7	15,426.1	16,156.8
OPERATING INCOME	4,303.6	3,556.2	3,482.7
Other Income (Expense):
Allowance for Equity Funds Used During Construction	211	174.9	133.7
Non-Service Cost Components of Net Periodic Benefit Cost	126	221.1	188.5
Interest Expense	(1,862.8)	(1,806.9)	(1,396.1)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	2,842.9	2,208.7	2,420.4
Income Tax Expense (Benefit)	(39.2)	54.6	5.4
AEP TEXAS INC.
REVENUES
TOTAL REVENUES	2,079.9	1,901.9	1,846.8
EXPENSES
Other Operation	625.1	541.6	594.2
Maintenance	90.3	91.9	93.5
Depreciation and Amortization	493.5	468.5	452.4
Taxes Other Than Income Taxes	164	160.8	157.5
TOTAL EXPENSES	1,372.9	1,262.8	1,297.6
OPERATING INCOME	707	639.1	549.2
Other Income (Expense):
Interest Income	6.6	2.3	3.6
Allowance for Equity Funds Used During Construction	45.9	28.4	19.7
Non-Service Cost Components of Net Periodic Benefit Cost	20.3	19.2	16.7
Interest Expense	(257.6)	(232.7)	(208.7)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	522.2	456.3	380.5
Income Tax Expense (Benefit)	102.1	85.9	72.6
NET INCOME	420.1	370.4	307.9
Transmission and Distribution Utilities
REVENUES
TOTAL REVENUES	5,879.6	5,677.2	5,489.6
Transmission and Distribution Utilities | AEP TEXAS INC.
REVENUES
TOTAL REVENUES	2,070.8	1,892	1,839.7
Sales to AEP Affiliates | AEP TEXAS INC. | Affiliated Entity
REVENUES
TOTAL REVENUES	5.4	4.9	3.5
Other Revenues
REVENUES
TOTAL REVENUES	483	458.1	408.2
Other Revenues | AEP TEXAS INC.
REVENUES
TOTAL REVENUES	$ 3.7	$ 5	$ 3.6

CONSOLIDATED STATEMENTS OF CO_3

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - AEP Texas - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES
Cash Flow Hedges, Net of Tax	$ 5	$ (127)	$ 81.4
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(2.5)	(12.6)	(10.4)
Pension and OPEB Funded Status, Net of Tax	41	(16.3)	(155.4)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)	52.4	(139.2)	(101.1)
TOTAL COMPREHENSIVE INCOME ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS	3,019.5	2,068.9	2,206.1
AEP TEXAS INC.
Net Income	420.1	370.4	307.9
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES
Cash Flow Hedges, Net of Tax	5.8	0.8	1
Amortization of Pension and OPEB Deferred Costs, Net of Tax	0	(0.7)	0.1
Pension and OPEB Funded Status, Net of Tax	(0.2)	(0.1)	(3.2)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)	5.6	0	(2.1)
TOTAL COMPREHENSIVE INCOME ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS	$ 425.7	$ 370.4	$ 305.8

CONSOLIDATED STATEMENTS OF CO_4

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - AEP Texas (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Cash Flow Hedges, Tax	$ 1.3	$ (33.8)	$ 21.6
Amortization of Pension and OPEB Deferred Costs, Tax	(0.7)	(3.4)	(2.8)
Pension and OPEB Funded Status, Tax	10.9	(4.3)	(41.3)
AEP TEXAS INC.
Cash Flow Hedges, Tax	1.5	0.2	0.3
Amortization of Pension and OPEB Deferred Costs, Tax	0	(0.2)	0
Pension and OPEB Funded Status, Tax	$ (0.1)	$ 0	$ (0.9)

CONSOLIDATED STATEMENTS OF CH_3

CONSOLIDATED STATEMENTS OF CHANGES IN COMMON SHAREHOLDER’S EQUITY - AEP Texas - USD ($) $ in Millions	Total	Retained Earnings	[1]	Accumulated Other Comprehensive Income (Loss)	AEP TEXAS INC.	AEP TEXAS INC. Paid-in Capital	AEP TEXAS INC. Retained Earnings	AEP TEXAS INC. Accumulated Other Comprehensive Income (Loss)
Beginning balance at Dec. 31, 2021					$ 3,594.2	$ 1,553.9	$ 2,046.8	$ (6.5)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contribution from Parent					4.3	4.3
Common Stock Dividends	$ (1,645.2)	$ (1,628.7)
Net Income					307.9		307.9
Other Comprehensive Income (Loss)	(101.1)			$ (101.1)	(2.1)			(2.1)
Ending balance at Dec. 31, 2022					3,904.3	1,558.2	2,354.7	(8.6)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contribution from Parent					527	527
Return of Capital to Parent					(5.6)	(5.6)
Common Stock Dividends	(1,760.4)	(1,752.3)
Net Income					370.4		370.4
Other Comprehensive Income (Loss)	(139.2)			(139.2)	0
Ending balance at Dec. 31, 2023	25,246.7				4,796.1	2,079.6	2,725.1	(8.6)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contribution from Parent					13.5	13.5
Return of Capital to Parent					(0.7)	(0.7)
Common Stock Dividends	(1,903.9)	$ (1,898.3)			(350)		(350)
Net Income					420.1		420.1
Other Comprehensive Income (Loss)	52.4			$ 52.4	5.6			5.6
Ending balance at Dec. 31, 2024	$ 26,943.8				$ 4,884.6	$ 2,092.4	$ 2,795.2	$ (3)
[1]Cash dividends declared per AEP common share were $3.57, $3.37 and $3.17 for the years ended December 31, 2024, 2023 and 2022, respectively.

CONSOLIDATED BALANCE SHEETS - A

CONSOLIDATED BALANCE SHEETS - AEP Texas - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
CURRENT ASSETS
Cash and Cash Equivalents	$ 202.9	$ 330.1
Restricted Cash	43.1	48.9
Accounts Receivable:
Customers	1,100.1	1,029.9
Accrued Unbilled Revenues	367	179.5
Miscellaneous	64.1	48.7
Allowance for Credit Losses	(60.8)	(60.1)
Total Accounts Receivable	2,631.9	2,447.4
Materials and Supplies	966.2	1,025.8
Prepayments and Other Current Assets	285.9	274.2
TOTAL CURRENT ASSETS	5,788.8	6,082.1
PROPERTY, PLANT AND EQUIPMENT
Transmission	38,871.9	35,934.1
Distribution	31,061.9	28,989.9
Other Property, Plant and Equipment	7,491.6	6,484.9
Construction Work in Progress	6,346.9	5,508
Total Property, Plant and Equipment	108,602	101,246.4
Accumulated Depreciation and Amortization	26,186.4	24,553
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	82,415.6	76,693.4
OTHER NONCURRENT ASSETS
Regulatory Assets	5,129.2	5,092.4
Securitized Assets	554.3	336.3
Deferred Charges and Other Noncurrent Assets	3,873.3	3,625.7
TOTAL OTHER NONCURRENT ASSETS	14,873.6	13,908.5
TOTAL ASSETS	103,078	96,684
CURRENT LIABILITIES
Accounts Payable	2,637.6	2,032.5
Long-term Debt Due Within One Year	3,335	2,490.5
Accrued Taxes	1,922.1	1,800.1
Accrued Interest	453.3	410.2
Obligations Under Operating Leases	91.9	115.7
Other Current Liabilities	1,490.9	1,251.1
TOTAL CURRENT LIABILITIES	13,009.3	11,583.6
NONCURRENT LIABILITIES
Long-term Debt	39,307.8	37,652.7
Deferred Income Taxes	9,972.4	9,415.7
Regulatory Liabilities and Deferred Investment Tax Credits	8,344	8,182.4
Obligations Under Operating Leases	504.3	519.4
Deferred Credits and Other Noncurrent Liabilities	800.6	545.8
TOTAL NONCURRENT LIABILITIES	63,044.8	59,772
TOTAL LIABILITIES	76,054.1	71,355.6
Rate Matters (Note 4)
Commitments and Contingencies (Note 6)
COMMON SHAREHOLDER’S EQUITY
Paid-in Capital	9,606.1	9,073.9
Retained Earnings	13,869.2	12,800.4
Accumulated Other Comprehensive Income (Loss)	(3.1)	(55.5)
TOTAL COMMON SHAREHOLDER’S EQUITY	26,943.8	25,246.7
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	103,078	96,684
AEP TEXAS INC.
CURRENT ASSETS
Cash and Cash Equivalents	0.1	0.1
Restricted Cash	23.5	34
Advances to Affiliates	7.2	7.1
Accounts Receivable:
Customers	182.8	176.5
Accrued Unbilled Revenues	97.2	82.3
Miscellaneous	0.3	0.8
Allowance for Credit Losses	(4.3)	(4.9)
Total Accounts Receivable	286.7	278.5
Materials and Supplies	169.5	190.4
Prepayments and Other Current Assets	13.4	10
TOTAL CURRENT ASSETS	500.4	520.1
PROPERTY, PLANT AND EQUIPMENT
Transmission	7,546.2	6,812.6
Distribution	6,250.5	5,798.8
Other Property, Plant and Equipment	1,175.7	1,145.9
Construction Work in Progress	1,118	904.6
Total Property, Plant and Equipment	16,090.4	14,661.9
Accumulated Depreciation and Amortization	2,046.9	1,887.9
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	14,043.5	12,774
OTHER NONCURRENT ASSETS
Regulatory Assets	353.6	315.3
Securitized Assets	116.7	202.9
Deferred Charges and Other Noncurrent Assets	185.4	178.4
TOTAL OTHER NONCURRENT ASSETS	655.7	696.6
TOTAL ASSETS	15,199.6	13,990.7
CURRENT LIABILITIES
Accounts Payable	366.2	192.3
Long-term Debt Due Within One Year	324.5	96
Accrued Taxes	127.1	99.1
Accrued Interest	55	49.2
Obligations Under Operating Leases	13.1	28.7
Other Current Liabilities	201.4	152.7
TOTAL CURRENT LIABILITIES	1,407.1	749.4
NONCURRENT LIABILITIES
Long-term Debt	6,117.1	5,793.8
Deferred Income Taxes	1,322.7	1,227.8
Regulatory Liabilities and Deferred Investment Tax Credits	1,285.4	1,261.4
Obligations Under Operating Leases	43.4	50.9
Deferred Credits and Other Noncurrent Liabilities	139.3	111.3
TOTAL NONCURRENT LIABILITIES	8,907.9	8,445.2
TOTAL LIABILITIES	10,315	9,194.6
Rate Matters (Note 4)
Commitments and Contingencies (Note 6)
COMMON SHAREHOLDER’S EQUITY
Paid-in Capital	2,092.4	2,079.6
Retained Earnings	2,795.2	2,725.1
Accumulated Other Comprehensive Income (Loss)	(3)	(8.6)
TOTAL COMMON SHAREHOLDER’S EQUITY	4,884.6	4,796.1
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	15,199.6	13,990.7
AEP TEXAS INC. | Affiliated Entity
Accounts Receivable:
Affiliated Companies	10.7	23.8
CURRENT LIABILITIES
Advances from Affiliates	284.9	103.7
Accounts Payable	$ 34.9	$ 27.7

CONSOLIDATED BALANCE SHEETS -_2

CONSOLIDATED BALANCE SHEETS - AEP Texas (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Restricted Cash	$ 43.1	$ 48.9
Securitized Assets	554.3	336.3
Long-term Debt Due Within One Year	3,335	2,490.5
Accrued Interest	453.3	410.2
Long-term Debt	39,307.8	37,652.7
AEP TEXAS INC.
Restricted Cash	23.5	34
Securitized Assets	116.7	202.9
Long-term Debt Due Within One Year	324.5	96
Accrued Interest	55	49.2
Long-term Debt	6,117.1	5,793.8
AEP TEXAS INC. | AEP Texas Transition and Restoration Funding
Restricted Cash	23.5	34
Securitized Assets	116.7	202.9
Long-term Debt Due Within One Year	24.4	95.9
Accrued Interest	1.9	2
Long-term Debt	$ 102.4	$ 125.9

CONSOLIDATED STATEMENTS OF CA_2

CONSOLIDATED STATEMENTS OF CASH FLOWS - AEP Texas - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities:
Depreciation and Amortization	$ 3,289.9	$ 3,090.4	$ 3,202.8
Deferred Income Taxes	58.3	185.1	(137.2)
Allowance for Equity Funds Used During Construction	(211)	(174.9)	(133.7)
Mark-to-Market of Risk Management Contracts	(80.4)	8.8	15.5
Change in Other Noncurrent Assets	(347.6)	(465.1)	(187.7)
Change in Other Noncurrent Liabilities	306.3	29	337.8
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(156)	236.5	(681.7)
Materials and Supplies	171.6	(504)	(313.9)
Accounts Payable	85.1	(253.2)	489.2
Accrued Taxes, Net	240.2	22.5	105.4
Other Current Assets	(13.2)	(43.9)	109
Other Current Liabilities	182.6	(161.4)	54.3
Net Cash Flows from Operating Activities	6,804.3	5,012.2	5,288
INVESTING ACTIVITIES
Construction Expenditures	(7,630.7)	(7,378.3)	(6,671.7)
Other Investing Activities	141.9	122.1	50.3
Net Cash Flows Used for Investing Activities	(7,596.5)	(6,266.7)	(7,751.8)
FINANCING ACTIVITIES
Issuance of Long-term Debt	5,117	5,462.8	4,649.7
Retirement of Long-term Debt	(2,685)	(2,196.1)	(2,345.4)
Principal Payments for Finance Lease Obligations	(64.8)	(68.3)	(309.5)
Dividends Paid on Common Stock	(1,903.9)	(1,760.4)	(1,645.2)
Other Financing Activities	(49.8)	(78.6)	(105.4)
Net Cash Flows from Financing Activities	659.2	1,077	2,568.9
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(133)	(177.5)	105.1
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	379	556.5	451.4
Cash, Cash Equivalents and Restricted Cash at End of Period	246	379	556.5
SUPPLEMENTARY INFORMATION
Cash Paid for Interest, Net of Capitalized Amounts	1,837.8	1,673.5	1,286.3
Net Cash Paid for Income Taxes	133.4	78.4	116.8
Noncash Acquisitions Under Finance Leases	29.5	48.7	31.8
Construction Expenditures Included in Current Liabilities as of December 31,	1,312	842.4	1,258.9
AEP TEXAS INC.
OPERATING ACTIVITIES
Net Income	420.1	370.4	307.9
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities:
Depreciation and Amortization	493.5	468.5	452.4
Deferred Income Taxes	77.8	64.1	42.2
Allowance for Equity Funds Used During Construction	(45.9)	(28.4)	(19.7)
Mark-to-Market of Risk Management Contracts	0	0.4	(0.4)
Change in Other Noncurrent Assets	(90.8)	(96.5)	(36.2)
Change in Other Noncurrent Liabilities	39.2	24.3	57.6
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(8.2)	(28.3)	(45)
Materials and Supplies	20.9	(51.6)	(64.9)
Accounts Payable	24.8	(24.1)	25
Accrued Taxes, Net	30.1	11.8	14.8
Other Current Assets	(5.6)	3	2.2
Other Current Liabilities	8.2	(53.9)	(4)
Net Cash Flows from Operating Activities	964.1	659.7	731.9
INVESTING ACTIVITIES
Construction Expenditures	(1,413.6)	(1,477.1)	(1,305)
Change in Advances to Affiliates, Net	(0.1)	(0.2)	0
Other Investing Activities	54.3	69.3	35.1
Net Cash Flows Used for Investing Activities	(1,359.4)	(1,408)	(1,269.9)
FINANCING ACTIVITIES
Capital Contribution from Parent	13.5	527	4.3
Return of Capital to Parent	(0.7)	(5.6)	0
Issuance of Long-term Debt	841.9	505.4	1,188.6
Change in Advances from Affiliates, Net	181.2	7.2	69.6
Retirement of Long-term Debt	(296)	(278.5)	(716)
Principal Payments for Finance Lease Obligations	(7.5)	(7.4)	(6.8)
Dividends Paid on Common Stock	(350)	0	0
Other Financing Activities	2.4	1.5	0.6
Net Cash Flows from Financing Activities	384.8	749.6	540.3
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(10.5)	1.3	2.3
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	34.1	32.8	30.5
Cash, Cash Equivalents and Restricted Cash at End of Period	23.6	34.1	32.8
SUPPLEMENTARY INFORMATION
Cash Paid for Interest, Net of Capitalized Amounts	240.7	225.6	198.9
Net Cash Paid for Income Taxes	10.9	11.5	11
Noncash Acquisitions Under Finance Leases	4.6	4.8	6.1
Construction Expenditures Included in Current Liabilities as of December 31,	$ 266	$ 112.2	$ 235.4

CONSOLIDATED STATEMENTS OF IN_3

CONSOLIDATED STATEMENTS OF INCOME - AEP Transmission Holdco - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
REVENUES
TOTAL REVENUES	$ 19,721.3	$ 18,982.3	$ 19,639.5
EXPENSES
Other Operation	3,127.6	2,810.5	2,878.1
Maintenance	1,325.1	1,276.3	1,249.4
Depreciation and Amortization	3,289.9	3,090.4	3,202.8
Taxes Other Than Income Taxes	1,596.3	1,492.3	1,469.8
TOTAL EXPENSES	15,417.7	15,426.1	16,156.8
OPERATING INCOME	4,303.6	3,556.2	3,482.7
Other Income (Expense):
Allowance for Equity Funds Used During Construction	211	174.9	133.7
Interest Expense	(1,862.8)	(1,806.9)	(1,396.1)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	2,842.9	2,208.7	2,420.4
Income Tax Expense (Benefit)	(39.2)	54.6	5.4
AEP TRANSMISSION COMPANY, LLC
REVENUES
TOTAL REVENUES	1,890.9	1,672	1,624.5
EXPENSES
Other Operation	137.4	109	136.3
Maintenance	20.9	20.4	17.2
Depreciation and Amortization	430.9	393.8	346.2
Taxes Other Than Income Taxes	308.7	283.2	271.1
TOTAL EXPENSES	897.9	806.4	770.8
OPERATING INCOME	993	865.6	853.7
Other Income (Expense):
Interest Income	10.5	7	1.6
Allowance for Equity Funds Used During Construction	89.4	83.2	70.7
Interest Expense	(214.2)	(194.5)	(162.7)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	878.7	761.3	763.3
Income Tax Expense (Benefit)	190.3	147.1	169.1
NET INCOME	688.4	614.2	594.2
AEP TRANSMISSION COMPANY, LLC | Affiliated Entity
REVENUES
TOTAL REVENUES	1,512.3	1,317.8	1,283.8
AEP TRANSMISSION COMPANY, LLC | Nonrelated Party
REVENUES
TOTAL REVENUES	378.6	354.2	340.9
Transmission | AEP TRANSMISSION COMPANY, LLC
REVENUES
TOTAL REVENUES	400.9	363.3	354.9
Sales to AEP Affiliates | AEP TRANSMISSION COMPANY, LLC | Affiliated Entity
REVENUES
TOTAL REVENUES	1,582.3	1,463.4	1,354.5
Provision for Refund | AEP TRANSMISSION COMPANY, LLC | Affiliated Entity
REVENUES
TOTAL REVENUES	(70)	(145.6)	(70.7)
Provision for Refund | AEP TRANSMISSION COMPANY, LLC | Nonrelated Party
REVENUES
TOTAL REVENUES	$ (22.3)	$ (9.1)	$ (14.2)

CONSOLIDATED STATEMENTS OF CH_4

CONSOLIDATED STATEMENTS OF CHANGES IN MEMBER’S EQUITY - AEP Transmission Holdco - AEP TRANSMISSION COMPANY, LLC - USD ($) $ in Millions	Total	Paid-in Capital	Retained Earnings
Beginning balance at Dec. 31, 2021	$ 5,376.1	$ 2,949.6	$ 2,426.5
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contribution from Member	72.7	72.7
Dividends Paid to Member	(170)		(170)
Net Income	594.2		594.2
Ending balance at Dec. 31, 2022	5,873	3,022.3	2,850.7
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contribution from Member	29.7	29.7
Return of Capital to Member	(8.6)	(8.6)
Dividends Paid to Member	(175)		(175)
Net Income	614.2		614.2
Ending balance at Dec. 31, 2023	6,333.3	3,043.4	3,289.9
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contribution from Member	61.7	61.7
Return of Capital to Member	(4.5)	(4.5)
Dividends Paid to Member	(128)		(128)
Net Income	688.4		688.4
Ending balance at Dec. 31, 2024	$ 6,950.9	$ 3,100.6	$ 3,850.3

CONSOLIDATED BALANCE SHEETS -_3

CONSOLIDATED BALANCE SHEETS - AEP Transmission Holdco - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Accounts Receivable:
Customers	$ 1,100.1	$ 1,029.9
Miscellaneous	64.1	48.7
Total Accounts Receivable	2,631.9	2,447.4
Prepayments and Other Current Assets	285.9	274.2
TOTAL CURRENT ASSETS	5,788.8	6,082.1
PROPERTY, PLANT AND EQUIPMENT
Transmission	38,871.9	35,934.1
Other Property, Plant and Equipment	7,491.6	6,484.9
Construction Work in Progress	6,346.9	5,508
Total Property, Plant and Equipment	108,602	101,246.4
Accumulated Depreciation and Amortization	26,186.4	24,553
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	82,415.6	76,693.4
OTHER NONCURRENT ASSETS
Regulatory Assets	5,129.2	5,092.4
Deferred Charges and Other Noncurrent Assets	3,873.3	3,625.7
TOTAL OTHER NONCURRENT ASSETS	14,873.6	13,908.5
TOTAL ASSETS	103,078	96,684
CURRENT LIABILITIES
Accounts Payable	2,637.6	2,032.5
Long-term Debt Due Within One Year	3,335	2,490.5
Accrued Taxes	1,922.1	1,800.1
Accrued Interest	453.3	410.2
Obligations Under Operating Leases	91.9	115.7
Other Current Liabilities	1,490.9	1,251.1
TOTAL CURRENT LIABILITIES	13,009.3	11,583.6
NONCURRENT LIABILITIES
Long-term Debt	39,307.8	37,652.7
Deferred Income Taxes	9,972.4	9,415.7
Regulatory Liabilities and Deferred Investment Tax Credits	8,344	8,182.4
Obligations Under Operating Leases	504.3	519.4
Deferred Credits and Other Noncurrent Liabilities	800.6	545.8
TOTAL NONCURRENT LIABILITIES	63,044.8	59,772
TOTAL LIABILITIES	76,054.1	71,355.6
Rate Matters (Note 4)
Commitments and Contingencies (Note 6)
MEMBER’S EQUITY
Retained Earnings	13,869.2	12,800.4
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	103,078	96,684
AEP TRANSMISSION COMPANY, LLC
CURRENT ASSETS
Advances to Affiliates	30.4	67.1
Accounts Receivable:
Customers	58.9	82.2
Miscellaneous	1.3	0
Total Accounts Receivable	194.3	207.7
Prepayments and Other Current Assets	11.1	4
TOTAL CURRENT ASSETS	235.8	278.8
PROPERTY, PLANT AND EQUIPMENT
Transmission	14,913.4	13,723.9
Other Property, Plant and Equipment	516.1	501.4
Construction Work in Progress	1,965.4	1,563.7
Total Property, Plant and Equipment	17,394.9	15,789
Accumulated Depreciation and Amortization	1,578.4	1,291.3
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	15,816.5	14,497.7
OTHER NONCURRENT ASSETS
Regulatory Assets	0.4	3.1
Deferred Property Taxes	308.9	286.4
Deferred Charges and Other Noncurrent Assets	8.7	6.5
TOTAL OTHER NONCURRENT ASSETS	318	296
TOTAL ASSETS	16,370.3	15,072.5
CURRENT LIABILITIES
Accounts Payable	360.5	274.7
Long-term Debt Due Within One Year	90	95
Accrued Taxes	665.9	568.6
Accrued Interest	44.9	39.6
Obligations Under Operating Leases	1.3	1.3
Other Current Liabilities	44.5	24.7
TOTAL CURRENT LIABILITIES	1,408.8	1,286.1
NONCURRENT LIABILITIES
Long-term Debt	5,678.1	5,319.4
Deferred Income Taxes	1,278.6	1,147.7
Regulatory Liabilities and Deferred Investment Tax Credits	878.4	783.7
Obligations Under Operating Leases	1.2	1.4
Deferred Credits and Other Noncurrent Liabilities	174.3	200.9
TOTAL NONCURRENT LIABILITIES	8,010.6	7,453.1
TOTAL LIABILITIES	9,419.4	8,739.2
Rate Matters (Note 4)
Commitments and Contingencies (Note 6)
MEMBER’S EQUITY
Paid-in Capital	3,100.6	3,043.4
Retained Earnings	3,850.3	3,289.9
TOTAL MEMBER’S EQUITY	6,950.9	6,333.3
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	16,370.3	15,072.5
AEP TRANSMISSION COMPANY, LLC | Affiliated Entity
Accounts Receivable:
Affiliated Companies	134.1	125.5
CURRENT LIABILITIES
Advances from Affiliates	84.7	174.3
Accounts Payable	$ 117	$ 107.9

CONSOLIDATED STATEMENTS OF CA_3

CONSOLIDATED STATEMENTS OF CASH FLOWS - AEP Transmission Holdco - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities:
Depreciation and Amortization	$ 3,289.9	$ 3,090.4	$ 3,202.8
Deferred Income Taxes	58.3	185.1	(137.2)
Allowance for Equity Funds Used During Construction	(211)	(174.9)	(133.7)
Property Taxes	(45.4)	(41.1)	(41.2)
Change in Other Noncurrent Assets	(347.6)	(465.1)	(187.7)
Change in Other Noncurrent Liabilities	306.3	29	337.8
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(156)	236.5	(681.7)
Materials and Supplies	171.6	(504)	(313.9)
Accounts Payable	85.1	(253.2)	489.2
Accrued Taxes, Net	240.2	22.5	105.4
Other Current Assets	(13.2)	(43.9)	109
Other Current Liabilities	182.6	(161.4)	54.3
Net Cash Flows from Operating Activities	6,804.3	5,012.2	5,288
INVESTING ACTIVITIES
Construction Expenditures	(7,630.7)	(7,378.3)	(6,671.7)
Other Investing Activities	141.9	122.1	50.3
Net Cash Flows Used for Investing Activities	(7,596.5)	(6,266.7)	(7,751.8)
FINANCING ACTIVITIES
Issuance of Long-term Debt	5,117	5,462.8	4,649.7
Retirement of Long-term Debt	(2,685)	(2,196.1)	(2,345.4)
Net Cash Flows from Financing Activities	659.2	1,077	2,568.9
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(133)	(177.5)	105.1
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	379	556.5	451.4
Cash, Cash Equivalents and Restricted Cash at End of Period	246	379	556.5
SUPPLEMENTARY INFORMATION
Cash Paid for Interest, Net of Capitalized Amounts	1,837.8	1,673.5	1,286.3
Net Cash Paid for Income Taxes	133.4	78.4	116.8
Construction Expenditures Included in Current Liabilities as of December 31,	1,312	842.4	1,258.9
AEP TRANSMISSION COMPANY, LLC
OPERATING ACTIVITIES
Net Income	688.4	614.2	594.2
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities:
Depreciation and Amortization	430.9	393.8	346.2
Deferred Income Taxes	109.6	44.1	62.3
Allowance for Equity Funds Used During Construction	(89.4)	(83.2)	(70.7)
Property Taxes	(22.5)	(19.8)	(20.9)
Change in Other Noncurrent Assets	(0.6)	8.6	(7.4)
Change in Other Noncurrent Liabilities	(17)	134.2	68.7
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	13.4	(41.3)	(46.3)
Materials and Supplies	0	10.7	(1.4)
Accounts Payable	9.5	22.8	18.5
Accrued Taxes, Net	97.3	42.9	50.2
Accrued Interest	5.3	10.8	0
Other Current Assets	(0.4)	(0.1)	(1.1)
Other Current Liabilities	13.3	(0.1)	3
Net Cash Flows from Operating Activities	1,237.8	1,137.6	995.3
INVESTING ACTIVITIES
Construction Expenditures	(1,477.3)	(1,496.2)	(1,458.5)
Change in Advances to Affiliates, Net	36.7	(62.7)	22.8
Acquisitions of Assets	(4.5)	(6.9)	(9.8)
Other Investing Activities	17	8.1	6.3
Net Cash Flows Used for Investing Activities	(1,428.1)	(1,557.7)	(1,439.2)
FINANCING ACTIVITIES
Capital Contribution from Member	61.7	29.7	72.7
Return of Capital to Parent	(4.5)	(8.6)	0
Issuance of Long-term Debt	445.7	689	540.8
Change in Advances from Affiliates, Net	(89.6)	(55)	104.4
Retirement of Long-term Debt	(95)	(60)	(104)
Dividends Paid to Member	(128)	(175)	(170)
Net Cash Flows from Financing Activities	190.3	420.1	443.9
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	0	0	0
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	0	0	0
Cash, Cash Equivalents and Restricted Cash at End of Period	0	0	0
SUPPLEMENTARY INFORMATION
Cash Paid for Interest, Net of Capitalized Amounts	204	179.9	158.8
Net Cash Paid for Income Taxes	42.6	87.6	95.5
Construction Expenditures Included in Current Liabilities as of December 31,	$ 262.7	$ 177.6	$ 320.7

CONSOLIDATED STATEMENTS OF IN_4

CONSOLIDATED STATEMENTS OF INCOME - APCo - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
REVENUES
TOTAL REVENUES	$ 19,721.3	$ 18,982.3	$ 19,639.5
EXPENSES
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	5,936.3	6,578.3	7,097.9
Other Operation	3,127.6	2,810.5	2,878.1
Maintenance	1,325.1	1,276.3	1,249.4
Asset Impairments and Other Related Charges	142.5	85.6	48.8
Establishment of 2017-2019 Virginia Triennial Review Regulatory Asset	0	0	(37)
Depreciation and Amortization	3,289.9	3,090.4	3,202.8
Taxes Other Than Income Taxes	1,596.3	1,492.3	1,469.8
TOTAL EXPENSES	15,417.7	15,426.1	16,156.8
OPERATING INCOME	4,303.6	3,556.2	3,482.7
Other Income (Expense):
Allowance for Equity Funds Used During Construction	211	174.9	133.7
Non-Service Cost Components of Net Periodic Benefit Cost	126	221.1	188.5
Interest Expense	(1,862.8)	(1,806.9)	(1,396.1)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	2,842.9	2,208.7	2,420.4
Income Tax Expense (Benefit)	(39.2)	54.6	5.4
APPALACHIAN POWER COMPANY
REVENUES
TOTAL REVENUES	4,032.6	3,720.7	3,519.9
EXPENSES
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	1,405.6	1,434.6	1,173.9
Other Operation	804.7	748.4	724.1
Maintenance	322.6	271.7	297.8
Asset Impairments and Other Related Charges	0	0	24.9
Establishment of 2017-2019 Virginia Triennial Review Regulatory Asset	0	0	(37)
Depreciation and Amortization	602.4	571.9	575.9
Taxes Other Than Income Taxes	177.5	163.1	158.2
TOTAL EXPENSES	3,312.8	3,189.7	2,917.8
OPERATING INCOME	719.8	531	602.1
Other Income (Expense):
Interest Income	5.1	2.8	3.5
Allowance for Equity Funds Used During Construction	16.1	11.9	11.7
Non-Service Cost Components of Net Periodic Benefit Cost	27.2	32.5	29
Interest Expense	(271.4)	(269.6)	(233.9)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	496.8	308.6	412.4
Income Tax Expense (Benefit)	75.1	14.2	18.2
NET INCOME	421.7	294.4	394.2
Electric Generation, Transmission and Distribution Revenues | APPALACHIAN POWER COMPANY
REVENUES
TOTAL REVENUES	3,769.3	3,464.1	3,245.5
Other Revenues
REVENUES
TOTAL REVENUES	483	458.1	408.2
Other Revenues | APPALACHIAN POWER COMPANY
REVENUES
TOTAL REVENUES	15.9	17.3	18.3
Sales to AEP Affiliates | APPALACHIAN POWER COMPANY | Affiliated Entity
REVENUES
TOTAL REVENUES	$ 247.4	$ 239.3	$ 256.1

CONSOLIDATED STATEMENTS OF CO_5

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - APCo - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES
Cash Flow Hedges, Net of Tax	$ 5	$ (127)	$ 81.4
Amortization of Pension and OPEB Deferred Costs, Tax	2.5	12.6	10.4
Pension and OPEB Funded Status, Net of Tax	41	(16.3)	(155.4)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)	52.4	(139.2)	(101.1)
TOTAL COMPREHENSIVE INCOME ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS	3,019.5	2,068.9	2,206.1
APPALACHIAN POWER COMPANY
Net Income	421.7	294.4	394.2
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES
Cash Flow Hedges, Net of Tax	(0.8)	(0.8)	(0.8)
Amortization of Pension and OPEB Deferred Costs, Tax	1.1	3	4.3
Pension and OPEB Funded Status, Net of Tax	16.9	4.9	(24.1)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)	15	1.1	(29.2)
TOTAL COMPREHENSIVE INCOME ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS	$ 436.7	$ 295.5	$ 365

CONSOLIDATED STATEMENTS OF CO_6

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - APCo (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Cash Flow Hedges, Tax	$ 1.3	$ (33.8)	$ 21.6
Amortization of Pension and OPEB Deferred Costs, Tax	(0.7)	(3.4)	(2.8)
Pension and OPEB Funded Status, Tax	10.9	(4.3)	(41.3)
APPALACHIAN POWER COMPANY
Cash Flow Hedges, Tax	(0.2)	(0.2)	(0.2)
Amortization of Pension and OPEB Deferred Costs, Tax	(0.3)	(0.8)	(1.1)
Pension and OPEB Funded Status, Tax	$ 4.5	$ 1.3	$ (6.4)

CONSOLIDATED STATEMENTS OF CH_5

CONSOLIDATED STATEMENTS OF CHANGES IN COMMON SHAREHOLDER’S EQUITY - APCo - USD ($) $ in Millions	Total	Retained Earnings	[1]	Accumulated Other Comprehensive Income (Loss)	APPALACHIAN POWER COMPANY	APPALACHIAN POWER COMPANY Common Stock	APPALACHIAN POWER COMPANY Paid-in Capital	APPALACHIAN POWER COMPANY Retained Earnings	APPALACHIAN POWER COMPANY Accumulated Other Comprehensive Income (Loss)
Beginning balance at Dec. 31, 2021					$ 4,647.9	$ 260.4	$ 1,828.7	$ 2,534.4	$ 24.4
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock Dividends	$ (1,645.2)	$ (1,628.7)			(37.5)			(37.5)
Net Income					394.2			394.2
Other Comprehensive Income (Loss)	(101.1)			$ (101.1)	(29.2)				(29.2)
Ending balance at Dec. 31, 2022					4,975.4	260.4	1,828.7	2,891.1	(4.8)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contribution from Parent					6.5		6.5
Return of Capital to Parent					(0.7)		(0.7)
Common Stock Dividends	(1,760.4)	(1,752.3)
Net Income					294.4			294.4
Other Comprehensive Income (Loss)	(139.2)			(139.2)	1.1				1.1
Ending balance at Dec. 31, 2023	25,246.7				5,276.7	260.4	1,834.5	3,185.5	(3.7)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contribution from Parent					114.1		114.1
Return of Capital to Parent					(4.5)		(4.5)
Common Stock Dividends	(1,903.9)	$ (1,898.3)			(75)			(75)
Net Income					421.7			421.7
Other Comprehensive Income (Loss)	52.4			$ 52.4	15				15
Ending balance at Dec. 31, 2024	$ 26,943.8				$ 5,748	$ 260.4	$ 1,944.1	$ 3,532.2	$ 11.3
[1]Cash dividends declared per AEP common share were $3.57, $3.37 and $3.17 for the years ended December 31, 2024, 2023 and 2022, respectively.

CONSOLIDATED BALANCE SHEETS -_4

CONSOLIDATED BALANCE SHEETS - APCo - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
CURRENT ASSETS
Cash and Cash Equivalents	$ 202.9	$ 330.1
Restricted Cash for Securitized Funding	43.1	48.9
Accounts Receivable:
Customers	1,100.1	1,029.9
Accrued Unbilled Revenues	367	179.5
Miscellaneous	64.1	48.7
Allowance for Credit Losses	(60.8)	(60.1)
Total Accounts Receivable	2,631.9	2,447.4
Fuel	748.9	853.7
Materials and Supplies	966.2	1,025.8
Risk Management Assets	210.4	217.5
Regulatory Asset for Under-Recovered Fuel Costs	445.9	514
Prepayments and Other Current Assets	285.9	274.2
TOTAL CURRENT ASSETS	5,788.8	6,082.1
PROPERTY, PLANT AND EQUIPMENT
Generation	24,829.7	24,329.5
Transmission	38,871.9	35,934.1
Distribution	31,061.9	28,989.9
Other Property, Plant and Equipment	7,491.6	6,484.9
Construction Work in Progress	6,346.9	5,508
Total Property, Plant and Equipment	108,602	101,246.4
Accumulated Depreciation and Amortization	26,186.4	24,553
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	82,415.6	76,693.4
OTHER NONCURRENT ASSETS
Regulatory Assets	5,129.2	5,092.4
Securitized Assets	554.3	336.3
Operating Lease Assets	580.1	620.2
Deferred Charges and Other Noncurrent Assets	3,873.3	3,625.7
TOTAL OTHER NONCURRENT ASSETS	14,873.6	13,908.5
TOTAL ASSETS	103,078	96,684
CURRENT LIABILITIES
Accounts Payable	2,637.6	2,032.5
Long-term Debt Due Within One Year	3,335	2,490.5
Customer Deposits	454.7	423.7
Accrued Taxes	1,922.1	1,800.1
Obligations Under Operating Leases	91.9	115.7
Other Current Liabilities	1,490.9	1,251.1
TOTAL CURRENT LIABILITIES	13,009.3	11,583.6
NONCURRENT LIABILITIES
Long-term Debt	39,307.8	37,652.7
Deferred Income Taxes	9,972.4	9,415.7
Regulatory Liabilities and Deferred Investment Tax Credits	8,344	8,182.4
Asset Retirement Obligations	3,530.6	2,972.5
Employee Benefits and Pension Obligations	360.7	241.7
Obligations Under Operating Leases	504.3	519.4
Deferred Credits and Other Noncurrent Liabilities	800.6	545.8
TOTAL NONCURRENT LIABILITIES	63,044.8	59,772
TOTAL LIABILITIES	76,054.1	71,355.6
Rate Matters (Note 4)
Commitments and Contingencies (Note 6)
COMMON SHAREHOLDER’S EQUITY
Common Stock	3,471.6	3,427.9
Paid-in Capital	9,606.1	9,073.9
Retained Earnings	13,869.2	12,800.4
Accumulated Other Comprehensive Income (Loss)	(3.1)	(55.5)
TOTAL COMMON SHAREHOLDER’S EQUITY	26,943.8	25,246.7
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	103,078	96,684
APPALACHIAN POWER COMPANY
CURRENT ASSETS
Cash and Cash Equivalents	3.9	5
Restricted Cash for Securitized Funding	16.2	14.9
Advances to Affiliates	17.7	18.9
Accounts Receivable:
Customers	185.7	170.3
Accrued Unbilled Revenues	93.1	70.8
Miscellaneous	0.3	0.6
Allowance for Credit Losses	(2)	(2)
Total Accounts Receivable	387.6	338.5
Fuel	308	315
Materials and Supplies	131.7	148.4
Risk Management Assets	35.7	22.4
Regulatory Asset for Under-Recovered Fuel Costs	148.1	155.4
Prepayments and Other Current Assets	46	40.5
TOTAL CURRENT ASSETS	1,094.9	1,059
PROPERTY, PLANT AND EQUIPMENT
Generation	7,272.6	7,041.3
Transmission	5,001.5	4,711.8
Distribution	5,568.5	5,176.6
Other Property, Plant and Equipment	1,062.9	981.3
Construction Work in Progress	742.6	709.2
Total Property, Plant and Equipment	19,648.1	18,620.2
Accumulated Depreciation and Amortization	6,035.6	5,688.7
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	13,612.5	12,931.5
OTHER NONCURRENT ASSETS
Regulatory Assets	1,366	1,155.1
Securitized Assets	106.2	133.4
Employee Benefits and Pension Assets	203.9	171.7
Operating Lease Assets	67	73.7
Deferred Charges and Other Noncurrent Assets	215.4	187.5
TOTAL OTHER NONCURRENT ASSETS	1,958.5	1,721.4
TOTAL ASSETS	16,665.9	15,711.9
CURRENT LIABILITIES
Accounts Payable	427.2	280.4
Long-term Debt Due Within One Year	798.6	538.8
Customer Deposits	86.6	80
Accrued Taxes	168.8	117.6
Obligations Under Operating Leases	13.7	14.6
Other Current Liabilities	229.7	193.6
TOTAL CURRENT LIABILITIES	2,025.5	1,685.9
NONCURRENT LIABILITIES
Long-term Debt	4,861.7	5,049.5
Deferred Income Taxes	2,033.5	2,011.9
Regulatory Liabilities and Deferred Investment Tax Credits	1,115.8	1,081.9
Asset Retirement Obligations	767.4	442.5
Employee Benefits and Pension Obligations	29.6	32.8
Obligations Under Operating Leases	54	59.8
Deferred Credits and Other Noncurrent Liabilities	30.4	70.9
TOTAL NONCURRENT LIABILITIES	8,892.4	8,749.3
TOTAL LIABILITIES	10,917.9	10,435.2
Rate Matters (Note 4)
Commitments and Contingencies (Note 6)
COMMON SHAREHOLDER’S EQUITY
Common Stock	260.4	260.4
Paid-in Capital	1,944.1	1,834.5
Retained Earnings	3,532.2	3,185.5
Accumulated Other Comprehensive Income (Loss)	11.3	(3.7)
TOTAL COMMON SHAREHOLDER’S EQUITY	5,748	5,276.7
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	16,665.9	15,711.9
APPALACHIAN POWER COMPANY | Affiliated Entity
Accounts Receivable:
Affiliated Companies	110.5	98.8
CURRENT LIABILITIES
Advances from Affiliates	95	339.6
Accounts Payable	$ 205.9	$ 121.3

CONSOLIDATED BALANCE SHEETS -_5

CONSOLIDATED BALANCE SHEETS - APCo (Parenthetical) - shares	Dec. 31, 2024	Dec. 31, 2023
Common Stock – Shares Authorized (in shares)	600,000,000	600,000,000
APPALACHIAN POWER COMPANY
Common Stock – Shares Authorized (in shares)	30,000,000	30,000,000
Common Stock – Shares Outstanding (in shares)	13,499,500	13,499,500

CONSOLIDATED STATEMENTS OF CA_4

CONSOLIDATED STATEMENTS OF CASH FLOWS - APCo - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities:
Depreciation and Amortization	$ 3,289.9	$ 3,090.4	$ 3,202.8
Deferred Income Taxes	58.3	185.1	(137.2)
Asset Impairments and Other Related Charges	142.5	85.6	48.8
Allowance for Equity Funds Used During Construction	(211)	(174.9)	(133.7)
Mark-to-Market of Risk Management Contracts	(80.4)	8.8	15.5
Deferred Fuel Over/Under-Recovery, Net	277	892.8	(319.2)
Change in Regulatory Assets	(174.3)	(315.8)	(46.7)
Establishment of 2017-2019 Virginia Triennial Review Regulatory Asset	0	0	(37)
Change in Other Noncurrent Assets	(347.6)	(465.1)	(187.7)
Change in Other Noncurrent Liabilities	306.3	29	337.8
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(156)	236.5	(681.7)
Fuel, Materials and Supplies	171.6	(504)	(313.9)
Accounts Payable	85.1	(253.2)	489.2
Accrued Taxes, Net	240.2	22.5	105.4
Other Current Assets	(13.2)	(43.9)	109
Other Current Liabilities	182.6	(161.4)	54.3
Net Cash Flows from Operating Activities	6,804.3	5,012.2	5,288
INVESTING ACTIVITIES
Construction Expenditures	(7,630.7)	(7,378.3)	(6,671.7)
Other Investing Activities	141.9	122.1	50.3
Net Cash Flows Used for Investing Activities	(7,596.5)	(6,266.7)	(7,751.8)
FINANCING ACTIVITIES
Issuance of Long-term Debt	5,117	5,462.8	4,649.7
Retirement of Long-term Debt	(2,685)	(2,196.1)	(2,345.4)
Principal Payments for Finance Lease Obligations	(64.8)	(68.3)	(309.5)
Dividends Paid on Common Stock	(1,903.9)	(1,760.4)	(1,645.2)
Other Financing Activities	(49.8)	(78.6)	(105.4)
Net Cash Flows from Financing Activities	659.2	1,077	2,568.9
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(133)	(177.5)	105.1
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	379	556.5	451.4
Cash, Cash Equivalents and Restricted Cash at End of Period	246	379	556.5
SUPPLEMENTARY INFORMATION
Cash Paid for Interest, Net of Capitalized Amounts	1,837.8	1,673.5	1,286.3
Net Cash Paid for Income Taxes	133.4	78.4	116.8
Noncash Acquisitions Under Finance Leases	29.5	48.7	31.8
Construction Expenditures Included in Current Liabilities as of December 31,	1,312	842.4	1,258.9
APPALACHIAN POWER COMPANY
OPERATING ACTIVITIES
Net Income	421.7	294.4	394.2
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities:
Depreciation and Amortization	602.4	571.9	575.9
Deferred Income Taxes	(17.4)	(54.3)	79.6
Asset Impairments and Other Related Charges	0	0	24.9
Allowance for Equity Funds Used During Construction	(16.1)	(11.9)	(11.7)
Mark-to-Market of Risk Management Contracts	(35)	65.6	(24.4)
Deferred Fuel Over/Under-Recovery, Net	136.1	279.7	(501.8)
Change in Regulatory Assets	(114.9)	(19.9)	(34.4)
Establishment of 2017-2019 Virginia Triennial Review Regulatory Asset	0	0	(37)
Change in Other Noncurrent Assets	(46.8)	(95.4)	(40.8)
Change in Other Noncurrent Liabilities	11.9	(1.9)	31.4
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(45.9)	17.5	(8.5)
Fuel, Materials and Supplies	23.7	(173.9)	(113.5)
Margin Deposits	(1.4)	(16.1)	64.4
Accounts Payable	166.2	(125.9)	190.1
Accrued Taxes, Net	50.8	25.2	6.7
Other Current Assets	(3.3)	0.4	0.2
Other Current Liabilities	11.7	(32.3)	5.9
Net Cash Flows from Operating Activities	1,143.7	723.1	601.2
INVESTING ACTIVITIES
Construction Expenditures	(1,009.4)	(1,053)	(1,048.6)
Change in Advances to Affiliates, Net	1.2	0.9	1
Other Investing Activities	15.5	(2.8)	42.4
Net Cash Flows Used for Investing Activities	(992.7)	(1,054.9)	(1,005.2)
FINANCING ACTIVITIES
Capital Contribution from Parent	114.1	6.5	0
Return of Capital to Parent	(4.5)	(0.7)	0
Issuance of Long-term Debt	480.8	200	698
Change in Advances from Affiliates, Net	(244.6)	157.4	(17.1)
Retirement of Long-term Debt	(413.5)	(26.6)	(230.4)
Principal Payments for Finance Lease Obligations	(8.7)	(8.3)	(7.9)
Dividends Paid on Common Stock	(75)	0	(37.5)
Other Financing Activities	0.6	1.5	0.7
Net Cash Flows from Financing Activities	(150.8)	329.8	405.8
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	0.2	(2)	1.8
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	19.9	21.9	20.1
Cash, Cash Equivalents and Restricted Cash at End of Period	20.1	19.9	21.9
SUPPLEMENTARY INFORMATION
Cash Paid for Interest, Net of Capitalized Amounts	256.9	259.7	215.1
Net Cash Paid for Income Taxes	47.8	47.4	(88.6)
Noncash Acquisitions Under Finance Leases	1.8	5	1.6
Construction Expenditures Included in Current Liabilities as of December 31,	$ 159.2	$ 100.7	$ 164.6

CONSOLIDATED STATEMENTS OF IN_5

CONSOLIDATED STATEMENTS OF INCOME - I&M - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
REVENUES
TOTAL REVENUES	$ 19,721.3	$ 18,982.3	$ 19,639.5
EXPENSES
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	5,936.3	6,578.3	7,097.9
Other Operation	3,127.6	2,810.5	2,878.1
Maintenance	1,325.1	1,276.3	1,249.4
Asset Impairments and Other Related Charges	142.5	85.6	48.8
Depreciation and Amortization	3,289.9	3,090.4	3,202.8
Taxes Other Than Income Taxes	1,596.3	1,492.3	1,469.8
TOTAL EXPENSES	15,417.7	15,426.1	16,156.8
OPERATING INCOME	4,303.6	3,556.2	3,482.7
Other Income (Expense):
Other Income	65.1	63.4	11.6
Non-Service Cost Components of Net Periodic Benefit Cost	126	221.1	188.5
Interest Expense	(1,862.8)	(1,806.9)	(1,396.1)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	2,842.9	2,208.7	2,420.4
Income Tax Expense (Benefit)	(39.2)	54.6	5.4
INDIANA MICHIGAN POWER COMPANY
REVENUES
TOTAL REVENUES	2,572	2,535.9	2,669.6
EXPENSES
Other Operation	728.2	662.8	621
Maintenance	235.4	238.7	227.2
Asset Impairments and Other Related Charges	13.4	0	0
Depreciation and Amortization	481.1	470	527.2
Taxes Other Than Income Taxes	89.2	84.2	97
TOTAL EXPENSES	2,172.8	2,048.2	2,249.7
OPERATING INCOME	399.2	487.7	419.9
Other Income (Expense):
Other Income	12.7	12.5	9.3
Non-Service Cost Components of Net Periodic Benefit Cost	17.8	31	24.9
Interest Expense	(133.5)	(136.7)	(125.2)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	296.2	394.5	328.9
Income Tax Expense (Benefit)	(95.2)	58.6	4.2
NET INCOME	391.4	335.9	324.7
INDIANA MICHIGAN POWER COMPANY | Affiliated Entity
EXPENSES
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	208.9	181.2	241.8
INDIANA MICHIGAN POWER COMPANY | Nonrelated Party
EXPENSES
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	416.6	411.3	535.5
Electric Generation, Transmission and Distribution Revenues | INDIANA MICHIGAN POWER COMPANY
REVENUES
TOTAL REVENUES	2,552.3	2,469	2,613.7
Sales to AEP Affiliates | INDIANA MICHIGAN POWER COMPANY | Affiliated Entity
REVENUES
TOTAL REVENUES	15.4	9.3	17.8
Provision for Refund | INDIANA MICHIGAN POWER COMPANY | Affiliated Entity
REVENUES
TOTAL REVENUES	(13.7)	(10.5)	(2.5)
Provision for Refund | INDIANA MICHIGAN POWER COMPANY | Nonrelated Party
REVENUES
TOTAL REVENUES	(56.8)	(3.2)	(25.4)
Other Revenues
REVENUES
TOTAL REVENUES	483	458.1	408.2
Other Revenues | INDIANA MICHIGAN POWER COMPANY | Affiliated Entity
REVENUES
TOTAL REVENUES	64.5	59	54.3
Other Revenues | INDIANA MICHIGAN POWER COMPANY | Nonrelated Party
REVENUES
TOTAL REVENUES	$ 10.3	$ 12.3	$ 11.7

CONSOLIDATED STATEMENTS OF CO_7

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - I&M - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES
Cash Flow Hedges, Net of Tax	$ 5	$ (127)	$ 81.4
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(2.5)	(12.6)	(10.4)
Pension and OPEB Funded Status, Net of Tax	41	(16.3)	(155.4)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)	52.4	(139.2)	(101.1)
TOTAL COMPREHENSIVE INCOME ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS	3,019.5	2,068.9	2,206.1
INDIANA MICHIGAN POWER COMPANY
Net Income	391.4	335.9	324.7
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES
Cash Flow Hedges, Net of Tax	0.4	(0.4)	1.6
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(0.2)	(0.9)	(0.3)
Pension and OPEB Funded Status, Net of Tax	0.6	1	(0.3)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)	0.8	(0.3)	1
TOTAL COMPREHENSIVE INCOME ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS	$ 392.2	$ 335.6	$ 325.7

CONSOLIDATED STATEMENTS OF CO_8

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - I&M (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Cash Flow Hedges, Tax	$ 1.3	$ (33.8)	$ 21.6
Amortization of Pension and OPEB Deferred Costs, Tax	(0.7)	(3.4)	(2.8)
Pension and OPEB Funded Status, Tax	10.9	(4.3)	(41.3)
INDIANA MICHIGAN POWER COMPANY
Cash Flow Hedges, Tax	0.1	(0.1)	0.4
Amortization of Pension and OPEB Deferred Costs, Tax	0	(0.2)	(0.1)
Pension and OPEB Funded Status, Tax	$ 0.2	$ 0.3	$ (0.1)

CONSOLIDATED STATEMENTS OF CH_6

CONSOLIDATED STATEMENTS OF CHANGES IN COMMON SHAREHOLDER’S EQUITY - I&M - USD ($) $ in Millions	Total	Retained Earnings	[1]	Accumulated Other Comprehensive Income (Loss)	INDIANA MICHIGAN POWER COMPANY	INDIANA MICHIGAN POWER COMPANY Common Stock	INDIANA MICHIGAN POWER COMPANY Paid-in Capital	INDIANA MICHIGAN POWER COMPANY Retained Earnings	INDIANA MICHIGAN POWER COMPANY Accumulated Other Comprehensive Income (Loss)
Beginning balance at Dec. 31, 2021					$ 2,784.7	$ 56.6	$ 980.9	$ 1,748.5	$ (1.3)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contribution from Parent					7.9		7.9
Common Stock Dividends	$ (1,645.2)	$ (1,628.7)			(110)			(110)
Net Income					324.7			324.7
Other Comprehensive Income (Loss)	(101.1)			$ (101.1)	1				1
Ending balance at Dec. 31, 2022					3,008.3	56.6	988.8	1,963.2	(0.3)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contribution from Parent					8.8		8.8
Common Stock Dividends	(1,760.4)	(1,752.3)			(212.5)			(212.5)
Net Income					335.9			335.9
Other Comprehensive Income (Loss)	(139.2)			(139.2)	(0.3)				(0.3)
Ending balance at Dec. 31, 2023	25,246.7				3,140.2	56.6	997.6	2,086.6	(0.6)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contribution from Parent					15.9		15.9
Return of Capital to Parent					(1.8)		(1.8)
Common Stock Dividends	(1,903.9)	$ (1,898.3)			(150)			(150)
Net Income					391.4			391.4
Other Comprehensive Income (Loss)	52.4			$ 52.4	0.8				0.8
Ending balance at Dec. 31, 2024	$ 26,943.8				$ 3,396.5	$ 56.6	$ 1,011.7	$ 2,328	$ 0.2
[1]Cash dividends declared per AEP common share were $3.57, $3.37 and $3.17 for the years ended December 31, 2024, 2023 and 2022, respectively.

CONSOLIDATED BALANCE SHEETS - I

CONSOLIDATED BALANCE SHEETS - I&M - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
CURRENT ASSETS
Cash and Cash Equivalents	$ 202.9	$ 330.1
Accounts Receivable:
Customers	1,100.1	1,029.9
Accrued Unbilled Revenues	367	179.5
Miscellaneous	64.1	48.7
Total Accounts Receivable	2,631.9	2,447.4
Fuel	748.9	853.7
Materials and Supplies	966.2	1,025.8
Risk Management Assets	210.4	217.5
Regulatory Asset for Under-Recovered Fuel Costs	445.9	514
Prepayments and Other Current Assets	285.9	274.2
TOTAL CURRENT ASSETS	5,788.8	6,082.1
PROPERTY, PLANT AND EQUIPMENT
Generation	24,829.7	24,329.5
Transmission	38,871.9	35,934.1
Distribution	31,061.9	28,989.9
Other Property, Plant and Equipment (Including Coal Mining and Nuclear Fuel)	7,491.6	6,484.9
Construction Work in Progress	6,346.9	5,508
Total Property, Plant and Equipment	108,602	101,246.4
Accumulated Depreciation and Amortization	26,186.4	24,553
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	82,415.6	76,693.4
OTHER NONCURRENT ASSETS
Regulatory Assets	5,129.2	5,092.4
Spent Nuclear Fuel and Decommissioning Trusts	4,395.1	3,860.2
Operating Lease Assets	580.1	620.2
Deferred Charges and Other Noncurrent Assets	3,873.3	3,625.7
TOTAL OTHER NONCURRENT ASSETS	14,873.6	13,908.5
TOTAL ASSETS	103,078	96,684
CURRENT LIABILITIES
Accounts Payable	2,637.6	2,032.5
Long-term Debt Due Within One Year	3,335	2,490.5
Customer Deposits	454.7	423.7
Accrued Taxes	1,922.1	1,800.1
Accrued Interest	453.3	410.2
Obligations Under Operating Leases	91.9	115.7
Other Current Liabilities	1,490.9	1,251.1
TOTAL CURRENT LIABILITIES	13,009.3	11,583.6
NONCURRENT LIABILITIES
Long-term Debt	39,307.8	37,652.7
Deferred Income Taxes	9,972.4	9,415.7
Regulatory Liabilities and Deferred Investment Tax Credits	8,344	8,182.4
Asset Retirement Obligations	3,530.6	2,972.5
Obligations Under Operating Leases	504.3	519.4
Deferred Credits and Other Noncurrent Liabilities	800.6	545.8
TOTAL NONCURRENT LIABILITIES	63,044.8	59,772
TOTAL LIABILITIES	76,054.1	71,355.6
Rate Matters (Note 4)
Commitments and Contingencies (Note 6)
COMMON SHAREHOLDER’S EQUITY
Common Stock	3,471.6	3,427.9
Paid-in Capital	9,606.1	9,073.9
Retained Earnings	13,869.2	12,800.4
Accumulated Other Comprehensive Income (Loss)	(3.1)	(55.5)
TOTAL COMMON SHAREHOLDER’S EQUITY	26,943.8	25,246.7
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	103,078	96,684
INDIANA MICHIGAN POWER COMPANY
CURRENT ASSETS
Cash and Cash Equivalents	1.5	2.1
Accounts Receivable:
Customers	58.7	66.9
Accrued Unbilled Revenues	21.4	0.2
Miscellaneous	6.3	8.2
Total Accounts Receivable	165.5	140.3
Fuel	83.4	88.1
Materials and Supplies	212.2	208.2
Risk Management Assets	18.4	27.8
Regulatory Asset for Under-Recovered Fuel Costs	10.6	14.8
Prepayments and Other Current Assets	52	46.7
TOTAL CURRENT ASSETS	543.6	528
PROPERTY, PLANT AND EQUIPMENT
Generation	5,503	5,646.8
Transmission	1,957.8	1,906.4
Distribution	3,535	3,254
Other Property, Plant and Equipment (Including Coal Mining and Nuclear Fuel)	992.4	898.5
Construction Work in Progress	334.9	301.7
Total Property, Plant and Equipment	12,323.1	12,007.4
Accumulated Depreciation and Amortization	4,643.8	4,378.4
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	7,679.3	7,629
OTHER NONCURRENT ASSETS
Regulatory Assets	548.1	406.3
Spent Nuclear Fuel and Decommissioning Trusts	4,395.1	3,860.2
Operating Lease Assets	51.5	53.8
Deferred Charges and Other Noncurrent Assets	317.9	330.7
TOTAL OTHER NONCURRENT ASSETS	5,312.6	4,651
TOTAL ASSETS	13,535.5	12,808
CURRENT LIABILITIES
Accounts Payable	202.2	225.8
Long-term Debt Due Within One Year	269.2	83.7
Customer Deposits	59.1	72.2
Accrued Taxes	102.2	104.7
Accrued Interest	41.3	41.3
Obligations Under Operating Leases	12.3	16.8
Regulatory Liability for Over-Recovered Fuel Costs	10.3	23.2
Other Current Liabilities	149.3	91.9
TOTAL CURRENT LIABILITIES	1,071.2	830.2
NONCURRENT LIABILITIES
Long-term Debt	3,225.1	3,415.7
Deferred Income Taxes	1,175.8	1,169.9
Regulatory Liabilities and Deferred Investment Tax Credits	2,480.8	2,052.3
Asset Retirement Obligations	2,088.8	2,104.3
Obligations Under Operating Leases	40.1	37.7
Deferred Credits and Other Noncurrent Liabilities	57.2	57.7
TOTAL NONCURRENT LIABILITIES	9,067.8	8,837.6
TOTAL LIABILITIES	10,139	9,667.8
Rate Matters (Note 4)
Commitments and Contingencies (Note 6)
COMMON SHAREHOLDER’S EQUITY
Common Stock	56.6	56.6
Paid-in Capital	1,011.7	997.6
Retained Earnings	2,328	2,086.6
Accumulated Other Comprehensive Income (Loss)	0.2	(0.6)
TOTAL COMMON SHAREHOLDER’S EQUITY	3,396.5	3,140.2
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	13,535.5	12,808
INDIANA MICHIGAN POWER COMPANY | Affiliated Entity
Accounts Receivable:
Affiliated Companies	79.1	65
CURRENT LIABILITIES
Advances from Affiliates	126.8	63.3
Accounts Payable	$ 98.5	$ 107.3

CONSOLIDATED BALANCE SHEETS -_6

CONSOLIDATED BALANCE SHEETS - I&M (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Common Stock – Shares Authorized (in shares)	600,000,000	600,000,000
Long-term Debt Due Within One Year – Nonaffiliated	$ 3,335	$ 2,490.5
INDIANA MICHIGAN POWER COMPANY
Common Stock – Shares Authorized (in shares)	2,500,000	2,500,000
Common Stock – Shares Outstanding (in shares)	1,400,000	1,400,000
Long-term Debt Due Within One Year – Nonaffiliated	$ 269.2	$ 83.7
INDIANA MICHIGAN POWER COMPANY | DCC Fuel
Long-term Debt Due Within One Year – Nonaffiliated	$ 79	$ 81.4

CONSOLIDATED STATEMENTS OF CA_5

CONSOLIDATED STATEMENTS OF CASH FLOWS - I&M - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities:
Depreciation and Amortization	$ 3,289.9	$ 3,090.4	$ 3,202.8
Deferred Income Taxes	58.3	185.1	(137.2)
Asset Impairments and Other Related Charges	142.5	85.6	48.8
Allowance for Equity Funds Used During Construction	(211)	(174.9)	(133.7)
Mark-to-Market of Risk Management Contracts	(80.4)	8.8	15.5
Amortization of Nuclear Fuel	102.9	96.6	82.9
Deferred Fuel Over/Under-Recovery, Net	277	892.8	(319.2)
Change in Other Noncurrent Assets	(347.6)	(465.1)	(187.7)
Change in Other Noncurrent Liabilities	306.3	29	337.8
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(156)	236.5	(681.7)
Fuel, Materials and Supplies	171.6	(504)	(313.9)
Accounts Payable	85.1	(253.2)	489.2
Accrued Taxes, Net	240.2	22.5	105.4
Other Current Assets	(13.2)	(43.9)	109
Other Current Liabilities	182.6	(161.4)	54.3
Net Cash Flows from Operating Activities	6,804.3	5,012.2	5,288
INVESTING ACTIVITIES
Construction Expenditures	(7,630.7)	(7,378.3)	(6,671.7)
Purchases of Investment Securities	(2,922.5)	(2,863.6)	(2,784.2)
Sales of Investment Securities	2,878	2,795.1	2,743.8
Acquisitions of Nuclear Fuel	(139.9)	(128.2)	(100.7)
Other Investing Activities	141.9	122.1	50.3
Net Cash Flows Used for Investing Activities	(7,596.5)	(6,266.7)	(7,751.8)
FINANCING ACTIVITIES
Issuance of Long-term Debt	5,117	5,462.8	4,649.7
Retirement of Long-term Debt	(2,685)	(2,196.1)	(2,345.4)
Principal Payments for Finance Lease Obligations	(64.8)	(68.3)	(309.5)
Dividends Paid on Common Stock	(1,903.9)	(1,760.4)	(1,645.2)
Other Financing Activities	(49.8)	(78.6)	(105.4)
Net Cash Flows from Financing Activities	659.2	1,077	2,568.9
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(133)	(177.5)	105.1
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	379	556.5	451.4
Cash, Cash Equivalents and Restricted Cash at End of Period	246	379	556.5
SUPPLEMENTARY INFORMATION
Cash Paid for Interest, Net of Capitalized Amounts	1,837.8	1,673.5	1,286.3
Net Cash Paid for Income Taxes	133.4	78.4	116.8
Noncash Acquisitions Under Finance Leases	29.5	48.7	31.8
Construction Expenditures Included in Current Liabilities as of December 31,	1,312	842.4	1,258.9
Acquisition of Nuclear Fuel Included in Current Liabilities as of December 31,	23.5	24.2	0
INDIANA MICHIGAN POWER COMPANY
OPERATING ACTIVITIES
Net Income	391.4	335.9	324.7
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities:
Depreciation and Amortization	481.1	470	527.2
Deferred Income Taxes	(117)	(54.1)	(45.1)
Amortization (Deferral) of Incremental Nuclear Refueling Outage Expenses, Net	12.6	25.6	(49.2)
Asset Impairments and Other Related Charges	13.4	0	0
Allowance for Equity Funds Used During Construction	(13.3)	(10.9)	(9.8)
Mark-to-Market of Risk Management Contracts	19.8	(22.2)	(16.9)
Amortization of Nuclear Fuel	102.9	96.6	82.9
Deferred Fuel Over/Under-Recovery, Net	(8.7)	55.5	(42.2)
Change in Other Noncurrent Assets	(16.9)	(80.3)	(47.3)
Change in Other Noncurrent Liabilities	40	47.6	62.4
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(23.1)	71.4	(82.7)
Fuel, Materials and Supplies	0.7	(61.4)	(2.6)
Accounts Payable	(45.3)	22.5	37.3
Accrued Taxes, Net	(2.5)	1.5	9.4
Other Current Assets	1.5	(6.2)	19.5
Other Current Liabilities	32.3	(11.6)	(46.9)
Net Cash Flows from Operating Activities	868.9	879.9	720.7
INVESTING ACTIVITIES
Construction Expenditures	(583)	(550.3)	(557.8)
Change in Advances to Affiliates, Net	0	23	(1.5)
Purchases of Investment Securities	(2,902.4)	(2,845.1)	(2,765.4)
Sales of Investment Securities	2,851.2	2,787.5	2,713.6
Acquisitions of Nuclear Fuel	(139.9)	(128.2)	(100.7)
Other Investing Activities	6.4	6.1	10.3
Net Cash Flows Used for Investing Activities	(767.7)	(707)	(701.5)
FINANCING ACTIVITIES
Capital Contribution from Parent	15.9	8.8	7.9
Return of Capital to Parent	(1.8)	0	0
Issuance of Long-term Debt	80.4	565.3	142.7
Change in Advances from Affiliates, Net	63.5	(186.6)	156.6
Retirement of Long-term Debt	(103.4)	(343.3)	(83.4)
Principal Payments for Finance Lease Obligations	(7.1)	(7.4)	(130.7)
Dividends Paid on Common Stock	(150)	(212.5)	(110)
Other Financing Activities	0.7	0.7	0.6
Net Cash Flows from Financing Activities	(101.8)	(175)	(16.3)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(0.6)	(2.1)	2.9
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	2.1	4.2	1.3
Cash, Cash Equivalents and Restricted Cash at End of Period	1.5	2.1	4.2
SUPPLEMENTARY INFORMATION
Cash Paid for Interest, Net of Capitalized Amounts	144.1	131.6	120.9
Net Cash Paid for Income Taxes	24	109	10.1
Noncash Acquisitions Under Finance Leases	1.3	4.8	2.2
Construction Expenditures Included in Current Liabilities as of December 31,	77.2	67.8	71.9
Acquisition of Nuclear Fuel Included in Current Liabilities as of December 31,	$ 23.5	$ 24.2	$ 0

CONSOLIDATED STATEMENTS OF IN_6

CONSOLIDATED STATEMENTS OF INCOME - OPCo - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
REVENUES
TOTAL REVENUES	$ 19,721.3	$ 18,982.3	$ 19,639.5
EXPENSES
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	5,936.3	6,578.3	7,097.9
Other Operation	3,127.6	2,810.5	2,878.1
Maintenance	1,325.1	1,276.3	1,249.4
Asset Impairments and Other Related Charges	142.5	85.6	48.8
Depreciation and Amortization	3,289.9	3,090.4	3,202.8
Taxes Other Than Income Taxes	1,596.3	1,492.3	1,469.8
TOTAL EXPENSES	15,417.7	15,426.1	16,156.8
OPERATING INCOME	4,303.6	3,556.2	3,482.7
Other Income (Expense):
Other Income	65.1	63.4	11.6
Allowance for Equity Funds Used During Construction	211	174.9	133.7
Non-Service Cost Components of Net Periodic Benefit Cost	126	221.1	188.5
Interest Expense	(1,862.8)	(1,806.9)	(1,396.1)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	2,842.9	2,208.7	2,420.4
Income Tax Expense (Benefit)	(39.2)	54.6	5.4
Equity Earnings (Loss) of Unconsolidated Subsidiaries	93.7	58.5	(109.4)
OHIO POWER COMPANY
REVENUES
TOTAL REVENUES	3,827.8	3,811.4	3,665.1
EXPENSES
Other Operation	1,198.3	1,091.7	982
Maintenance	256.3	211.5	185.5
Asset Impairments and Other Related Charges	52.9	0	0
Depreciation and Amortization	386	316.2	294.3
Taxes Other Than Income Taxes	560.2	507.3	502.4
TOTAL EXPENSES	3,362.8	3,341.5	3,251.4
OPERATING INCOME	465	469.9	413.7
Other Income (Expense):
Other Income	3.4	0.4	1.3
Allowance for Equity Funds Used During Construction	23.4	17.1	13.9
Non-Service Cost Components of Net Periodic Benefit Cost	15.3	26	22.1
Interest Expense	(148)	(130.9)	(119.6)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	359.1	382.5	331.4
Income Tax Expense (Benefit)	52.4	54.3	44.2
Equity Earnings (Loss) of Unconsolidated Subsidiaries	(1.1)	0	0.6
NET INCOME	305.6	328.2	287.8
OHIO POWER COMPANY | Affiliated Entity
EXPENSES
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	97.8	86.8	9.8
OHIO POWER COMPANY | Nonrelated Party
EXPENSES
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	811.3	1,128	1,277.4
Electricity, Transmission and Distribution | OHIO POWER COMPANY
REVENUES
TOTAL REVENUES	3,793	3,768	3,635.3
Sales to AEP Affiliates | OHIO POWER COMPANY | Affiliated Entity
REVENUES
TOTAL REVENUES	22.7	31.1	18.8
Other Revenues
REVENUES
TOTAL REVENUES	483	458.1	408.2
Other Revenues | OHIO POWER COMPANY
REVENUES
TOTAL REVENUES	$ 12.1	$ 12.3	$ 11

CONSOLIDATED STATEMENTS OF CH_7

CONSOLIDATED STATEMENTS OF CHANGES IN COMMON SHAREHOLDER’S EQUITY - OPCo - USD ($) $ in Millions	Total	Retained Earnings	[1]	OHIO POWER COMPANY	OHIO POWER COMPANY Common Stock	OHIO POWER COMPANY Paid-in Capital	OHIO POWER COMPANY Retained Earnings
Beginning balance at Dec. 31, 2021				$ 2,846.3	$ 321.2	$ 838.8	$ 1,686.3
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contribution from Parent				1		1
Return of Capital to Parent				(2)		(2)
Common Stock Dividends	$ (1,645.2)	$ (1,628.7)		(45)			(45)
Net Income				287.8			287.8
Ending balance at Dec. 31, 2022				3,088.1	321.2	837.8	1,929.1
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contribution from Parent				175		175
Common Stock Dividends	(1,760.4)	(1,752.3)		(20)			(20)
Net Income				328.2			328.2
Ending balance at Dec. 31, 2023	25,246.7			3,571.3	321.2	1,012.8	2,237.3
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contribution from Parent				7.2		7.2
Common Stock Dividends	(1,903.9)	$ (1,898.3)
Net Income				305.6			305.6
Ending balance at Dec. 31, 2024	$ 26,943.8			$ 3,884.1	$ 321.2	$ 1,020	$ 2,542.9
[1]Cash dividends declared per AEP common share were $3.57, $3.37 and $3.17 for the years ended December 31, 2024, 2023 and 2022, respectively.

CONSOLIDATED BALANCE SHEETS - O

CONSOLIDATED BALANCE SHEETS - OPCo - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
CURRENT ASSETS
Cash and Cash Equivalents	$ 202.9	$ 330.1
Accounts Receivable:
Customers	1,100.1	1,029.9
Accrued Unbilled Revenues	367	179.5
Miscellaneous	64.1	48.7
Total Accounts Receivable	2,631.9	2,447.4
Materials and Supplies	966.2	1,025.8
Prepayments and Other Current Assets	285.9	274.2
TOTAL CURRENT ASSETS	5,788.8	6,082.1
PROPERTY, PLANT AND EQUIPMENT
Transmission	38,871.9	35,934.1
Distribution	31,061.9	28,989.9
Other Property, Plant and Equipment	7,491.6	6,484.9
Construction Work in Progress	6,346.9	5,508
Total Property, Plant and Equipment	108,602	101,246.4
Accumulated Depreciation and Amortization	26,186.4	24,553
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	82,415.6	76,693.4
OTHER NONCURRENT ASSETS
Regulatory Assets	5,129.2	5,092.4
Operating Lease Assets	580.1	620.2
Deferred Charges and Other Noncurrent Assets	3,873.3	3,625.7
TOTAL OTHER NONCURRENT ASSETS	14,873.6	13,908.5
TOTAL ASSETS	103,078	96,684
CURRENT LIABILITIES
Accounts Payable	2,637.6	2,032.5
Risk Management Liabilities	100	229.6
Customer Deposits	454.7	423.7
Accrued Taxes	1,922.1	1,800.1
Obligations Under Operating Leases	91.9	115.7
Other Current Liabilities	1,490.9	1,251.1
TOTAL CURRENT LIABILITIES	13,009.3	11,583.6
NONCURRENT LIABILITIES
Long-term Debt	39,307.8	37,652.7
Long-term Risk Management Liabilities	224.4	241.8
Deferred Income Taxes	9,972.4	9,415.7
Regulatory Liabilities and Deferred Investment Tax Credits	8,344	8,182.4
Obligations Under Operating Leases	504.3	519.4
Deferred Credits and Other Noncurrent Liabilities	800.6	545.8
TOTAL NONCURRENT LIABILITIES	63,044.8	59,772
TOTAL LIABILITIES	76,054.1	71,355.6
Rate Matters (Note 4)
Commitments and Contingencies (Note 6)
COMMON SHAREHOLDER’S EQUITY
Common Stock	3,471.6	3,427.9
Paid-in Capital	9,606.1	9,073.9
Retained Earnings	13,869.2	12,800.4
TOTAL COMMON SHAREHOLDER’S EQUITY	26,943.8	25,246.7
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	103,078	96,684
OHIO POWER COMPANY
CURRENT ASSETS
Cash and Cash Equivalents	4.5	6.4
Accounts Receivable:
Customers	189.2	39.2
Accrued Unbilled Revenues	31.1	0
Miscellaneous	8.6	2.3
Total Accounts Receivable	346.4	170.7
Materials and Supplies	141.4	175
Renewable Energy Credits	0	8.9
Prepayments and Other Current Assets	19.9	16.8
TOTAL CURRENT ASSETS	627.1	377.8
PROPERTY, PLANT AND EQUIPMENT
Transmission	3,663.9	3,395.1
Distribution	7,244	6,839.4
Other Property, Plant and Equipment	1,256	1,125
Construction Work in Progress	691.1	654
Total Property, Plant and Equipment	12,855	12,013.5
Accumulated Depreciation and Amortization	2,883.9	2,713.6
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	9,971.1	9,299.9
OTHER NONCURRENT ASSETS
Regulatory Assets	379.1	455
Operating Lease Assets	60.4	69.9
Deferred Charges and Other Noncurrent Assets	661	641.1
TOTAL OTHER NONCURRENT ASSETS	1,100.5	1,166
TOTAL ASSETS	11,698.7	10,843.7
CURRENT LIABILITIES
Accounts Payable	343.6	320.7
Risk Management Liabilities	7.3	6.8
Customer Deposits	108.1	62
Accrued Taxes	836.1	763.3
Obligations Under Operating Leases	12.3	13.5
Other Current Liabilities	182.2	183.3
TOTAL CURRENT LIABILITIES	1,694.5	1,614.3
NONCURRENT LIABILITIES
Long-term Debt	3,715.7	3,366.8
Long-term Risk Management Liabilities	40.2	43.9
Deferred Income Taxes	1,201.1	1,152.7
Regulatory Liabilities and Deferred Investment Tax Credits	987.7	1,003.6
Obligations Under Operating Leases	48.4	56.7
Deferred Credits and Other Noncurrent Liabilities	127	34.4
TOTAL NONCURRENT LIABILITIES	6,120.1	5,658.1
TOTAL LIABILITIES	7,814.6	7,272.4
Rate Matters (Note 4)
Commitments and Contingencies (Note 6)
COMMON SHAREHOLDER’S EQUITY
Common Stock	321.2	321.2
Paid-in Capital	1,020	1,012.8
Retained Earnings	2,542.9	2,237.3
TOTAL COMMON SHAREHOLDER’S EQUITY	3,884.1	3,571.3
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	11,698.7	10,843.7
OHIO POWER COMPANY | Affiliated Entity
CURRENT ASSETS
Advances to Affiliates	114.9	0
Accounts Receivable:
Affiliated Companies	117.5	129.2
CURRENT LIABILITIES
Advances from Affiliates	0	110.5
Accounts Payable	$ 204.9	$ 154.2

CONSOLIDATED BALANCE SHEETS -_7

CONSOLIDATED BALANCE SHEETS - OPCo (Parenthetical) - shares	Dec. 31, 2024	Dec. 31, 2023
Common Stock – Shares Authorized (in shares)	600,000,000	600,000,000
OHIO POWER COMPANY
Common Stock – Shares Authorized (in shares)	40,000,000	40,000,000
Common Stock – Shares Outstanding (in shares)	27,952,473	27,952,473

CONSOLIDATED STATEMENTS OF CA_6

CONSOLIDATED STATEMENTS OF CASH FLOWS - OPCo - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities:
Depreciation and Amortization	$ 3,289.9	$ 3,090.4	$ 3,202.8
Deferred Income Taxes	58.3	185.1	(137.2)
Asset Impairments and Other Related Charges	142.5	85.6	48.8
Allowance for Equity Funds Used During Construction	(211)	(174.9)	(133.7)
Mark-to-Market of Risk Management Contracts	(80.4)	8.8	15.5
Property Taxes	(45.4)	(41.1)	(41.2)
Change in Regulatory Assets	(174.3)	(315.8)	(46.7)
Change in Other Noncurrent Assets	(347.6)	(465.1)	(187.7)
Change in Other Noncurrent Liabilities	306.3	29	337.8
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(156)	236.5	(681.7)
Materials and Supplies	171.6	(504)	(313.9)
Accounts Payable	85.1	(253.2)	489.2
Accrued Taxes, Net	240.2	22.5	105.4
Other Current Assets	(13.2)	(43.9)	109
Other Current Liabilities	182.6	(161.4)	54.3
Net Cash Flows from Operating Activities	6,804.3	5,012.2	5,288
INVESTING ACTIVITIES
Construction Expenditures	(7,630.7)	(7,378.3)	(6,671.7)
Other Investing Activities	141.9	122.1	50.3
Net Cash Flows Used for Investing Activities	(7,596.5)	(6,266.7)	(7,751.8)
FINANCING ACTIVITIES
Issuance of Long-term Debt	5,117	5,462.8	4,649.7
Retirement of Long-term Debt	(2,685)	(2,196.1)	(2,345.4)
Principal Payments for Finance Lease Obligations	(64.8)	(68.3)	(309.5)
Dividends Paid on Common Stock	(1,903.9)	(1,760.4)	(1,645.2)
Other Financing Activities	(49.8)	(78.6)	(105.4)
Net Cash Flows from Financing Activities	659.2	1,077	2,568.9
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(133)	(177.5)	105.1
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	379	556.5	451.4
Cash, Cash Equivalents and Restricted Cash at End of Period	246	379	556.5
SUPPLEMENTARY INFORMATION
Cash Paid for Interest, Net of Capitalized Amounts	1,837.8	1,673.5	1,286.3
Net Cash Paid (Received) for Income Taxes	133.4	78.4	116.8
Noncash Acquisitions Under Finance Leases	29.5	48.7	31.8
Construction Expenditures Included in Current Liabilities as of December 31,	1,312	842.4	1,258.9
OHIO POWER COMPANY
OPERATING ACTIVITIES
Net Income	305.6	328.2	287.8
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities:
Depreciation and Amortization	386	316.2	294.3
Deferred Income Taxes	7.8	7.9	71.5
Asset Impairments and Other Related Charges	52.9	0	0
Allowance for Equity Funds Used During Construction	(23.4)	(17.1)	(13.9)
Mark-to-Market of Risk Management Contracts	(3.2)	11	(52.8)
Property Taxes	(24.5)	(11.5)	(20)
Change in Regulatory Assets	45.4	(90.9)	30.4
Change in Other Noncurrent Assets	(37.8)	(137.5)	(87.1)
Change in Other Noncurrent Liabilities	57.9	(0.4)	91.1
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(169.8)	72.8	(83.7)
Materials and Supplies	54.8	(6.9)	(23.4)
Accounts Payable	6.7	23.6	112.7
Accrued Taxes, Net	75.9	27.5	27.8
Other Current Assets	(7.2)	0.4	11.2
Other Current Liabilities	43.1	(61)	40.2
Net Cash Flows from Operating Activities	770.2	462.3	686.1
INVESTING ACTIVITIES
Construction Expenditures	(930.1)	(990.4)	(872.4)
Change in Advances to Affiliates, Net	(114.9)	0	42
Other Investing Activities	34	41	27.9
Net Cash Flows Used for Investing Activities	(1,011)	(949.4)	(802.5)
FINANCING ACTIVITIES
Capital Contribution from Parent	7.2	175	1
Return of Capital to Parent	0	0	(2)
Issuance of Long-term Debt	346.2	395	0
Change in Advances from Affiliates, Net	(110.5)	(62.4)	172.9
Retirement of Long-term Debt	0	(0.6)	(0.1)
Principal Payments for Finance Lease Obligations	(5.3)	(5)	(4.9)
Dividends Paid on Common Stock	0	(20)	(45)
Other Financing Activities	1.3	1.9	1.1
Net Cash Flows from Financing Activities	238.9	483.9	123
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(1.9)	(3.2)	6.6
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	6.4	9.6	3
Cash, Cash Equivalents and Restricted Cash at End of Period	4.5	6.4	9.6
SUPPLEMENTARY INFORMATION
Cash Paid for Interest, Net of Capitalized Amounts	138.8	124.1	113.4
Net Cash Paid (Received) for Income Taxes	18.9	38.9	(19.7)
Noncash Acquisitions Under Finance Leases	1.5	4.1	3
Construction Expenditures Included in Current Liabilities as of December 31,	$ 157.9	$ 97.7	$ 109.7

CONSOLIDATED STATEMENTS OF IN_7

CONSOLIDATED STATEMENTS OF INCOME - PSO - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
REVENUES
TOTAL REVENUES	$ 19,721.3	$ 18,982.3	$ 19,639.5
EXPENSES
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	5,936.3	6,578.3	7,097.9
Other Operation	3,127.6	2,810.5	2,878.1
Maintenance	1,325.1	1,276.3	1,249.4
Depreciation and Amortization	3,289.9	3,090.4	3,202.8
Taxes Other Than Income Taxes	1,596.3	1,492.3	1,469.8
TOTAL EXPENSES	15,417.7	15,426.1	16,156.8
OPERATING INCOME	4,303.6	3,556.2	3,482.7
Other Income (Expense):
Allowance for Equity Funds Used During Construction	211	174.9	133.7
Non-Service Cost Components of Net Periodic Benefit Cost	126	221.1	188.5
Interest Expense	(1,862.8)	(1,806.9)	(1,396.1)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	2,842.9	2,208.7	2,420.4
Income Tax Expense (Benefit)	(39.2)	54.6	5.4
PUBLIC SERVICE COMPANY OF OKLAHOMA
REVENUES
TOTAL REVENUES	1,846.4	1,977	1,874.7
EXPENSES
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	742.5	955.3	891.5
Other Operation	416.8	355.8	400.4
Maintenance	113	112	114.4
Depreciation and Amortization	272.2	255.5	230.1
Taxes Other Than Income Taxes	77.3	64.1	57.5
TOTAL EXPENSES	1,621.8	1,742.7	1,693.9
OPERATING INCOME	224.6	234.3	180.8
Other Income (Expense):
Interest Income	1.8	1.8	7.4
Allowance for Equity Funds Used During Construction	7.4	8.4	1.5
Non-Service Cost Components of Net Periodic Benefit Cost	11.2	14.3	12.5
Interest Expense	(95.3)	(103.6)	(83.8)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	149.7	155.2	118.4
Income Tax Expense (Benefit)	(99.6)	(53.6)	(49.2)
NET INCOME	249.3	208.8	167.6
Electric Generation, Transmission and Distribution Revenues | PUBLIC SERVICE COMPANY OF OKLAHOMA
REVENUES
TOTAL REVENUES	1,820	1,968.4	1,865.6
Sales to AEP Affiliates | PUBLIC SERVICE COMPANY OF OKLAHOMA | Affiliated Entity
REVENUES
TOTAL REVENUES	6.9	1.2	2.9
Other Revenues
REVENUES
TOTAL REVENUES	483	458.1	408.2
Other Revenues | PUBLIC SERVICE COMPANY OF OKLAHOMA
REVENUES
TOTAL REVENUES	$ 19.5	$ 7.4	$ 6.2

CONSOLIDATED STATEMENTS OF CO_9

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - PSO - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES
Cash Flow Hedges, Net of Tax	$ 5	$ (127)	$ 81.4
TOTAL COMPREHENSIVE INCOME ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS	3,019.5	2,068.9	2,206.1
PUBLIC SERVICE COMPANY OF OKLAHOMA
Net Income	249.3	208.8	167.6
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES
Cash Flow Hedges, Net of Tax	3.8	(1.5)	1.3
TOTAL COMPREHENSIVE INCOME ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS	$ 253.1	$ 207.3	$ 168.9

CONSOLIDATED STATEMENTS OF C_10

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - PSO (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Cash Flow Hedges, Tax	$ 1.3	$ (33.8)	$ 21.6
PUBLIC SERVICE COMPANY OF OKLAHOMA
Cash Flow Hedges, Tax	$ 1	$ (0.4)	$ 0.3

CONSOLIDATED STATEMENTS OF CH_8

CONSOLIDATED STATEMENTS OF CHANGES IN COMMON SHAREHOLDER’S EQUITY - PSO - USD ($) $ in Millions	Total	Retained Earnings	[1]	Accumulated Other Comprehensive Income (Loss)	PUBLIC SERVICE COMPANY OF OKLAHOMA	PUBLIC SERVICE COMPANY OF OKLAHOMA Common Stock	PUBLIC SERVICE COMPANY OF OKLAHOMA Paid-in Capital	PUBLIC SERVICE COMPANY OF OKLAHOMA Retained Earnings	PUBLIC SERVICE COMPANY OF OKLAHOMA Accumulated Other Comprehensive Income (Loss)
Beginning balance at Dec. 31, 2021					$ 2,291.6	$ 157.2	$ 1,039	$ 1,095.4	$ 0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contribution from Parent					3.6		3.6
Common Stock Dividends	$ (1,645.2)	$ (1,628.7)			(45)			(45)
Other Comprehensive Income (Loss)	(101.1)			$ (101.1)	1.3				1.3
Net Income					167.6			167.6
Ending balance at Dec. 31, 2022					2,419.1	157.2	1,042.6	1,218	1.3
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contribution from Parent					0.6		0.6
Return of Capital to Parent					(3.9)		(3.9)
Common Stock Dividends	(1,760.4)	(1,752.3)			(52.5)			(52.5)
Other Comprehensive Income (Loss)	(139.2)			(139.2)	(1.5)				(1.5)
Net Income					208.8			208.8
Ending balance at Dec. 31, 2023	25,246.7				2,570.6	157.2	1,039.3	1,374.3	(0.2)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contribution from Parent					1.9		1.9
Common Stock Dividends	(1,903.9)	$ (1,898.3)			(140)			(140)
Other Comprehensive Income (Loss)	52.4			$ 52.4	3.8				3.8
Net Income					249.3			249.3
Ending balance at Dec. 31, 2024	$ 26,943.8				$ 2,685.6	$ 157.2	$ 1,041.2	$ 1,483.6	$ 3.6
[1]Cash dividends declared per AEP common share were $3.57, $3.37 and $3.17 for the years ended December 31, 2024, 2023 and 2022, respectively.

CONSOLIDATED BALANCE SHEETS - P

CONSOLIDATED BALANCE SHEETS - PSO - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
CURRENT ASSETS
Cash and Cash Equivalents	$ 202.9	$ 330.1
Accounts Receivable:
Customers	1,100.1	1,029.9
Miscellaneous	64.1	48.7
Total Accounts Receivable	2,631.9	2,447.4
Fuel	748.9	853.7
Materials and Supplies	966.2	1,025.8
Risk Management Assets	210.4	217.5
Accrued Tax Benefits	38.2	156.2
Regulatory Asset for Under-Recovered Fuel Costs	445.9	514
Prepayments and Other Current Assets	285.9	274.2
TOTAL CURRENT ASSETS	5,788.8	6,082.1
PROPERTY, PLANT AND EQUIPMENT
Generation	24,829.7	24,329.5
Transmission	38,871.9	35,934.1
Distribution	31,061.9	28,989.9
Other Property, Plant and Equipment	7,491.6	6,484.9
Construction Work in Progress	6,346.9	5,508
Total Property, Plant and Equipment	108,602	101,246.4
Accumulated Depreciation and Amortization	26,186.4	24,553
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	82,415.6	76,693.4
OTHER NONCURRENT ASSETS
Regulatory Assets	5,129.2	5,092.4
Operating Lease Assets	580.1	620.2
Deferred Charges and Other Noncurrent Assets	3,873.3	3,625.7
TOTAL OTHER NONCURRENT ASSETS	14,873.6	13,908.5
TOTAL ASSETS	103,078	96,684
CURRENT LIABILITIES
Accounts Payable	2,637.6	2,032.5
Long-term Debt Due Within One Year	3,335	2,490.5
Risk Management Liabilities	100	229.6
Customer Deposits	454.7	423.7
Accrued Taxes	1,922.1	1,800.1
Accrued Interest	453.3	410.2
Obligations Under Operating Leases	91.9	115.7
Other Current Liabilities	1,490.9	1,251.1
TOTAL CURRENT LIABILITIES	13,009.3	11,583.6
NONCURRENT LIABILITIES
Long-term Debt	39,307.8	37,652.7
Deferred Income Taxes	9,972.4	9,415.7
Regulatory Liabilities and Deferred Investment Tax Credits	8,344	8,182.4
Asset Retirement Obligations	3,530.6	2,972.5
Obligations Under Operating Leases	504.3	519.4
Deferred Credits and Other Noncurrent Liabilities	800.6	545.8
TOTAL NONCURRENT LIABILITIES	63,044.8	59,772
TOTAL LIABILITIES	76,054.1	71,355.6
Rate Matters (Note 4)
Commitments and Contingencies (Note 6)
COMMON SHAREHOLDER’S EQUITY
Common Stock	3,471.6	3,427.9
Paid-in Capital	9,606.1	9,073.9
Retained Earnings	13,869.2	12,800.4
Accumulated Other Comprehensive Income (Loss)	(3.1)	(55.5)
TOTAL COMMON SHAREHOLDER’S EQUITY	26,943.8	25,246.7
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	103,078	96,684
PUBLIC SERVICE COMPANY OF OKLAHOMA
CURRENT ASSETS
Cash and Cash Equivalents	1.8	2.5
Advances to Affiliates	232	0
Accounts Receivable:
Customers	74.8	107.6
Miscellaneous	0.3	0.8
Total Accounts Receivable	107.7	139.4
Fuel	17.1	33.7
Materials and Supplies	108.8	106.9
Risk Management Assets	20.6	19
Accrued Tax Benefits	35.5	31
Regulatory Asset for Under-Recovered Fuel Costs	64.7	118.3
Prepayments and Other Current Assets	20.2	18.7
TOTAL CURRENT ASSETS	608.4	469.5
PROPERTY, PLANT AND EQUIPMENT
Generation	2,772.4	2,695.5
Transmission	1,345.3	1,228.3
Distribution	3,698.8	3,450.8
Other Property, Plant and Equipment	550	505.9
Construction Work in Progress	378.8	313.7
Total Property, Plant and Equipment	8,745.3	8,194.2
Accumulated Depreciation and Amortization	2,213	2,081.9
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	6,532.3	6,112.3
OTHER NONCURRENT ASSETS
Regulatory Assets	527.8	522.7
Employee Benefits and Pension Assets	73.6	68.4
Operating Lease Assets	106.2	112.8
Deferred Charges and Other Noncurrent Assets	62	49.2
TOTAL OTHER NONCURRENT ASSETS	769.6	753.1
TOTAL ASSETS	7,910.3	7,334.9
CURRENT LIABILITIES
Accounts Payable	200.5	159.3
Long-term Debt Due Within One Year	125.6	0.6
Risk Management Liabilities	5.8	28.9
Customer Deposits	72.9	81.4
Accrued Taxes	33.4	30.7
Accrued Interest	33.1	30.7
Obligations Under Operating Leases	10.4	10.1
Other Current Liabilities	78.6	106.2
TOTAL CURRENT LIABILITIES	619.4	559
NONCURRENT LIABILITIES
Long-term Debt	2,730	2,384
Deferred Income Taxes	930.6	831.2
Regulatory Liabilities and Deferred Investment Tax Credits	689.7	765.6
Asset Retirement Obligations	118.8	83.9
Obligations Under Operating Leases	101.9	106.8
Deferred Credits and Other Noncurrent Liabilities	34.3	33.8
TOTAL NONCURRENT LIABILITIES	4,605.3	4,205.3
TOTAL LIABILITIES	5,224.7	4,764.3
Rate Matters (Note 4)
Commitments and Contingencies (Note 6)
COMMON SHAREHOLDER’S EQUITY
Common Stock	157.2	157.2
Paid-in Capital	1,041.2	1,039.3
Retained Earnings	1,483.6	1,374.3
Accumulated Other Comprehensive Income (Loss)	3.6	(0.2)
TOTAL COMMON SHAREHOLDER’S EQUITY	2,685.6	2,570.6
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	7,910.3	7,334.9
PUBLIC SERVICE COMPANY OF OKLAHOMA | Affiliated Entity
Accounts Receivable:
Affiliated Companies	32.6	31
CURRENT LIABILITIES
Advances from Affiliates	0	54.4
Accounts Payable	$ 59.1	$ 56.7

CONSOLIDATED BALANCE SHEETS -_8

CONSOLIDATED BALANCE SHEETS - PSO (Parenthetical) - $ / shares	Dec. 31, 2024	Dec. 31, 2023
Common Stock – Par Value (in USD per share)	$ 6.50	$ 6.50
Common Stock – Shares Authorized (in shares)	600,000,000	600,000,000
Common Stock – Shares Issued (in shares)	534,094,530	527,369,157
PUBLIC SERVICE COMPANY OF OKLAHOMA
Common Stock – Par Value (in USD per share)	$ 15	$ 15
Common Stock – Shares Authorized (in shares)	11,000,000	11,000,000
Common Stock – Shares Issued (in shares)	10,482,000	10,482,000
Common Stock – Shares Outstanding (in shares)	9,013,000	9,013,000

CONSOLIDATED STATEMENTS OF CA_7

CONSOLIDATED STATEMENTS OF CASH FLOWS - PSO - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities:
Depreciation and Amortization	$ 3,289.9	$ 3,090.4	$ 3,202.8
Deferred Income Taxes	58.3	185.1	(137.2)
Allowance for Equity Funds Used During Construction	(211)	(174.9)	(133.7)
Mark-to-Market of Risk Management Contracts	(80.4)	8.8	15.5
Deferred Fuel Over/Under-Recovery, Net	277	892.8	(319.2)
Change in Other Noncurrent Assets	(347.6)	(465.1)	(187.7)
Change in Other Noncurrent Liabilities	306.3	29	337.8
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(156)	236.5	(681.7)
Fuel, Materials and Supplies	171.6	(504)	(313.9)
Accounts Payable	85.1	(253.2)	489.2
Accrued Taxes, Net	240.2	22.5	105.4
Other Current Assets	(13.2)	(43.9)	109
Other Current Liabilities	182.6	(161.4)	54.3
Net Cash Flows from Operating Activities	6,804.3	5,012.2	5,288
INVESTING ACTIVITIES
Construction Expenditures	(7,630.7)	(7,378.3)	(6,671.7)
Acquisitions of Renewable Energy Facilities	(399.5)	(155.2)	(1,207.3)
Other Investing Activities	141.9	122.1	50.3
Net Cash Flows Used for Investing Activities	(7,596.5)	(6,266.7)	(7,751.8)
FINANCING ACTIVITIES
Issuance of Long-term Debt	5,117	5,462.8	4,649.7
Retirement of Long-term Debt	(2,685)	(2,196.1)	(2,345.4)
Principal Payments for Finance Lease Obligations	(64.8)	(68.3)	(309.5)
Dividends Paid on Common Stock	(1,903.9)	(1,760.4)	(1,645.2)
Other Financing Activities	(49.8)	(78.6)	(105.4)
Net Cash Flows from Financing Activities	659.2	1,077	2,568.9
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(133)	(177.5)	105.1
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	379	556.5	451.4
Cash, Cash Equivalents and Restricted Cash at End of Period	246	379	556.5
SUPPLEMENTARY INFORMATION
Cash Paid for Interest, Net of Capitalized Amounts	1,837.8	1,673.5	1,286.3
Net Cash Paid (Received) for Income Taxes	133.4	78.4	116.8
Construction Expenditures Included in Current Liabilities as of December 31,	1,312	842.4	1,258.9
PUBLIC SERVICE COMPANY OF OKLAHOMA
OPERATING ACTIVITIES
Net Income	249.3	208.8	167.6
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities:
Depreciation and Amortization	272.2	255.5	230.1
Deferred Income Taxes	20.6	7.9	(59.4)
Allowance for Equity Funds Used During Construction	(7.4)	(8.4)	(1.5)
Mark-to-Market of Risk Management Contracts	(27.1)	33	(13.7)
Deferred Fuel Over/Under-Recovery, Net	53.6	313.2	442.4
Change in Other Regulatory Assets	(0.3)	(108.3)	4.7
Change in Other Noncurrent Assets	(44.6)	(71.3)	(40.1)
Change in Other Noncurrent Liabilities	7.6	8.2	29.9
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	31.7	(16.3)	(46)
Fuel, Materials and Supplies	14.7	(16.8)	(51.1)
Accounts Payable	17.7	(58.2)	57.5
Accrued Taxes, Net	(1.8)	(12.9)	3.2
Other Current Assets	(4.3)	10.7	(6.3)
Other Current Liabilities	(33.3)	45.4	30.4
Net Cash Flows from Operating Activities	548.6	590.5	747.7
INVESTING ACTIVITIES
Construction Expenditures	(597.6)	(562.3)	(447)
Change in Advances to Affiliates, Net	(232)	0	0
Acquisitions of Renewable Energy Facilities	0	(145.7)	(549.3)
Other Investing Activities	5.3	15.2	4.3
Net Cash Flows Used for Investing Activities	(824.3)	(692.8)	(992)
FINANCING ACTIVITIES
Capital Contribution from Parent	1.9	0.6	3.6
Return of Capital to Parent	0	(3.9)	0
Issuance of Long-term Debt	595.5	469.8	499.7
Change in Advances from Affiliates, Net	(54.4)	(309.8)	291.9
Retirement of Long-term Debt	(125.6)	(0.5)	(500.5)
Principal Payments for Finance Lease Obligations	(3.3)	(3.3)	(3.2)
Dividends Paid on Common Stock	(140)	(52.5)	(45)
Other Financing Activities	0.9	0.4	0.5
Net Cash Flows from Financing Activities	275	100.8	247
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(0.7)	(1.5)	2.7
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	2.5	4	1.3
Cash, Cash Equivalents and Restricted Cash at End of Period	1.8	2.5	4
SUPPLEMENTARY INFORMATION
Cash Paid for Interest, Net of Capitalized Amounts	101.8	87.3	79.7
Net Cash Paid (Received) for Income Taxes	(15.1)	(10.6)	(12.5)
Cash Paid (Received) for Transferable Tax Credits	(96)	(34.6)	0
Noncash Acquisitions Under Finance Leases	1.5	2.1	2.8
Construction Expenditures Included in Current Liabilities as of December 31,	$ 88.4	$ 72.9	$ 69.8

CONSOLIDATED STATEMENTS OF IN_8

CONSOLIDATED STATEMENTS OF INCOME - SWEPCo - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
REVENUES
TOTAL REVENUES	$ 19,721.3	$ 18,982.3	$ 19,639.5
EXPENSES
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	5,936.3	6,578.3	7,097.9
Other Operation	3,127.6	2,810.5	2,878.1
Maintenance	1,325.1	1,276.3	1,249.4
Asset Impairments and Other Related Charges	142.5	85.6	48.8
Depreciation and Amortization	3,289.9	3,090.4	3,202.8
Taxes Other Than Income Taxes	1,596.3	1,492.3	1,469.8
TOTAL EXPENSES	15,417.7	15,426.1	16,156.8
OPERATING INCOME	4,303.6	3,556.2	3,482.7
Other Income (Expense):
Allowance for Equity Funds Used During Construction	211	174.9	133.7
Non-Service Cost Components of Net Periodic Benefit Cost	126	221.1	188.5
Interest Expense	(1,862.8)	(1,806.9)	(1,396.1)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	2,842.9	2,208.7	2,420.4
Income Tax Expense (Benefit)	(39.2)	54.6	5.4
Equity Earnings (Loss) of Unconsolidated Subsidiaries	93.7	58.5	(109.4)
NET INCOME	2,975.8	2,212.6	2,305.6
Net Income (Loss) Attributable to Noncontrolling Interests	8.7	4.5	(1.6)
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS, Basic	2,967.1	2,208.1	2,307.2
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS, Diluted	2,967.1	2,208.1	2,307.2
SOUTHWESTERN ELECTRIC POWER COMPANY
REVENUES
TOTAL REVENUES	2,036.3	2,182.8	2,284.4
EXPENSES
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	733.3	807.1	889.5
Other Operation	422.4	360.5	424.7
Maintenance	149.1	159.4	148.6
Asset Impairments and Other Related Charges	0	85.6	0
Depreciation and Amortization	389.3	342.8	324.8
Taxes Other Than Income Taxes	124.9	135.1	126.8
TOTAL EXPENSES	1,819	1,890.5	1,914.4
OPERATING INCOME	217.3	292.3	370
Other Income (Expense):
Interest Income	14.2	18.9	17.7
Allowance for Equity Funds Used During Construction	13.5	11.5	4.9
Non-Service Cost Components of Net Periodic Benefit Cost	0.8	13.6	12.5
Interest Expense	(105.5)	(147.2)	(137.4)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	140.3	189.1	267.7
Income Tax Expense (Benefit)	(184)	(33.3)	(25.2)
Equity Earnings (Loss) of Unconsolidated Subsidiaries	1.4	1.4	1.4
NET INCOME	325.7	223.8	294.3
Net Income (Loss) Attributable to Noncontrolling Interests	4.5	3.5	4.2
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS, Basic	321.2	220.3	290.1
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS, Diluted	321.2	220.3	290.1
Electric Generation, Transmission and Distribution Revenues | SOUTHWESTERN ELECTRIC POWER COMPANY
REVENUES
TOTAL REVENUES	2,148.6	2,154.7	2,234.9
Sales to AEP Affiliates | SOUTHWESTERN ELECTRIC POWER COMPANY | Affiliated Entity
REVENUES
TOTAL REVENUES	71.4	81.6	59.5
Provision for Refund | SOUTHWESTERN ELECTRIC POWER COMPANY | Affiliated Entity
REVENUES
TOTAL REVENUES	(9.3)	(34.8)	(5.6)
Provision for Refund | SOUTHWESTERN ELECTRIC POWER COMPANY | Nonrelated Party
REVENUES
TOTAL REVENUES	(181.9)	(21.1)	(6.3)
Other Revenues
REVENUES
TOTAL REVENUES	483	458.1	408.2
Other Revenues | SOUTHWESTERN ELECTRIC POWER COMPANY
REVENUES
TOTAL REVENUES	$ 7.5	$ 2.4	$ 1.9

CONSOLIDATED STATEMENTS OF C_11

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - SWEPCo - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Net Income	$ 2,975.8	$ 2,212.6	$ 2,305.6
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES
Cash Flow Hedges, Net of Tax	5	(127)	81.4
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(2.5)	(12.6)	(10.4)
Pension and OPEB Funded Status, Net of Tax	41	(16.3)	(155.4)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)	52.4	(139.2)	(101.1)
TOTAL COMPREHENSIVE INCOME	3,028.2	2,073.4	2,204.5
Total Comprehensive Income (Loss) Attributable To Noncontrolling Interests	8.7	4.5	(1.6)
TOTAL COMPREHENSIVE INCOME ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS	3,019.5	2,068.9	2,206.1
SOUTHWESTERN ELECTRIC POWER COMPANY
Net Income	325.7	223.8	294.3
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAXES
Cash Flow Hedges, Net of Tax	(0.3)	0.2	(0.1)
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(0.3)	(1.3)	(1.6)
Pension and OPEB Funded Status, Net of Tax	6.3	1.9	(9.2)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)	5.7	0.8	(10.9)
TOTAL COMPREHENSIVE INCOME	331.4	224.6	283.4
Total Comprehensive Income (Loss) Attributable To Noncontrolling Interests	4.5	3.5	4.2
TOTAL COMPREHENSIVE INCOME ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS	$ 326.9	$ 221.1	$ 279.2

CONSOLIDATED STATEMENTS OF C_12

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - SWEPCo (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Cash Flow Hedges, Tax	$ 1.3	$ (33.8)	$ 21.6
Amortization of Pension and OPEB Deferred Costs, Tax	(0.7)	(3.4)	(2.8)
Pension and OPEB Funded Status, Tax	10.9	(4.3)	(41.3)
SOUTHWESTERN ELECTRIC POWER COMPANY
Cash Flow Hedges, Tax	(0.1)	0	0
Amortization of Pension and OPEB Deferred Costs, Tax	(0.1)	(0.3)	(0.4)
Pension and OPEB Funded Status, Tax	$ 1.7	$ 0.5	$ (2.5)

CONSOLIDATED STATEMENTS OF CH_9

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - SWEPCo - USD ($) $ in Millions	Total	Common Stock	Paid-in Capital	Retained Earnings		Accumulated Other Comprehensive Income (Loss)	Noncontrolling Interests	SOUTHWESTERN ELECTRIC POWER COMPANY	SOUTHWESTERN ELECTRIC POWER COMPANY Common Stock	SOUTHWESTERN ELECTRIC POWER COMPANY Paid-in Capital	SOUTHWESTERN ELECTRIC POWER COMPANY Retained Earnings	SOUTHWESTERN ELECTRIC POWER COMPANY Accumulated Other Comprehensive Income (Loss)	SOUTHWESTERN ELECTRIC POWER COMPANY Noncontrolling Interests
Beginning balance at Dec. 31, 2021	$ 22,680.2	$ 3,408.7	$ 7,172.6	$ 11,667.1		$ 184.8	$ 247	$ 3,149.8	$ 0.1	$ 1,092.2	$ 2,050.9	$ 6.7	$ (0.1)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contribution from Parent								350		350
Common Stock Dividends	(1,645.2)			(1,628.7)	[1]		(16.5)	(105)			(105)
Common Stock Dividends – Nonaffiliated								(3.4)					(3.4)
Net Income (Loss)	2,305.6			2,307.2			(1.6)	294.3			290.1
Other Comprehensive Income (Loss)	(101.1)					(101.1)		(10.9)				(10.9)	4.2
Ending balance at Dec. 31, 2022	24,122.4	3,413.1	8,051	12,345.6		83.7	229	3,674.8	0.1	1,442.2	2,236	(4.2)	0.7
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contribution from Parent								50		50
Common Stock Dividends	(1,760.4)			(1,752.3)	[1]		(8.1)	(175)			(175)
Common Stock Dividends – Nonaffiliated								(4)					(4)
Net Income (Loss)	2,212.6			2,208.1			4.5	223.8			220.3		3.5
Other Comprehensive Income (Loss)	(139.2)					(139.2)		0.8				0.8
Ending balance at Dec. 31, 2023	25,285.9	3,427.9	9,073.9	12,800.4		(55.5)	39.2	3,770.4	0.1	1,492.2	2,281.3	(3.4)	0.2
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital Contribution from Parent								58.6		58.6
Return of Capital to Parent								(1.1)		(1.1)
Common Stock Dividends	(1,903.9)			(1,898.3)	[1]		(5.6)	(250)			(250)
Common Stock Dividends – Nonaffiliated								(4.3)					(4.3)
Net Income (Loss)	2,975.8			2,967.1			8.7	325.7			321.2		4.5
Other Comprehensive Income (Loss)	52.4					52.4		5.7				5.7
Ending balance at Dec. 31, 2024	$ 26,986.1	$ 3,471.6	$ 9,606.1	$ 13,869.2		$ (3.1)	$ 42.3	$ 3,905	$ 0.1	$ 1,549.7	$ 2,352.5	$ 2.3	$ 0.4
[1]Cash dividends declared per AEP common share were $3.57, $3.37 and $3.17 for the years ended December 31, 2024, 2023 and 2022, respectively.

CONSOLIDATED BALANCE SHEETS - S

CONSOLIDATED BALANCE SHEETS - SWEPCo - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
CURRENT ASSETS
Cash and Cash Equivalents	$ 202.9	$ 330.1
Restricted Cash	43.1	48.9
Accounts Receivable:
Customers	1,100.1	1,029.9
Miscellaneous	64.1	48.7
Total Accounts Receivable	2,631.9	2,447.4
Fuel	748.9	853.7
Materials and Supplies	966.2	1,025.8
Risk Management Assets	210.4	217.5
Accrued Tax Benefits	38.2	156.2
Regulatory Asset for Under-Recovered Fuel Costs	445.9	514
Prepayments and Other Current Assets	285.9	274.2
TOTAL CURRENT ASSETS	5,788.8	6,082.1
PROPERTY, PLANT AND EQUIPMENT
Generation	24,829.7	24,329.5
Transmission	38,871.9	35,934.1
Distribution	31,061.9	28,989.9
Other Property, Plant and Equipment	7,491.6	6,484.9
Construction Work in Progress	6,346.9	5,508
Total Property, Plant and Equipment	108,602	101,246.4
Accumulated Depreciation and Amortization	26,186.4	24,553
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	82,415.6	76,693.4
OTHER NONCURRENT ASSETS
Regulatory Assets	5,129.2	5,092.4
Securitized Assets	554.3	336.3
Deferred Charges and Other Noncurrent Assets	3,873.3	3,625.7
TOTAL OTHER NONCURRENT ASSETS	14,873.6	13,908.5
TOTAL ASSETS	103,078	96,684
CURRENT LIABILITIES
Accounts Payable	2,637.6	2,032.5
Short-term Debt – Nonaffiliated	2,523.8	2,830.2
Long-term Debt Due Within One Year	3,335	2,490.5
Risk Management Liabilities	100	229.6
Customer Deposits	454.7	423.7
Accrued Taxes	1,922.1	1,800.1
Accrued Interest	453.3	410.2
Obligations Under Operating Leases	91.9	115.7
Other Current Liabilities	1,490.9	1,251.1
TOTAL CURRENT LIABILITIES	13,009.3	11,583.6
NONCURRENT LIABILITIES
Long-term Debt	39,307.8	37,652.7
Deferred Income Taxes	9,972.4	9,415.7
Regulatory Liabilities and Deferred Investment Tax Credits	8,344	8,182.4
Asset Retirement Obligations	3,530.6	2,972.5
Employee Benefits and Pension Obligations	360.7	241.7
Obligations Under Operating Leases	504.3	519.4
Deferred Credits and Other Noncurrent Liabilities	800.6	545.8
TOTAL NONCURRENT LIABILITIES	63,044.8	59,772
TOTAL LIABILITIES	76,054.1	71,355.6
Rate Matters (Note 4)
Commitments and Contingencies (Note 6)
EQUITY
Common Stock	3,471.6	3,427.9
Paid-in Capital	9,606.1	9,073.9
Retained Earnings	13,869.2	12,800.4
Accumulated Other Comprehensive Income (Loss)	(3.1)	(55.5)
TOTAL COMMON SHAREHOLDER’S EQUITY	26,943.8	25,246.7
Noncontrolling Interests	42.3	39.2
TOTAL EQUITY	26,986.1	25,285.9
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	103,078	96,684
SOUTHWESTERN ELECTRIC POWER COMPANY
CURRENT ASSETS
Cash and Cash Equivalents	1.2	2.4
Restricted Cash	3.4	0
Accounts Receivable:
Customers	34.5	39
Miscellaneous	9.2	8.3
Total Accounts Receivable	97.8	94.5
Fuel	86.5	113.8
Materials and Supplies	81.4	88.4
Risk Management Assets	18.1	11.6
Accrued Tax Benefits	26	28.4
Regulatory Asset for Under-Recovered Fuel Costs	106.6	170.8
Prepayments and Other Current Assets	14.7	29.2
TOTAL CURRENT ASSETS	438	541.3
PROPERTY, PLANT AND EQUIPMENT
Generation	5,287.5	4,790.7
Transmission	2,863.8	2,660.6
Distribution	3,007.1	2,824.1
Other Property, Plant and Equipment	940.4	814.4
Construction Work in Progress	627.3	555.8
Total Property, Plant and Equipment	12,726.1	11,645.6
Accumulated Depreciation and Amortization	3,280	3,087.2
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	9,446.1	8,558.4
OTHER NONCURRENT ASSETS
Regulatory Assets	921.3	1,131.8
Securitized Assets	331.4	0
Deferred Charges and Other Noncurrent Assets	358.2	326.1
TOTAL OTHER NONCURRENT ASSETS	1,610.9	1,457.9
TOTAL ASSETS	11,495	10,557.6
CURRENT LIABILITIES
Accounts Payable	265.5	198.9
Short-term Debt – Nonaffiliated	5.5	4.3
Long-term Debt Due Within One Year	22.7	0
Risk Management Liabilities	2.3	14.4
Customer Deposits	75.4	72.5
Accrued Taxes	48.6	58.7
Accrued Interest	40.6	39.9
Obligations Under Operating Leases	8.2	9
Provision for Refund	70.8	0.7
Other Current Liabilities	159.9	153.9
TOTAL CURRENT LIABILITIES	1,031.6	686.9
NONCURRENT LIABILITIES
Long-term Debt	3,958.1	3,646.9
Deferred Income Taxes	1,271.3	1,179.3
Regulatory Liabilities and Deferred Investment Tax Credits	610.8	756.1
Asset Retirement Obligations	257.5	258.6
Employee Benefits and Pension Obligations	46.5	43.1
Obligations Under Operating Leases	137.5	122.5
Provision for Refund	107.8	24.9
Storm Reserve	106.2	0
Deferred Credits and Other Noncurrent Liabilities	62.7	68.9
TOTAL NONCURRENT LIABILITIES	6,558.4	6,100.3
TOTAL LIABILITIES	7,590	6,787.2
Rate Matters (Note 4)
Commitments and Contingencies (Note 6)
EQUITY
Common Stock	0.1	0.1
Paid-in Capital	1,549.7	1,492.2
Retained Earnings	2,352.5	2,281.3
Accumulated Other Comprehensive Income (Loss)	2.3	(3.4)
TOTAL COMMON SHAREHOLDER’S EQUITY	3,904.6	3,770.2
Noncontrolling Interests	0.4	0.2
TOTAL EQUITY	3,905	3,770.4
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	11,495	10,557.6
SOUTHWESTERN ELECTRIC POWER COMPANY | Affiliated Entity
CURRENT ASSETS
Advances to Affiliates	2.3	2.2
Accounts Receivable:
Affiliated Companies	54.1	47.2
CURRENT LIABILITIES
Advances from Affiliates	275	88.7
Accounts Payable	$ 57.1	$ 45.9

CONSOLIDATED BALANCE SHEETS -_9

CONSOLIDATED BALANCE SHEETS - SWEPCo (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Restricted Cash	$ 43.1	$ 48.9
Materials and Supplies	966.2	1,025.8
Other Property, Plant and Equipment	7,491.6	6,484.9
Accumulated Depreciation and Amortization	26,186.4	24,553
Securitized Assets	554.3	336.3
Long-term Debt Due Within One Year	3,335	2,490.5
Long-term Debt	$ 39,307.8	$ 37,652.7
Common Stock – Par Value (in USD per share)	$ 6.50	$ 6.50
Common Stock – Shares Authorized (in shares)	600,000,000	600,000,000
Subsidiaries
Restricted Cash	$ 43.1	$ 48.9
Long-term Debt Due Within One Year	216.5	207.2
Long-term Debt	826.5	556.3
SOUTHWESTERN ELECTRIC POWER COMPANY
Restricted Cash	3.4	0
Materials and Supplies	81.4	88.4
Other Property, Plant and Equipment	940.4	814.4
Accumulated Depreciation and Amortization	3,280	3,087.2
Securitized Assets	331.4	0
Long-term Debt Due Within One Year	22.7	0
Long-term Debt	$ 3,958.1	$ 3,646.9
Common Stock – Par Value (in USD per share)	$ 18	$ 18
Common Stock – Shares Authorized (in shares)	3,680	3,680
Common Stock – Shares Outstanding (in shares)	3,680	3,680
SOUTHWESTERN ELECTRIC POWER COMPANY | Subsidiaries
Restricted Cash	$ 3.4	$ 0
Securitized Assets	331.4	0
Long-term Debt Due Within One Year	22.7	0
Long-term Debt	308.7	0
SOUTHWESTERN ELECTRIC POWER COMPANY | Sabine
Materials and Supplies	1.5	3.9
Other Property, Plant and Equipment	166.8	182.7
Accumulated Depreciation and Amortization	$ 166.8	$ 182.7

CONSOLIDATED STATEMENTS OF CA_8

CONSOLIDATED STATEMENTS OF CASH FLOWS - SWEPCo - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
OPERATING ACTIVITIES
Net Income	$ 2,975.8	$ 2,212.6	$ 2,305.6
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities:
Depreciation and Amortization	3,289.9	3,090.4	3,202.8
Deferred Income Taxes	58.3	185.1	(137.2)
Asset Impairments and Other Related Charges	142.5	85.6	48.8
Allowance for Equity Funds Used During Construction	(211)	(174.9)	(133.7)
Mark-to-Market of Risk Management Contracts	(80.4)	8.8	15.5
Deferred Fuel Over/Under-Recovery, Net	277	892.8	(319.2)
Change in Regulatory Assets	(174.3)	(315.8)	(46.7)
Change in Other Noncurrent Assets	(347.6)	(465.1)	(187.7)
Change in Other Noncurrent Liabilities	306.3	29	337.8
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(156)	236.5	(681.7)
Fuel, Materials and Supplies	171.6	(504)	(313.9)
Accounts Payable	85.1	(253.2)	489.2
Accrued Taxes, Net	240.2	22.5	105.4
Other Current Assets	(13.2)	(43.9)	109
Other Current Liabilities	182.6	(161.4)	54.3
Net Cash Flows from Operating Activities	6,804.3	5,012.2	5,288
INVESTING ACTIVITIES
Construction Expenditures	(7,630.7)	(7,378.3)	(6,671.7)
Acquisitions of Renewable Energy Facilities	(399.5)	(155.2)	(1,207.3)
Other Investing Activities	141.9	122.1	50.3
Net Cash Flows Used for Investing Activities	(7,596.5)	(6,266.7)	(7,751.8)
FINANCING ACTIVITIES
Issuance of Long-term Debt	5,117	5,462.8	4,649.7
Change in Short-term Debt – Nonaffiliated	(159.1)	(1,223.1)	1,650.4
Retirement of Long-term Debt	(2,685)	(2,196.1)	(2,345.4)
Principal Payments for Finance Lease Obligations	(64.8)	(68.3)	(309.5)
Dividends Paid on Common Stock	(1,903.9)	(1,760.4)	(1,645.2)
Other Financing Activities	(49.8)	(78.6)	(105.4)
Net Cash Flows from Financing Activities	659.2	1,077	2,568.9
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(133)	(177.5)	105.1
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	379	556.5	451.4
Cash, Cash Equivalents and Restricted Cash at End of Period	246	379	556.5
SUPPLEMENTARY INFORMATION
Cash Paid for Interest, Net of Capitalized Amounts	1,837.8	1,673.5	1,286.3
Net Cash Paid (Received) for Income Taxes	133.4	78.4	116.8
Construction Expenditures Included in Current Liabilities as of December 31,	1,312	842.4	1,258.9
SOUTHWESTERN ELECTRIC POWER COMPANY
OPERATING ACTIVITIES
Net Income	325.7	223.8	294.3
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities:
Depreciation and Amortization	389.3	342.8	324.8
Deferred Income Taxes	(74.3)	54	9.4
Asset Impairments and Other Related Charges	0	85.6	0
Allowance for Equity Funds Used During Construction	(13.5)	(11.5)	(4.9)
Mark-to-Market of Risk Management Contracts	(19.8)	19.1	(6.2)
Deferred Fuel Over/Under-Recovery, Net	156.1	184.3	(86.4)
Change in Regulatory Assets	(50.8)	(60.8)	7.6
Provision for Refund – Turk Plant	79.2	0	0
Change in Other Noncurrent Assets	(18.9)	(40.5)	42.9
Change in Other Noncurrent Liabilities	(41.4)	11	18.3
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(3.3)	20.1	(28.2)
Fuel, Materials and Supplies	29.4	(31.4)	(9.3)
Accounts Payable	2.5	(8.4)	34.1
Accrued Taxes, Net	(7.7)	(4.5)	9.8
Provision for Refund – Turk Plant	68.3	0	0
Other Current Assets	9.9	20.2	(9.8)
Other Current Liabilities	(13.9)	(0.8)	(9.8)
Net Cash Flows from Operating Activities	816.8	803	586.6
INVESTING ACTIVITIES
Construction Expenditures	(740.5)	(780.5)	(586.4)
Change in Advances to Affiliates, Net	(0.1)	(0.1)	153.8
Acquisitions of Renewable Energy Facilities	(399.5)	0	(658)
Other Investing Activities	11.4	3.9	5.5
Net Cash Flows Used for Investing Activities	(1,128.7)	(776.7)	(1,085.1)
FINANCING ACTIVITIES
Capital Contribution from Parent	58.6	50	350
Return of Capital to Parent	(1.1)	0	0
Issuance of Long-term Debt	336.3	346.8	0
Change in Short-term Debt – Nonaffiliated	1.2	4.3	0
Change in Advances from Affiliates, Net	186.3	(222)	310.7
Retirement of Long-term Debt	0	(94.1)	(6.2)
Principal Payments for Finance Lease Obligations	(14)	(19.1)	(10.8)
Dividends Paid on Common Stock	(250)	(175)	(105)
Dividends Paid on Common Stock – Nonaffiliated	(4.3)	(4)	(3.4)
Other Financing Activities	1.1	0.8	0.4
Net Cash Flows from Financing Activities	314.1	(112.3)	535.7
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	2.2	(86)	37.2
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	2.4	88.4	51.2
Cash, Cash Equivalents and Restricted Cash at End of Period	4.6	2.4	88.4
SUPPLEMENTARY INFORMATION
Cash Paid for Interest, Net of Capitalized Amounts	139	128.9	131.2
Net Cash Paid (Received) for Income Taxes	(15.1)	(41)	(29.1)
Cash Paid (Received) for Transferable Tax Credits	(88.6)	(41.4)	0
Noncash Acquisitions Under Finance Leases	2.3	7.1	3.6
Construction Expenditures Included in Current Liabilities as of December 31,	$ 137.3	$ 63.7	$ 105.6

ORGANIZATION AND SUMMARY OF SIG

ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	12 Months Ended
	Dec. 31, 2024
Accounting Policies [Abstract]
ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES The disclosures in this note apply to all Registrants unless indicated otherwise. ORGANIZATION The Registrants engage in the generation, transmission and distribution of electric power. The Registrant Subsidiaries that conduct most of these activities are regulated by the FERC under the Federal Power Act and the Energy Policy Act of 2005 and maintain accounts in accordance with the FERC and other regulatory guidelines. Most of these companies are subject to further regulation with regard to rates and other matters by state regulatory commissions. AEP also provides competitive electric and gas supply for residential, commercial and industrial customers in deregulated electricity markets. The Registrants also engage in wholesale electricity, natural gas and other commodity marketing and risk management activities in the United States and provide various energy-related services. I&M provides barging services to both affiliated and nonaffiliated companies. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Rates and Service Regulation AEP’s public utility subsidiaries’ rates are regulated by the FERC and state regulatory commissions in the eleven state operating territories in which they operate. The FERC also regulates the Registrants’ affiliated transactions, including AEPSC intercompany service billings which are generally at cost, under the 2005 Public Utility Holding Company Act and the Federal Power Act. The FERC also has jurisdiction over certain issuances and acquisitions of securities of the public utility subsidiaries, the acquisition or sale of certain utility assets and mergers with another electric utility or holding company. The state regulatory commissions also regulate certain intercompany transactions under various orders and affiliate statutes. Both the FERC and state regulatory commissions are permitted to review and audit the relevant books and records of companies within a public utility holding company system. The FERC regulates wholesale power markets and wholesale power transactions. The Registrants’ wholesale power transactions are generally market-based. Wholesale power transactions are cost-based regulated when a cost-based contract is negotiated and filed with the FERC or the FERC determines that the Registrants have “market power” in the region where the transaction occurs. Wholesale power supply contracts have been entered into with various municipalities and cooperatives that are FERC-regulated, cost-based contracts. These contracts are generally formula rate mechanisms, which are trued-up to actual costs annually. The state regulatory commissions regulate all of the retail distribution operations and rates of AEP’s retail public utility subsidiaries on a cost basis. The state regulatory commissions also regulate the retail generation/power supply operations and rates except in Ohio. For generation in Ohio, customers who have not switched to a CRES provider for generation pay market-based auction rates. In addition, all OPCo distribution customers continue to pay for certain legacy deferred generation-related costs through PUCO approved riders. The FERC also regulates the Registrants’ wholesale transmission operations and rates. Retail transmission rates are based upon the FERC OATT rate when retail rates are unbundled in connection with restructuring. Retail transmission rates are based on formula rates included in the PJM OATT that are cost-based and are unbundled in Ohio for OPCo, in Virginia for APCo and in Michigan for I&M. AEP Texas’ retail transmission rates in Texas are unbundled but the retail transmission rates are regulated, on a cost basis, by the PUCT. Bundled retail transmission rates are regulated, on a cost basis, by the state commissions. Transmission rates for AEPTCo’s seven wholly-owned transmission subsidiaries within the AEP Transmission Holdco segment are based on formula rates included in the applicable RTO’s OATT that are cost-based. In West Virginia, APCo and WPCo provide retail electric service at bundled rates approved by the WVPSC, with rates set on a combined cost-of-service basis. In addition, the FERC regulates the Operating Agreement, TA and TCA, all of which allocate shared system costs and revenues among the utility subsidiaries that are parties to each agreement. The FERC also regulates the PCA. See Note 17 - Related Party Transactions for additional information. Principles of Consolidation AEP and the Registrant Subsidiaries’ consolidated financial statements include wholly-owned subsidiaries and VIEs, of which AEP or a Registrant Subsidiary is the primary beneficiary. Intercompany items are eliminated in consolidation. The equity method of accounting is used for equity investments where the Registrants exercise significant influence but do not hold a controlling financial interest. Such investments are initially recorded at cost in Deferred Charges and Other Noncurrent Assets on the balance sheets. The proportionate share of the investee’s equity earnings or losses is included in Equity Earnings of Unconsolidated Subsidiaries on the statements of income. AEP, I&M, PSO and SWEPCo have undivided ownership interests in generating units that are jointly-owned. The proportionate share of the operating costs associated with such facilities is included on the income statements and the assets and liabilities are reflected on the balance sheets. See Note 18 - Variable Interest Entities and Equity Method Investments and Note 19 - Property, Plant and Equipment for additional information. Accounting for the Effects of Cost-Based Regulation The Registrants’ financial statements reflect the actions of regulators that result in the recognition of certain revenues and expenses in different time periods than enterprises that are not rate-regulated. In accordance with accounting guidance for “Regulated Operations,” regulatory assets (deferred expenses to be recovered in the future) and regulatory liabilities (deferred revenue reductions or refunds) are recorded to reflect the economic effects of regulation in the same accounting period by matching expenses with their recovery through regulated revenues and by matching income with its passage to customers in cost-based regulated rates. Use of Estimates The preparation of these financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. These estimates include, but are not limited to, inventory valuation, allowance for credit losses, intangible and long-lived asset impairment, unbilled electricity revenue, valuation of long-term energy contracts, the effects of regulation, long-lived asset recovery, storm costs, AROs, the effects of contingencies and certain assumptions made in accounting for pension and postretirement benefits. The estimates and assumptions used are based upon management’s evaluation of the relevant facts and circumstances as of the date of the financial statements. Actual results could ultimately differ from those estimates. Cash and Cash Equivalents Cash and Cash Equivalents include temporary cash investments with original maturities of three months or less. Restricted Cash (Applies to AEP, AEP Texas, APCo and SWEPCo) Restricted Cash primarily includes funds held by trustees for the payment of securitization bonds. Reconciliation of Cash, Cash Equivalents and Restricted Cash The following tables provide a reconciliation of Cash, Cash Equivalents and Restricted Cash reported within the balance sheets that sum to the total of the same amounts shown on the statement of cash flows: AEP AEP Texas APCo SWEPCo Year Ended December 31, 2024 2023 2024 2023 2024 2023 2024 2023 (in millions) Cash and Cash Equivalents $ 202.9 $ 330.1 $ 0.1 $ 0.1 $ 3.9 $ 5.0 $ 1.2 $ 2.4 Restricted Cash 43.1 48.9 23.5 34.0 16.2 14.9 3.4 — Total Cash, Cash Equivalents and Restricted Cash $ 246.0 $ 379.0 $ 23.6 $ 34.1 $ 20.1 $ 19.9 $ 4.6 $ 2.4 Other Temporary Investments (Applies to AEP) Other Temporary Investments primarily include marketable securities and investments by its protected cell of EIS. These securities have readily determinable fair values and are carried at fair value with changes in fair value recognized in net income. The cost of securities sold is based on the specific identification or weighted-average cost method. See “Fair Value Measurements of Other Temporary Investments” section of Note 11 for additional information. Inventory Fossil fuel inventories are carried at average cost with the exception of AGR, which carries these inventories at the lower of average cost or net realizable value. Materials and supplies inventories are carried at average cost. Accounts Receivable and Allowance for Credit Losses Customer accounts receivable primarily include receivables from wholesale and retail energy customers, receivables from energy contract counterparties related to risk management activities and customer receivables primarily related to other revenue-generating activities. Revenue is recognized over time as the performance obligations of delivering energy to customers are satisfied. To the extent that deliveries have occurred but a bill has not been issued, the Registrants accrue and recognize, as Accrued Unbilled Revenues on the balance sheets, an estimate of the revenues for energy delivered since the last billing. AEP Credit factors accounts receivable on a daily basis, excluding receivables from risk management activities, through purchase agreements with I&M, KGPCo, KPCo, OPCo, PSO, SWEPCo and a portion of APCo. Since APCo does not have regulatory authority to sell accounts receivable in its West Virginia regulatory jurisdiction, only a portion of APCo’s accounts receivable are sold to AEP Credit. AEP Credit has a receivables securitization agreement with bank conduits. Under the securitization agreement, AEP Credit receives financing from bank conduits for a portion of its interests in the billed and unbilled receivables acquired from the affiliated utility subsidiaries. See “Securitized Accounts Receivable – AEP Credit” section of Note 15 for additional information. Generally, AEP Credit recognizes bad debt expense based upon a 12-month rolling average of bad debt write-offs in proportion to gross accounts receivable purchased from participating AEP subsidiaries. The assessment is performed separately for each participating AEP subsidiary, which inherently contemplates any differences in geographical risk characteristics for the allowance for credit losses. For receivables related to APCo’s West Virginia operations, the allowance for credit losses is calculated based on a rolling two-year average write-off in proportion to gross accounts receivable. For customer accounts receivables relating to risk management activities, accounts receivable are reviewed for potential credit losses at a specific counterparty level basis. For AEP Texas, allowances for credit losses are calculated using the specific identification of receivable balances greater than 120 days delinquent, and for those balances less than 120 days where the collection is doubtful. For miscellaneous accounts receivable, bad debt expense is recognized based upon a 12-month rolling average of bad debt write-offs in proportion to gross accounts receivable, unless specifically identified. In addition to these processes, management contemplates available current information, as well as any reasonable and supportable forecast information, to determine if allowances for credit losses should be further adjusted in accordance with the accounting guidance for “Credit Losses.” Management’s assessments contemplate expected losses over the life of the accounts receivable. Concentrations of Credit Risk and Significant Customers (Applies to Registrant Subsidiaries) APCo, I&M, OPCo, PSO and SWEPCo do not have any significant customers that comprise 10% or more of their operating revenues. AEP Texas had significant customers which account for the following percentages of Total Revenues for the years ended December 31 and Accounts Receivable – Customers as of December 31: Significant Customers of AEP Texas: NRG Energy and TXU Energy 2024 2023 2022 Percentage of Total Revenues 40 % 41 % 45 % Percentage of Accounts Receivable – Customers 37 % 34 % 42 % AEPTCo had significant transactions with AEP Subsidiaries which on a combined basis account for the following percentages of Total Revenues for the years ended December 31 and Total Accounts Receivable as of December 31: Significant Customers of AEPTCo: AEP Subsidiaries 2024 2023 2022 Percentage of Total Revenues 80 % 79 % 79 % Percentage of Total Accounts Receivable 69 % 60 % 72 % The Registrant Subsidiaries monitor credit levels and the financial condition of their customers on a continuous basis to minimize credit risk. The regulatory commissions allow recovery in rates for a reasonable level of bad debt costs. Management believes adequate provisions for credit loss have been made in the accompanying Registrant Subsidiary financial statements. Renewable Energy Credits (Applies to all Registrants except AEP Texas and AEPTCo) In regulated jurisdictions, the Registrants record renewable energy credits (RECs) at cost. For RECs acquired in AEP’s nonregulated operations within the Generation & Marketing segment, management records those RECs at the lower of cost or net realizable value. The Registrants follow the inventory model for these RECs. RECs are reported in Materials and Supplies on the balance sheets. The purchases and sales of RECs are reported in the Operating Activities section of the statements of cash flows. RECs that are consumed to meet applicable state renewable portfolio standards are recorded in Fuel and Other Consumables Used for Electric Generation at an average cost on the statements of income. The net margin on sales of RECs affects the determination of deferred fuel and REC costs. Property, Plant and Equipment Regulated Electric utility property, plant and equipment for rate-regulated operations are stated at original cost. Additions, major replacements and betterments are added to the plant accounts. Under the group composite method of depreciation, continuous interim routine replacements of items such as boiler tubes, pumps, motors, etc. result in original cost retirements, less salvage, being charged to accumulated depreciation. The group composite method of depreciation assumes that on average, asset components are retired at the end of their useful lives and thus there is no gain or loss. The equipment in each primary electric plant account is identified as a separate group. The depreciation rates that are established take into account the past history of interim capital replacements and the amount of removal cost incurred and salvage received. These rates and the related lives are subject to periodic review. Removal costs accrued are typically recorded as regulatory liabilities when the revenue received for removal costs accrued exceeds actual removal costs incurred. The asset removal costs liability is relieved as removal costs are incurred. A regulatory asset balance will occur if actual removal costs incurred exceed accumulated removal costs accrued. The costs of labor, materials and overhead incurred to operate and maintain plant and equipment are included in operating expenses. Nuclear fuel, including nuclear fuel in the fabrication phase, is included in Other Property, Plant and Equipment on the balance sheets. Long-lived assets are required to be tested for impairment when it is determined that the carrying value of the assets may no longer be recoverable or when the assets meet the held-for-sale criteria under the accounting guidance for “Impairment or Disposal of Long-Lived Assets.” When it becomes probable that an asset in-service or an asset under construction will be abandoned and regulatory cost recovery has been disallowed or is not probable, the cost of that asset shall be written down to its then current estimated fair value, with the change charged to expense, and the asset is removed from plant-in-service or CWIP. The fair value of an asset is the amount at which that asset could be bought or sold in a current transaction between willing parties, as opposed to a forced or liquidation sale. Quoted market prices in active markets are the best evidence of fair value and are used as the basis for the measurement, if available. In the absence of quoted prices for identical or similar assets in active markets, fair value is estimated using various internal and external valuation methods including cash flow analysis and appraisals. Nonregulated Nonregulated operations generally follow the policies of rate-regulated operations listed above but with the following exceptions. Property, plant and equipment of nonregulated operations are stated at original cost (or as adjusted for any applicable impairments) plus the original cost of property acquired or constructed since the acquisition, less disposals. Normal and routine retirements from the plant accounts, net of salvage, are charged to accumulated depreciation for most nonregulated operations under the group composite method of depreciation. A gain or loss would be recorded if the retirement is not considered an interim routine replacement. Removal costs are charged to expense. Allowance for Funds Used During Construction and Interest Capitalization For regulated operations, AFUDC represents the estimated cost of borrowed and equity funds used to finance construction projects that is capitalized and recovered through depreciation over the service life of regulated electric utility plant. The Registrants record the equity component of AFUDC in Allowance for Equity Funds Used During Construction and the debt component of AFUDC as a reduction to Interest Expense on the statements of income. For nonregulated operations, including certain generating assets, interest is capitalized during construction in accordance with the accounting guidance for “Capitalization of Interest.” Asset Retirement Obligations (Applies to all Registrants except AEPTCo) The Registrants record ARO in accordance with the accounting guidance for “Asset Retirement and Environmental Obligations” for legal obligations for asbestos removal and for the retirement of certain ash disposal facilities, wind farms, solar farms and certain coal-mining facilities. I&M records ARO for the decommissioning of the Cook Plant. Certain registrants also record AROs related to the Federal EPA’s revised CCR Rule. For operating facilities, the present value of the liability is added to the cost of the associated asset and depreciated over the remaining life of the asset. For retired facilities, the present value of the liability is expensed, and where future recovery through rates is probable, the present value of the liability is subsequently deferred as a regulatory asset. AROs are computed as the present value of the estimated costs associated with the future retirement of an asset and are recorded in the period in which the liability is incurred. Estimates of the timing and amounts of future cash outlays are based on projections of when and how the assets will be decommissioned and the liabilities will be remediated as well as the inflation rate and discount rate, which may change significantly over time. The estimated costs are capitalized as part of the related long-lived asset and depreciated over the asset's useful life. The Registrants have identified, but not recognized, ARO liabilities related to electric transmission and distribution assets as a result of certain easements on property on which assets are owned. Generally, such easements are perpetual and require only the retirement and removal of assets upon the cessation of the property’s use. The retirement obligation is not estimable for such easements since the Registrants plan to use their facilities indefinitely. The retirement obligation would only be recognized if and when the Registrants abandon or cease the use of specific easements, which is not expected. Valuation of Nonderivative Financial Instruments The book values of Cash and Cash Equivalents, Advances to/from Affiliates, Accounts Receivable, Accounts Payable and Short-term Debt approximate fair value because of the short-term maturity of these instruments. Fair Value Measurements of Assets and Liabilities (Applies to all Registrants except AEPTCo) The accounting guidance for “Fair Value Measurements and Disclosures” establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). Where observable inputs are available for substantially the full term of the asset or liability, the instrument is categorized in Level 2. When quoted market prices are not available, pricing may be completed using comparable securities, dealer values, operating data and general market conditions to determine fair value. Valuation models utilize various inputs such as commodity, interest rate and, to a lesser degree, volatility and credit that include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, market corroborated inputs (i.e. inputs derived principally from, or correlated to, observable market data) and other observable inputs for the asset or liability. For commercial activities, exchange-traded derivatives, namely futures contracts, are generally fair valued based on unadjusted quoted prices in active markets and are classified as Level 1. Level 2 inputs primarily consist of OTC broker quotes in moderately active or less active markets, as well as exchange-traded derivatives where there is insufficient market liquidity to warrant inclusion in Level 1. Management verifies price curves using these broker quotes and classifies these fair values within Level 2 when substantially all of the fair value can be corroborated. Management typically obtains multiple broker quotes, which are nonbinding in nature but are based on recent trades in the marketplace. When multiple broker quotes are obtained, the quoted bid and ask prices are averaged. In certain circumstances, a broker quote may be discarded if it is a clear outlier. Management uses a historical correlation analysis between the broker quoted location and the illiquid locations. If the points are highly correlated, these locations are included within Level 2 as well. Certain OTC and bilaterally executed derivative instruments are executed in less active markets with a lower availability of pricing information. Illiquid transactions, complex structured transactions, FTRs and counterparty credit risk may require nonmarket-based inputs. Some of these inputs may be internally developed or extrapolated and utilized to estimate fair value. When such inputs have a significant impact on the measurement of fair value, the instrument is categorized as Level 3. The main driver of contracts being classified as Level 3 is the inability to substantiate energy price curves in the market. A portion of the Level 3 instruments have been economically hedged which limits potential earnings volatility. AEP utilizes its trustee’s external pricing service to estimate the fair value of the underlying investments held in the benefit plan and nuclear trusts. AEP’s investment managers review and validate the prices utilized by the trustee to determine fair value. AEP’s management performs its own valuation testing to verify the fair values of the securities. AEP receives audit reports of the trustee’s operating controls and valuation processes. Assets in the benefits and nuclear trusts, cash and cash equivalents, other temporary investments and restricted cash for securitized funding are classified using the following methods. Equities are classified as Level 1 holdings if they are actively traded on exchanges. Items classified as Level 1 are investments in money market funds, fixed income and equity mutual funds and equity securities. They are valued based on observable inputs, primarily unadjusted quoted prices in active markets for identical assets. Items classified as Level 2 are primarily investments in individual fixed income securities. Fixed income securities generally do not trade on exchanges and do not have an official closing price but their valuation inputs are based on observable market data. Pricing vendors calculate bond valuations using financial models and matrices. The models use observable inputs including yields on benchmark securities, quotes by securities brokers, rating agency actions, discounts or premiums on securities compared to par prices, changes in yields for U.S. Treasury securities, corporate actions by bond issuers, prepayment schedules and histories, economic events and, for certain securities, adjustments to yields to reflect changes in the rate of inflation. Other securities with model-derived valuation inputs that are observable are also classified as Level 2 investments. Investments with unobservable valuation inputs are classified as Level 3 investments. Investments classified as Other are valued using Net Asset Value as a practical expedient. Items classified as Other are primarily cash equivalent funds, common collective trusts, commingled funds, structured products, private equity, real estate and infrastructure investments. These investments do not have a readily determinable fair value or they contain redemption restrictions which may include the right to suspend redemptions under certain circumstances. Redemption restrictions may also prevent certain investments from being redeemed at the reporting date for the underlying value. Deferred Fuel Costs (Applies to all Registrants except AEP Texas, AEPTCo and OPCo) The cost of purchased electricity, fuel and related emission allowances and emission control chemicals/consumables is charged to Purchased Electricity, Fuel and Other Consumables Used for Electric Generation expense when the fuel is burned or the allowance or consumable is utilized. The cost of fuel also includes the cost of nuclear fuel burned which is computed primarily using the units-of-production method. In regulated jurisdictions with an active FAC, fuel cost over-recoveries (the excess of fuel-related revenues over applicable fuel costs incurred) are generally deferred as current regulatory liabilities and under-recoveries (the excess of applicable fuel costs incurred over fuel-related revenues) are generally deferred as current regulatory assets. Fuel cost over-recovery and under-recovery balances are classified as noncurrent when there is an expectation that refunds or recoveries will extend beyond a one year period, based on a company’s filing with a commission or a commission directive. These deferrals are incorporated into the development of future fuel rates billed to or refunded to customers. The amount of an over-recovery or under-recovery can also be affected by actions of the state regulatory commissions. On a routine basis, state regulatory commissions review and/or audit the Registrants’ fuel procurement policies and practices, the fuel cost calculations and FAC deferrals. FAC deferrals are adjusted when costs are no longer probable of recovery or when refunds of fuel reserves are probable. The Registrants share the majority of their Off-system Sales margins to customers either through an active FAC or other rate mechanisms. Where the FAC or Off-system Sales sharing mechanism is capped, frozen, non-existent or applicable to merchant operations, changes in fuel costs or sharing of Off-system Sales impact earnings. Revenue Recognition Regulatory Accounting The Registrants’ financial statements reflect the actions of regulators that can result in the recognition of revenues and expenses in different time periods than enterprises that are not rate-regulated. Regulatory assets (deferred expenses or alternative revenues recognized in accordance with the guidance for “Regulated Operations”) and regulatory liabilities (deferred revenue reductions or refunds) are recorded to reflect the economic effects of regulation in the same accounting period by matching expenses with their recovery through regulated revenues and by matching revenue with its passage to customers in cost-based regulated rates. When regulatory assets are probable of recovery through regulated rates, assets are recorded on the balance sheets. Regulatory assets are reviewed for probability of recovery at each balance sheet date or whenever new events occur. Examples of new events include the issuance of a regulatory commission order or passage of new legislation. If it is determined that recovery of a regulatory asset is no longer probable, the regulatory asset is derecognized as a charge against income. Retail and Wholesale Supply and Delivery of Electricity The Registrants recognize revenues from customers for retail and wholesale electricity sales and electricity transmission and distribution delivery services. The Registrants recognize such revenues on the statements of income as the performance obligations of delivering energy to customers are satisfied. Recognized revenues include both billed and unbilled amounts. In accordance with the applicable state commission’s regulatory treatment, PSO and SWEPCo do not include the fuel portion in unbilled revenue, but rather recognize such revenues when billed to customers. Wholesale transmission revenue is based on FERC-approved formula rate filings made for each calendar year using estimated costs. Revenues initially recognized per the annual rate filing are compared to actual costs, resulting in the subsequent recognition of an over or under-recovered amount, with interest, that is refunded or recovered, respectively, in a future year’s rates. These annual true-ups meet the definition of alternative revenues in accordance with the accounting guidance for “Regulated Operations”. An estimated annual true-up is recorded by the Registrants in the fourth quarter of each calendar year and a final annual true-up is recognized by the Registrants in the second quarter of each calendar year following the filing of annual FERC reports. Any portion of the true-ups applicable to an affiliated company is recorded as Accounts Receivable - Affiliated Companies or Accounts Payable - Affiliated Companies on the balance sheets. Any portion of the true-ups applicable to third-parties is recorded as Regulatory Assets or Regulatory Liabilities on the balance sheets. See Note 20 - Revenue from Contracts with Customers for additional information. Gross versus Net Presentation of Certain Electricity Supply and Delivery Activities Most of the power produced at the generation plants is sold to PJM or SPP. The Registrants also purchase power from PJM and SPP to supply power to customers. Generally, these power sales and purchases are reported on a net basis as revenues on the statements of income. However, purchases of power in excess of sales to PJM or SPP, on an hourly net basis, used to serve retail load are recorded gross as Purchased Electricity on the statements of income. With the exception of certain dedicated load bilateral power supply contracts, the transactions of AEP’s nonregulated subsidiaries are reported as gross purchases or sales. Physical energy purchases arising from non-derivative contracts are accounted for on a gross basis in Purchased Electricity for Resale on the statements of income. Energy purchases arising from non-trading derivative contracts are recorded based on the transaction’s facts and circumstances. 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. Realized gains and losses on cash flow hedges are recorded in Total Revenues or Purchased Electricity depending on the nature of the risk being hedged. Derivative purchases elected normal used to serve accrual based obligations are recorded in Purchased Electricity on the statements of income. All other non-trading derivative purchases are recorded net in revenues. In general, the Registrants record expenses when purchased electricity is received and when expenses are incurred, with the exception of certain power purchase contracts that are derivatives and accounted for using MTM accounting where generation/supp

NEW ACCOUNTING STANDARDS

NEW ACCOUNTING STANDARDS	12 Months Ended
	Dec. 31, 2024
Accounting Standards Update and Change in Accounting Principle [Abstract]
NEW ACCOUNTING STANDARDS	NEW ACCOUNTING STANDARDS The disclosures in this note apply to all Registrants unless indicated otherwise. Management reviews the FASB’s standard-setting process and the SEC’s rulemaking activity to determine the relevance, if any, to the Registrants’ business. The following standards/rules will impact the Registrants’ financial statements. SEC Climate Disclosure Rule On March 6, 2024, the SEC adopted final rules that require registrants to disclose certain climate-related information in registration statements and annual reports. The final rules require registrants to disclose, among other things, material climate-related risks, activities to mitigate such risks and information about a registrant’s board of directors oversight and management’s role in managing material climate-related risks. The final rules also require registrants to provide information related to any climate-related targets or goals that are material to a registrant’s business, results of operations or financial condition. A majority of the reporting requirements are applicable to the fiscal year beginning in 2025, with the addition of assurance reporting for GHG emissions starting in 2029 for large accelerated filers. Litigation challenging the new rules was filed by multiple parties in multiple jurisdictions, which have been consolidated and assigned to the U.S. Court of Appeals for the Eighth Circuit. On April 4, 2024, the SEC issued an order staying the final climate disclosure rules pending the completion of judicial review at the Court of Appeals. The Registrants are currently evaluating the impact of the final rules on their respective consolidated financial statements and related disclosures. ASU 2023-07 “Improvements to Reportable Segment Disclosures” (ASU 2023-07) In November 2023, the FASB issued ASU 2023-07, to address investors’ observations that there is limited information disclosed about segment expenses and to better understand expense categories and amounts included in segment profit or loss. The new standard requires annual and interim disclosure of (a) the categories and amounts of significant segment expenses (determined by management using both qualitative and quantitative factors) that are regularly provided to the CODM and included within each reported measure of segment profit or loss, (b) the amounts and a qualitative description of “other segment items”, defined as the difference between reported segment revenues less the significant segment expenses and each reported measure of segment profit or loss disclosed, (c) reportable segment profit or loss and assets that are currently only required annually, (d) the CODM’s title and position, and an explanation of how the CODM uses the reported measure(s) of segment profit or loss in assessing segment performance and deciding how to allocate resources and (e) a requirement that entities with a single reportable segment provide all disclosures required by ASU 2023-07 and all existing segment disclosures in Topic 280. Additionally, this new standard allows disclosure of one or more of additional profit or loss measures if the CODM uses more than one measure provided that at least one of the disclosed measures is determined in a manner “most consistent with the measurement principles under GAAP”. If multiple measures are presented, additional disclosure is required about how the CODM uses each measure to assess performance and decide how to allocate resources. Management adopted ASU 2023-07 and its related implementation guidance effective January 1, 2024 for the annual reporting period and applied the amendments retrospectively to all prior periods presented in the consolidated financial statements. The amendments for interim periods will be adopted in our fiscal year beginning on January 1, 2025. The adoption of the new standard did not impact the results of operations, statements of financial position or cash flows. See Note 9 - Business Segments for additional information. ASU 2023-09 “Improvements to Income Tax Disclosures” (ASU 2023-09) In December 2023, the FASB issued ASU 2023-09, to address investors’ suggested enhancements to (a) better understand an entity’s exposure to potential changes in jurisdictional tax legislation and the ensuing risks and opportunities, (b) assess income tax information that affects cash flow forecasts and capital allocation decisions and (c) identify potential opportunities to increase future cash flows. The new standard requires an annual rate reconciliation disclosure of the following categories regardless of materiality: state and local income tax, net of federal income tax effect, foreign tax effects, effect of changes in tax laws or rates enacted in the current period, effect of cross-border tax laws, tax credits, changes in valuation allowances, nontaxable or nondeductible items and changes in unrecognized tax benefits. The new standard also requires an annual disclosure of the amount of income taxes paid (net of refunds received) disaggregated by federal, state and foreign taxes and by individual jurisdictions that are equal to or greater than 5 percent of total income taxes paid. Disclosure of income (loss) from continuing operations before income tax expense (benefit) disaggregated between domestic and foreign jurisdictions and income tax expense (benefit) from continuing operations disaggregated by federal, state and foreign jurisdictions is required. The new standard removes the requirement to disclose the cumulative amount of each type of temporary difference when a deferred tax liability is not recognized because of the exceptions to comprehensive recognition of deferred taxes related to subsidiaries and corporate joint ventures. The amendments in the new standard may be applied on either a prospective or retrospective basis for public business entities for fiscal years beginning after December 15, 2024 with early adoption permitted. Management has concluded to adopt the amendments to this standard prospectively beginning on January 1, 2025. ASU 2024-03 “Income Statement-Reporting Comprehensive Income-Expense Disaggregation Disclosures” (ASU 2024-03) In November 2024, the FASB issued ASU 2024-03, the intent of which is to improve financial reporting and respond to investor input by requiring public business entities to disclose additional information about certain expenses in the notes to financial statements in interim and annual reporting periods. Among other provisions, the new standard requires disclosure of disaggregated amounts for expenses such as employee compensation, depreciation, and intangible asset amortization included in each expense caption presented on the face of the income statement. Public business entities are required to include certain amounts that are already required to be disclosed under GAAP in the same disclosure as the other disaggregation requirements as well as a qualitative description of any amounts remaining in relevant expense captions that are not separately disaggregated quantitatively. The new standard also requires disclosure of the total amount of selling expenses and, in annual reporting periods, an entity’s definition of selling expenses. An entity is not precluded from providing additional voluntary disclosures that may provide investors with additional decision-useful information.

COMPREHENSIVE INCOME

COMPREHENSIVE INCOME	12 Months Ended
	Dec. 31, 2024
Stockholders' Equity Note [Abstract]
COMPREHENSIVE INCOME	COMPREHENSIVE INCOME The disclosures in this note apply to AEP only. The impact of AOCI is not material to the financial statements of the Registrant Subsidiaries. Presentation of Comprehensive Income The following tables provide AEP’s components of changes in AOCI and details of reclassifications from AOCI for the years ended December 31, 2024, 2023 and 2022. The amortization of pension and OPEB AOCI components are included in the computation of net periodic pension and OPEB costs. See Note 8 - Benefit Plans for additional information. Cash Flow Hedges Pension and OPEB For the Year Ended December 31, 2024 Commodity Interest Rate Amortization of Deferred Costs Changes in Funded Status Total (in millions) Balance in AOCI as of December 31, 2023 $ 104.9 $ (8.1) $ 92.6 $ (244.9) $ (55.5) Change in Fair Value Recognized in AOCI, Net of Tax 2.5 7.1 — 41.0 50.6 Amount of (Gain) Loss Reclassified from AOCI Purchased Electricity, Fuel and Other Consumables Used for Electric Generation (a) (11.2) — — — (11.2) Interest Expense (a) — 5.3 — — 5.3 Amortization of Prior Service Cost (Credit) — — (5.4) — (5.4) Amortization of Actuarial (Gains) Losses — — 2.2 — 2.2 Recognition of Pension Settlement Costs — — 11.3 — 11.3 Reclassifications from AOCI, before Income Tax (Expense) Benefit (11.2) 5.3 8.1 — 2.2 Income Tax (Expense) Benefit (2.3) 1.0 1.7 — 0.4 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (8.9) 4.3 6.4 — 1.8 Net Current Period Other Comprehensive Income (Loss) (6.4) 11.4 6.4 41.0 52.4 Balance in AOCI as of December 31, 2024 $ 98.5 $ 3.3 $ 99.0 $ (203.9) $ (3.1) Cash Flow Hedges Pension and OPEB For the Year Ended December 31, 2023 Commodity Interest Rate Amortization of Deferred Costs Changes in Funded Status Total (in millions) Balance in AOCI as of December 31, 2022 $ 223.5 $ 0.3 $ 105.2 $ (245.3) $ 83.7 Change in Fair Value Recognized in AOCI, Net of Tax (175.8) (6.4) — (16.3) (198.5) Amount of (Gain) Loss Reclassified from AOCI Purchased Electricity, Fuel and Other Consumables Used for Electric Generation (a) 72.2 — — — 72.2 Interest Expense (a) — (2.4) — — (2.4) Amortization of Prior Service Cost (Credit) — — (21.2) — (21.2) Amortization of Actuarial (Gains) Losses — — 5.2 — 5.2 Reclassifications from AOCI, before Income Tax (Expense) Benefit 72.2 (2.4) (16.0) — 53.8 Income Tax (Expense) Benefit 15.0 (0.4) (3.4) — 11.2 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 57.2 (2.0) (12.6) — 42.6 Reclassifications of KPCo Pension and OPEB Regulatory Assets to 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 to AOCI, Net of Income Tax (Expense) Benefit — — — 16.7 16.7 Net Current Period Other Comprehensive Income (Loss) (118.6) (8.4) (12.6) 0.4 (139.2) Balance in AOCI as of December 31, 2023 $ 104.9 $ (8.1) $ 92.6 $ (244.9) $ (55.5) Cash Flow Hedges Pension and OPEB For the Year Ended December 31, 2022 Commodity Interest Rate Amortization of Deferred Costs Changes in Funded Status Total (in millions) Balance in AOCI as of December 31, 2021 $ 163.7 $ (21.3) $ 115.6 $ (73.2) $ 184.8 Change in Fair Value Recognized in AOCI, Net of Tax 477.3 18.4 — (155.4) 340.3 Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (a) 0.1 — — — 0.1 Purchased Electricity, Fuel and Other Consumables Used for Electric Generation (a) (528.6) — — — (528.6) Interest Expense (a) — 4.0 — — 4.0 Amortization of Prior Service Cost (Credit) — — (21.8) — (21.8) Amortization of Actuarial (Gains) Losses — — 8.6 — 8.6 Reclassifications from AOCI, before Income Tax (Expense) Benefit (528.5) 4.0 (13.2) — (537.7) Income Tax (Expense) Benefit (111.0) 0.8 (2.8) — (113.0) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (417.5) 3.2 (10.4) — (424.7) Reclassifications of KPCo Pension and OPEB Regulatory Assets to 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 to AOCI, Net of Income Tax (Expense) Benefit — — — (16.7) (16.7) Net Current Period Other Comprehensive Income (Loss) 59.8 21.6 (10.4) (172.1) (101.1) Balance in AOCI as of December 31, 2022 $ 223.5 $ 0.3 $ 105.2 $ (245.3) $ 83.7 (a)

RATE MATTERS

RATE MATTERS	12 Months Ended
	Dec. 31, 2024
Public Utilities, General Disclosures [Abstract]
RATE MATTERS	RATE MATTERS The disclosures in this note apply to all Registrants unless indicated otherwise. The Registrants are involved in rate and regulatory proceedings at the FERC and their state commissions. Rate matters can have a material impact on net income, cash flows and possibly financial condition. The Registrants’ recent significant rate orders and pending rate filings are addressed in this note. AEP Texas Rate Matters (Applies to AEP and AEP Texas) 2024 AEP Texas Base Rate Case In February 2024, AEP Texas filed a request with the PUCT for a $164 million annual base rate increase over its adjusted test year revenues which include interim transmission and distribution rate updates. AEP Texas’s request is based upon a proposed 10.6% ROE with a capital structure of 55% debt and 45% common equity. The rate case sought a prudence determination on all capital additions placed in service during the period January 1, 2019 through September 30, 2023. In July 2024, AEP Texas filed an unopposed settlement agreement with the PUCT. The settlement agreement included a proposed annual revenue increase of $70 million based upon a 9.76% ROE with a capital structure of 57.5% debt and 42.5% common equity. In addition, the settlement agreement approved the prudency of capital investments placed in service for the period January 1, 2019 through September 30, 2023 and the associated interim revenues collected on those capital investments. In October 2024, the PUCT issued a final order approving the settlement agreement without modification. APCo and WPCo Rate Matters (Applies to AEP and APCo) ENEC (Expanded Net Energy Cost) Filings In January 2024, the WVPSC issued an order resolving APCo’s and WPCo’s ( the Companies) 2021-2023 ENEC cases. In the order, the WVPSC: (a) disallowed $232 million in ENEC under-recovered costs as of February 28, 2023 ($136 million related to APCo) and (b) approved the recovery of $321 million of ENEC under-recovered costs as of February 28, 2023 ($174 million related to APCo) plus a 4% debt carrying charge rate over a ten-year recovery period starting September 1, 2024. In February 2024, the Companies filed briefs with the West Virginia Supreme Court (WVSC) to initiate an appeal of the January 2024 order. Following arguments that were held in September 2024, the WVSC issued a November 2024 opinion affirming in part and reversing in part the WVPSC’s January 2024 ENEC order. The WVSC remanded the ENEC case to the WVPSC to afford the Companies an opportunity to examine, analyze, rebut and refute the effect of the evidence associated with the $232 million disallowance. Staff and intervenor testimony is due in August 2025 and a hearing is scheduled for October 2025. In April 2024, the Companies submitted their annual ENEC update filing with the WVPSC proposing a $58 million annual increase in ENEC rates when compared to existing ENEC rates. The Companies proposed that this ENEC rate change would: (a) become effective September 1, 2024, (b) include a $20 million annual increase in ENEC rates related to the period ending February 29, 2024 and the forecast period September 2024 through August 2025 and (c) include a $38 million annual increase in ENEC rates for the recovery of $321 million of ENEC under-recovered costs as of February 28, 2023 over a ten-year period, plus a 4% debt carrying charge rate. In July 2024, intervenors and staff filed testimony with the WVPSC, which did not recommend any disallowances. In August 2024, the WVPSC issued an order approving the requested $38 million annual increase effective September 1, 2024. The WVPSC will address the proposed additional $20 million annual increase in ENEC rates in a future order. If any costs included in the future filing are not approved for recovery, it could reduce future net income and cash flows and impact financial condition. Virginia Fuel Adjustment Clause (FAC) Review In 2023, APCo submitted its annual fuel cost filing with the Virginia SCC. Interim Virginia FAC rates were implemented in November 2023. In APCo's 2022 Virginia fuel update filing, the Virginia staff ordered the Virginia Staff to commence an audit of APCo’s fuel costs for the years ended December 31, 2019, 2020, 2021 and 2022. The Virginia staff analyzed APCo’s 2019 through 2022 fuel procurement activities and concluded the procurement practices were reasonable and prudent and recommended no disallowances. In May 2024, the Virginia SCC issued an order approving the audit of APCo’s 2019 and 2020 fuel costs but concluded that the review of APCo fuel costs for 2021 and 2022 remains open for further evaluation as part of APCo’s 2024 fuel cost filing. In September 2024, APCo submitted its annual Virginia fuel cost filing with the Virginia SCC proposing no change in annual APCo Virginia FAC rates charged to customers. In January 2025, an intervening party recommended a minimum fuel under-recovery disallowance of $20 million related to alleged imprudent operations of Amos and Mountaineer generating units during October 2021 and November 2021. There were no other recommended disallowances by intervenors or Virginia Staff regarding APCo’s historical period Virginia fuel under-recovery balance through October 31, 2024. Virginia Staff recommended that the Virginia SCC close APCo’s open review periods related to 2021 and 2022 Virginia fuel costs. A hearing is scheduled for February 2025. If any fuel costs are not recoverable or refunds are ordered, it could reduce future net income and cash flows and impact financial condition. 2024 Virginia Base Rate Case In March 2024, APCo filed a request with the Virginia SCC for a $95 million annual increase in base rates based upon a proposed 10.8% ROE and a proposed capital structure of 51% debt and 49% common equity. The requested increase in base rates is primarily due to incremental rate base, proposed capital structure changes including an increase in ROE and proposed increases in distribution and generation operation and maintenance expenses. In September 2024, a hearing was held where APCo updated its requested increase in base rates to $64 million consistent with its rebuttal positions or, alternatively, an increase of $45 million if annual environmental compliance consumable expenses are moved from base rates to recovery through APCo’s environmental rate adjustment clause. In November 2024, the Virginia SCC issued a final order approving an annual base rate increase of $10 million, effective January 2025, based on a 9.75% ROE. 2024 West Virginia Base Rate Case In November 2024, APCo and WPCo (the Companies) filed a request with the WVPSC for a net $251 million annual increase in base rates based upon a proposed 10.8% ROE and a proposed capital structure of 52% debt and 48% common equity. The requested net annual increase in base rates excludes the Companies’ proposed $94 million annual Modified Rate Base Cost (MRBC) surcharge update proposed to be effective in a separate proceeding and the existing $21 million annual Mitchell Base Rate Surcharge that are both proposed to be rolled into base rates upon the Companies’ anticipated 2025 change in base rates. The Companies’ proposed base rate increase includes recovery of approximately $118 million in previously deferred major storm expense over a three-year period, capital structure changes including an increase in ROE, an increase in depreciation expense related to proposed changes in depreciation rates and increased capital investments and increases in distribution and generation operation and maintenance expenses. The Companies’ November 2024 West Virginia base rate filing also included two sets of alternative frameworks to simplify rates and customer bills and provide predictable future rate increases. The Companies’ first framework includes: (a) securitization, (b) approval of a major storm expense recovery and tracking mechanism and (c) freezing of OATT revenues in the ENEC. This framework includes securitization in a concurrent proceeding of approximately $2.4 billion of West Virginia jurisdictional assets including: (a) the Companies’ remaining combined unrecovered ENEC balance related to costs incurred through February 28, 2023, (b) undepreciated West Virginia jurisdictional plant balances as of December 31, 2022 for the Amos, Mitchell and Mountaineer Plants, (c) environmental costs previously approved for recovery through a separate West Virginia surcharge and (d) deferred major storm operation and maintenance costs. Securitization of those items could reduce the Companies’ combined requested increase in annual base rates to $37 million. The Companies also included an alternative ratemaking proposal that includes: (a) a separate surcharge that would allow the Companies up to a 3% annual increase in overall West Virginia rates for four consecutive years on April 1 st of each year after the implementation of base rates in this case, (b) the elimination of all of the Companies’ existing West Virginia jurisdictional surcharges except for the ENEC, with the revenues of these eliminated riders rolled into base rates and (c) the creation of a new West Virginia jurisdictional environmental and new generation surcharge. This alternative proposal would allow the Companies to submit a base rate case filing in advance of and in lieu of the annual April 1st 3% increase and would require the Companies to submit a base rate case filing at the end of the proposed four-year period. Staff and intervenor testimony is due in April 2025 and a hearing is scheduled for June 2025. If any costs included in this filing are not approved for recovery, it could reduce future net income and cash flows and impact financial condition. West Virginia Modified Rate Base Cost (MRBC) Surcharge Update Filing In March 2024, APCo and WPCo (the Companies) submitted an annual MRBC surcharge update filing with the WVPSC requesting a $32 million annual increase in the Companies’ combined MRBC rates. The MRBC is an infrastructure investment tracker that allows limited cost recovery related to capital investments between the Companies’ West Virginia jurisdictional base rate cases. WVPSC staff and an intervening party recommended revenue requirement disallowances in written and verbal testimony and briefs for certain ratemaking issues used to develop the Companies’ proposed MRBC rates, including the West Virginia jurisdictional effect of state deferred income taxes, NOLC and AROs. If any refund liabilities are imposed by the WVPSC, it could reduce future net income and cash flows and impact financial condition. Hurricane Helene In late September 2024, the remnants of Hurricane Helene significantly impacted APCo’s Virginia and West Virginia service territories leading to approximately 260,000 customer outages and damages to APCo’s power grid. Storm restoration efforts continued into early October and APCo completed restoration efforts for all customers who lost power by October 6, 2024. As of December 31, 2024, APCo incurred and deferred an estimated $98 million ($72 million related to the Virginia jurisdiction and $26 million related to the West Virginia jurisdiction) of incremental other operation and maintenance expenses. APCo will seek recovery of the deferred West Virginia jurisdictional incremental other operation and maintenance expenses in a future filing while recovery of the deferred Virginia jurisdictional share will be requested as part of APCo’s 2024-2025 Virginia Biennial earnings review. If any costs related to Hurricane Helene 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 December 31, 2024, AEP’s share of ETT’s cumulative revenues from interim base rate increases that are subject to a prudency review is approximately $1.8 billion. The 2025 ETT base rate case described below could result in a refund to customers if ETT incurs a disallowance of the transmission 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 rates, could reduce future net income and cash flows and impact financial condition. 2025 ETT Base Rate Case In January 2025, ETT filed a request with the PUCT for a $57 million annual base rate increase over its adjusted test year revenues which includes interim transmission rate updates. ETT’s request is based upon a proposed 10.6% ROE with a capital structure of 55% debt and 45% common equity. The rate case seeks a prudence review determination on cumulative capital additions included in interim rates. A procedural schedule for the case is pending. If any of the costs in the case are not recoverable or refunds collected under interim transmission rates are ordered to be returned, it could reduce future net income and cash flows and impact financial condition. I&M Rate Matters (Applies to AEP and I&M) 2023 Michigan Power Supply Cost Recovery (PSCR) Reconciliation In March 2024, I&M submitted its 2023 PSCR Reconciliation to the MPSC. In October 2024, MPSC staff and intervenors submitted testimony recommending PSCR cost disallowances associated with the OVEC Inter-Company Power Agreement and the Rockport UPA with AEGCo ranging from $3 million to $15 million. A hearing was held in December 2024. If any PSCR costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. 2023 Indiana Base Rate Case In August 2023, I&M filed a request with the IURC for a $116 million annual increase in Indiana base rates based upon a 2024 forecasted test year, a proposed 10.5% ROE and a proposed capital structure of 48.8% debt and 51.2% common equity. I&M proposed that the annual increase in base rates be implemented in two steps, with the first increase effective in mid-2024, following an IURC order, and the second increase effective in January 2025. The proposed annual increase includes, but is not limited to, a $41 million increase related to depreciation expense, driven by increased depreciation rates and increased capital investments, and a $15 million increase related to storm expenses. I&M’s Indiana base case filing requested recovery of certain historical period regulatory asset balances and proposed deferral accounting for certain future investments and tax-related issues, including CAMT expense and PTCs related to the Cook Plant. In December 2023, I&M and intervenors reached a settlement agreement that was submitted to the IURC recommending a two-step increase in Indiana rates with a $28 million annual increase effective upon an IURC order and the remaining $34 million annual increase effective in January 2025 subject to I&M’s level of electric plant in service as of December 31, 2024 in comparison to I&M’s 2024 forecasted test year. The recommended revenue increase includes: (a) a 9.85% ROE, (b) a two-step update of I&M’s Indiana capital structure with a capital structure of 50% for both debt and common equity effective upon an IURC order and a January 2025 update based on I&M’s actual capital structure as of December 31, 2024 with common equity not to exceed 51.2%, (c) a $25 million increase related to depreciation expense and (d) an $11 million increase related to storm expenses. In addition, I&M also agreed to withdraw its proposal to defer CAMT and Cook Plant PTCs and to instead include the Indiana jurisdictional impact of Cook Plant PTCs in I&M’s Indiana earnings test evaluations. See “Indiana Earnings Test” below for additional information. In May 2024, the IURC issued an order approving the settlement agreement with minor modifications. In January 2025, in accordance with the IURC’s order on I&M’s 2023 Indiana base case filing, I&M submitted a filing with the IURC reflecting December 31, 2024 balances of electric plant in service in comparison to I&M’s 2024 forecasted test year, resulting in a $15 million annual increase in I&M Indiana base rates effective January 2025. 2023 Michigan Base Rate Case In September 2023, I&M filed a request with the MPSC for a $34 million annual increase in Michigan base rates based upon a 2024 forecasted test year, a proposed 10.5% ROE and a capital structure of 49.4% debt and 50.6% common equity. The proposed annual increase includes an $11 million annual increase in depreciation expense driven by increased capital investment. I&M’s Michigan base case filing requests recovery of certain historical period regulatory asset balances and proposes deferral accounting for certain future investments and tax-related issues, including CAMT expense and PTCs related to the Cook Plant. In July 2024, the MPSC issued a final order approving an annual base rate increase of $17 million based on a 9.86% ROE and a capital structure of 52% debt and 48% common equity. The MPSC also ordered that Michigan jurisdictional Cook Plant PTCs will be reflected as a deferral in I&M’s PSCR reconciliation and rejected I&M’s request to defer Michigan jurisdictional CAMT. Indiana Earnings Test I&M is required by Indiana law to submit an earnings test evaluation for the most recent one-year and five-year periods as part of I&M’s semi-annual Indiana FAC filings. These earnings test evaluations require I&M to include a credit in the FAC factor computation for periods in which I&M earned above its authorized return for both the one-year and five-year periods. The credit is determined as 50% of the lower of the one-year or five-year earnings above the authorized level. Management believes its financial statements adequately address the impact of Indiana earnings test requirements. If future IURC orders require that I&M provide credits in the FAC factor computation, it could reduce future net income and cash flows and impact financial condition. In July 2024, I&M submitted its FAC filing and earnings test evaluation for the period ended May 2024. In September 2024, an intervenor submitted testimony suggesting that I&M failed to prorate calculations of I&M’s authorized net operating income used to establish the earnings test ceiling to reflect the last two Indiana base rate cases. In November 2024, the IURC issued an order on I&M’s July 2024 FAC filing concluding that I&M should have prorated the authorized net operating income for the May 2024 earnings test purposes. A resulting over-earnings credit to customers for the earnings test period ending May 2024 of $18 million was included in I&M’s updated FAC rates that became effective in December 2024. In January 2025, I&M submitted its FAC filing and earnings test evaluation for the period ended November 2024. I&M proposed an over-earnings credit to customers for the earnings test period ending November 2024 of $21 million. I&M also proposed to the IURC that intervenor testimony be due in March 2025. KPCo Rate Matters (Applies to AEP) Investigation of the Service, Rates and Facilities of KPCo In June 2023, the KPSC issued an order directing KPCo to show cause why it should not be subject to Kentucky statutory remedies, including fines and penalties, for failure to provide adequate service in its service territory. The KPSC’s show cause order did not make any determination regarding the adequacy of KPCo’s service. In July 2023, KPCo filed a response to the show cause order demonstrating that it has provided adequate service. In December 2023 and February 2024, KPCo and certain intervenors filed testimony with the KPSC. A hearing with the KPSC was previously scheduled to occur in June 2024. The hearing was postponed and has not yet been rescheduled. If any fines or penalties are levied against KPCo relating to the show cause order, it could reduce net income and cash flows and impact financial condition. 2023 Kentucky Base Rate and Securitization Case In June 2023, KPCo filed a request with the KPSC for a $94 million net annual increase in base rates based upon a proposed 9.9% ROE with the increase to be implemented no earlier than January 2024. In conjunction with its June 2023 filing, KPCo further requested to finance through the issuance of securitization bonds, approximately $471 million of regulatory assets. KPCo’s proposal did not address the disposition of its 50% interest in Mitchell Plant, which will be addressed in the future. As of December 31, 2024, the net book value of KPCo’s share of the Mitchell Plant, before cost of removal including CWIP and inventory, was $547 million. If any of these costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. In November 2023, KPCo filed an uncontested settlement agreement with the KPSC, that included an annual base rate increase of $75 million, based upon a 9.75% ROE. Settlement parties agreed that the KPSC should approve KPCo’s securitization request, and that the approximately $471 million regulatory assets requested for securitization are comprised of prudently incurred costs. In January 2024, the KPSC issued an order modifying the November 2023 uncontested settlement agreement and approving an annual base rate increase of $60 million based upon a 9.75% ROE effective with billing cycles mid-January 2024. The order reduced KPCo’s base rate revenue requirement by $14 million to allow recovery of actual test year PJM transmission costs instead of KPCo’s requested annual level of costs based on PJM 2023 projected transmission revenue requirements. In February 2024, KPCo filed an appeal with the Commonwealth of Kentucky Franklin Circuit Court, challenging among other aspects of the order, the $14 million base rate revenue requirement reduction. In January 2025, the Commonwealth of Kentucky Franklin Circuit Court issued an order agreeing with KPCo’s appeal and remanded this issue back to the KPSC with instructions to enter an order, within 30 days, which includes setting rates to allow KPCo to recover the $14 million of annual PJM transmission costs effective upon KPCo's January 2024 implementation of updated base rates. In January 2024, consistent with the November 2023 uncontested settlement agreement, the KPSC issued a financing order approving KPCo’s request to securitize certain regulatory assets balances as of the time securitization bonds are issued and concluding that costs requested for recovery through securitization were prudently incurred. The KPSC’s financing order includes certain additional requirements related to securitization bond structuring, marketing, placement and issuance that were not reflected in KPCo’s proposal. In accordance with Kentucky statutory requirements and the financing order, the issuance of the securitized bonds is subject to final review by the KPSC after bond pricing. KPCo expects to proceed with the securitized bond issuance process and to complete the securitization process in the first half of 2025, subject to market conditions. As of December 31, 2024, regulatory asset balances expected to be recovered through securitization total $491 million and include: (a) $303 million of plant retirement costs, (b) $79 million of deferred storm costs related to 2020, 2021, 2022 and 2023 major storms, (c) $50 million of deferred purchased power expenses, (d) $57 million of under-recovered purchased power rider costs and (e) $2 million of deferred issuance-related expenses, including KPSC advisor expenses. If any of these costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. Fuel Adjustment Clause (FAC) Review In December 2023, KPCo received intervenor testimony in its FAC review for the two-year period ending October 31, 2022, recommending a disallowance ranging from $44 million to $60 million of its total $432 million purchased power cost recoveries as a result of proposed modifications to the ratemaking methodology that limits purchased power costs recoverable through the FAC. In November 2024, KPCo and intervening parties entered into a settlement agreement whereby KPCo agreed to provide customer rate credits, which will reduce FAC costs otherwise recoverable in 2025 and 2026, for a combined $17 million over the periods January 2025 through April 2025 and January 2026 through April 2026 based on actual customer usage. In December 2024, the KPSC issued an order approving the settlement agreement without modification. Rockport Offset Recovery In January 2024, KPCo filed an application with the KPSC seeking to recover an allowed cost (Rockport Offset) of $41 million in accordance with the terms of the settlement agreement in the 2017 Kentucky Base Rate Case permitting KPCo to use the level of non-fuel, non-environmental Rockport Plant UPA expense included in base rates to earn its authorized ROE in 2023 since the Rockport UPA ended in December 2022. An estimated Rockport Offset of $23 million was recovered through a rider, subject to true-up, during the 12-months ended December 2023. In February 2024, the KPSC issued an order allowing KPCo to collect the remaining $18 million through interim rates, subject to refund, over twelve months starting in March 2024. In August 2024, KPCo filed an application with the KPSC to extend the recovery of the remaining balance through September 2025. In the fourth quarter of 2024, the KPSC issued orders approving KPCo’s application to extend recovery of the Rockport Offset and affirming collection of $18 million. 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 May 2023, as part of the OVEC cost recovery audits pending before the PUCO, intervenors filed positions claiming that costs incurred by OPCo during the 2020 audit period were imprudent and should be disallowed. In August 2024, the PUCO issued orders pertaining to the OVEC cost recovery audits that: (a) denied intervenors’ application for rehearing on the 2016-2017 audit period, (b) determined costs incurred by OPCo during the 2018-2019 audit period were prudent, (c) determined costs incurred by OPCo during the 2020 audit period were prudent and (d) recommended no disallowances for any mentioned audit period in question. In September 2024, intervenors filed for rehearing on the 2018-2019 and 2020 OVEC cost recovery audit periods claiming the PUCO’s August 2024 orders to adopt the findings of the audit reports were unjust, unlawful and unreasonable for multiple reasons, including the position that OPCo recovered imprudently incurred costs. In October 2024, the PUCO denied the intervenors’ applications for rehearing of the 2018-2019 and 2020 audit periods. In December 2024, intervenors filed appeals with the Supreme Court of Ohio on the PUCO’s denial for rehearing. 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. In June 2023, intervenors filed testimony opposing OPCo’s plan for various new riders and modifications to existing riders, including the DIR. In September 2023, OPCo and certain intervenors filed a settlement agreement with the PUCO addressing the ESP application. The settlement included a four year term from June 2024 through May 2028, an ROE of 9.7% and continuation of a number of riders including the DIR subject to revenue caps. In April 2024, the PUCO issued an order approving the settlement agreement. In May 2024, intervenors filed an application for rehearing with the PUCO on the approved settlement agreement and the PUCO denied the intervenors’ application for rehearing in June 2024. PSO Rate Matters (Applies to AEP and PSO) 2024 Oklahoma Base Rate Case In January 2024, PSO filed a request with the OCC for a $218 million annual base rate increase based upon a 10.8% ROE with a capital structure of 48.9% debt and 51.1% common equity. PSO requested an expanded transmission cost recovery rider and a mechanism to recover generation costs necessary to comply with SPP’s 2023 increased capacity planning reserve margin requirements. PSO’s request includes the 155 MW Rock Falls Wind Facility and reflects recovery of Northeastern Plant, Unit 3 through 2040. In October 2024, PSO, the OCC and certain intervenors filed a joint stipulation and settlement agreement with the OCC that included a net annual revenue increase of $120 million based upon a 9.5% ROE with a capital structure of 48.9% debt and 51.1% common equity. The agreement also allows for Rock Falls Wind Facility to be included in base rates and the deferral of certain generation-related costs necessary to comply with SPP’s 2023 increased capacity reserve margin requirements. One intervenor opposed the joint stipulation and settlement agreement. In October 2024, a hearing was held at the OCC, and PSO implemented an interim annual base rate increase of $120 million, subject to refund pending a final order by the OCC. In January 2025, the OCC issued a final order approving the joint stipulation and settlement agreement without modification. 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 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. In November 2021, SWEPCo and the PUCT submitted Petitions for Review with the Texas Supreme Court. 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 June 2023, the Texas Supreme Court denied SWEPCo’s request for rehearing and the case was remanded to the PUCT for future proceedings. In October 2023, SWEPCo filed testimony with the PUCT in the remanded proceeding recommending no refund or disallowance. In December 2023, the PUCT approved a preliminary order stating the PUCT will not address SWEPCo’s request that would allow the PUCT to find cause to allow SWEPCo to exceed the Texas jurisdictional capital cost cap in the current remand proceeding. As a result of the PUCT’s approval of the preliminary order, SWEPCo recorded a pretax, non-cash probable disallowance of $86 million in the fourth quarter of 2023. The PUCT’s December 2023 approval of the preliminary order determined that it will address, in the ongoing PUCT remand proceeding, any potential revenue refunds to customers that may be required by future PUCT orders. On March 1, 2024, SWEPCo filed supplemental direct testimony with the PUCT in response to the December 2023 preliminary order. On March 8, 2024, intervenors and the PUCT staff filed a motion with the PUCT to strike portions of SWEPCo’s October 2023 direct testimony and March 2024 supplemental direct testimony. On March

EFFECTS OF REGULATION

EFFECTS OF REGULATION	12 Months Ended
	Dec. 31, 2024
Regulatory Assets and Liabilities Disclosure [Abstract]
EFFECTS OF REGULATION	EFFECTS OF REGULATION The disclosures in this note apply to all Registrants unless indicated otherwise. Regulated Generating Units (Applies to AEP, PSO and SWEPCo) Compliance with extensive environmental regulations requires significant capital investment in environmental monitoring, installation of pollution control equipment, emission fees, disposal costs and permits. Management continuously evaluates cost estimates of complying with these regulations in balance with reliability and other factors, which has resulted in, and in the future may result in, a proposal to retire generating facilities earlier than their currently estimated useful lives. Management is seeking or will seek regulatory recovery, as necessary, for any net book value remaining when the plants are retired. To the extent the net book value of these generation assets is not deemed recoverable, it could reduce future net income and cash flows and impact financial condition. Regulated Generating Units that have been Retired SWEPCo In December 2021, the Dolet Hills Power Station was retired. As part of the 2020 Texas Base Rate Case, the PUCT authorized recovery of SWEPCo’s Texas jurisdictional share of the Dolet Hills Power Station through 2046, but denied SWEPCo the ability to earn a return on this investment resulting in a disallowance of $12 million in 2021. See “2020 Texas Base Rate Case” section of Note 4 for additional information. As part of the 2021 Arkansas Base Rate Case, the APSC authorized recovery of SWEPCo’s Arkansas jurisdictional share of the Dolet Hills Power Station through 2027, but denied SWEPCo the ability to earn a return on this investment resulting in a disallowance of $2 million in the second quarter of 2022. Also, the APSC did not rule on the prudency of the early retirement of the Dolet Hills Power Station, which will be addressed in a future proceeding. As part of the 2020 Louisiana Base Rate Case, the LPSC authorized the recovery of SWEPCo’s Louisiana share of the Dolet Hills Power Station, through a separate rider, through 2032, but did not rule on the prudency of the early retirement of the plant, which is being addressed in a separate proceeding. In April 2024, the LPSC approved a unanimous settlement agreement filed by SWEPCo, LPSC staff and certain intervenors that resolved the prudency of the retirement of the Dolet Hills Power Station and resulted in a disallowance of $14 million in the first quarter of 2024. In March 2023, the Pirkey Plant was retired. As part of the 2020 Louisiana Base Rate Case, the LPSC authorized the recovery of SWEPCo’s Louisiana jurisdictional share of the Pirkey Plant, through a separate rider, through 2032. As part of the 2021 Arkansas Base Rate Case, the APSC granted SWEPCo regulatory asset treatment. SWEPCo will request recovery including a weighted average cost of capital carrying charge through a future proceeding. In July 2023, Texas ALJs issued a PFD that concluded the decision to retire the Pirkey Plant was prudent. In September 2023, the PUCT rejected the ALJs’ July 2023 PFD. In the open meeting, the commissioners expressed their concerns that the analysis in support of SWEPCo’s decision to retire the Pirkey Plant was not robust enough and that SWEPCo should have re-evaluated the decision following Winter Storm Uri. The treatment of the cost of recovery of the Pirkey Plant is expected to be addressed in a future rate case. As of December 31, 2024, the Texas jurisdictional share of the net book value of the Pirkey Plant was $69 million. To the extent any portion of the Texas jurisdictional share of the net book value of the Pirkey Plant is not recoverable, it could reduce future net income and cash flows and impact financial condition. Regulated Generating Units to be Retired PSO In 2014, PSO received final approval from the Federal EPA to close Northeastern Plant, Unit 3, in 2026. The plant was originally scheduled to close in 2040. As a result of the early retirement date, PSO revised the useful life of Northeastern Plant, Unit 3, to the projected retirement date of 2026 and the incremental depreciation is being deferred as a regulatory asset. Following the 2024 Oklahoma Base Rate Case, PSO continues 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. In December 2024, SWEPCo filed an application for a Certificate of Convenience and Necessity (CCN) with the APSC, LPSC and PUCT to convert Welsh Plant, Units 1 and 3 to natural gas in 2028 and 2027, respectively. The table below summarizes the net book value including CWIP, before cost of removal and materials and supplies, as of December 31, 2024, of generating facilities planned for early retirement: Plant Net Book Value Accelerated Depreciation Regulatory Asset Cost of Removal Projected Current Authorized Annual (dollars in millions) Northeastern Plant, Unit 3 $ 101.7 $ 189.0 $ 21.0 (b) 2026 (c) $ 16.2 Welsh Plant, Units 1 and 3 324.3 168.6 57.6 (d) 2028 (e) (f) 43.6 (a) Represents the amount of annual depreciation that has been collected from customers over the prior 12-month period. (b) Includes Northeastern Plant, Unit 4, which was retired in 2016. Removal of Northeastern Plant, Unit 4, will be performed with the removal of Northeastern Plant, Unit 3, after retirement. (c) Northeastern Plant, Unit 3 is currently being recovered through 2040. (d) Includes Welsh Plant, Unit 2, which was retired in 2016. Removal of Welsh Plant, Unit 2, will be performed with the removal of Welsh Plant, Units 1 and 3, after retirement. (e) Represents projected retirement date of coal assets. (f) Unit 1 is being recovered through 2027 in the Louisiana jurisdiction and through 2037 in the Arkansas and Texas jurisdictions. Unit 3 is being recovered through 2032 in the Louisiana jurisdiction and through 2042 in the Arkansas and Texas jurisdictions. Dolet Hills Power Station and Related Fuel Operations (Applies to AEP and SWEPCo) In December 2021, the Dolet Hills Power Station was retired. While in operation, DHLC provided 100% of the fuel supply to Dolet Hills Power Station. The remaining book value of Dolet Hills Power Station non-fuel related assets are recoverable by SWEPCo through rate riders. As of December 31, 2024, SWEPCo’s share of the net investment in the Dolet Hills Power Station was $74 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 December 31, 2024, SWEPCo had a net under-recovered fuel balance of $22 million, inclusive of costs related to the Dolet Hills Power Station billed by DHLC, but excluding impacts of the February 2021 severe winter weather event. In March 2021, the LPSC issued an order allowing SWEPCo to recover up to $20 million of fuel costs in 2021 and defer approximately $35 million of additional costs with a recovery period to be determined at a later date. In August 2022, the LPSC staff filed testimony recommending fuel disallowances of up to $55 million, including denial of recovery of the $35 million deferral, with refunds to customers over five years. In February 2024, an ALJ issued a final recommendation which included a proposed $55 million refund to customers and the denial of recovery of the $35 million deferral. SWEPCo filed a motion to present oral arguments with the LPSC to dispute the ALJ’s recommendations. In April 2024, the LPSC approved a unanimous settlement agreement filed by SWEPCo, LPSC staff and certain intervenors that resolved the fuel recovery dispute and resulted in a fuel disallowance of $11 million. The remaining $24 million regulatory asset balance will be recovered over three years with interest. In March 2021, the APSC approved fuel rates that provide recovery of $20 million for the Arkansas share of the 2021 Dolet Hills Power Station fuel costs over five years through the existing fuel clause. In September 2023, the PUCT approved an unopposed settlement agreement that provides recovery of $48 million of Oxbow mine related costs through 2035. If any of these costs are not recoverable or customer refunds are required, it could reduce future net income and cash flows and impact financial condition. Pirkey Plant and Related Fuel Operations (Applies to AEP and SWEPCo) In March 2023, the Pirkey Plant was retired. SWEPCo is recovering, or will seek recovery of, the remaining net book value of Pirkey Plant non-fuel costs. As of December 31, 2024, SWEPCo’s share of the net investment in the Pirkey Plant was $188 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 December 31, 2024, SWEPCo had a net under-recovered fuel balance of $22 million, inclusive of costs related to the Pirkey Plant billed by Sabine, but excluding impacts of the February 2021 severe winter weather event. Remaining operational, reclamation and other land-related costs incurred by Sabine will be billed to SWEPCo and included in existing fuel clauses. In July 2023, the LPSC ordered that a separate proceeding be established to review the prudence of the decision to retire the Pirkey Plant, including the costs included in fuel for years starting in 2019 and after. In November 2024, the LPSC staff submitted testimony recommending a $5 million fuel disallowance and a lower return on the remaining Pirkey Plant balance or recovery of the retired plant balance at a rate less than SWEPCo’s weighted average cost of capital. In December 2024, SWEPCo filed its rebuttal testimony explaining why there should be no disallowance. A hearing is scheduled for March 2025. In September 2023, the PUCT approved an unopposed settlement agreement that provides recovery of $33 million of Sabine related fuel costs through 2035. In June 2024, SWEPCo filed a fuel reconciliation with the PUCT for its retail operation in Texas for the period of January 2022 through December 2023. In January 2025, intervenors filed testimony recommending a disallowance for fuel costs ranging from $2 million and $25 million related to SWEPCo’s decision to retire the Pirkey Plant, management of fuel inventory and SWEPCo’s energy price offers in SPP. Also, in January 2025, the PUCT staff filed testimony agreeing with SWEPCo’s filed fuel reconciliation. In February 2025, SWEPCo filed rebuttal testimony explaining why there should be no disallowance. If any of these costs are not recoverable or customer refunds are required, it could reduce future net income and cash flows and impact financial condition. Regulatory Assets and Liabilities Regulatory assets and liabilities are comprised of the following items: AEP December 31, Remaining Recovery Period 2024 2023 Current Regulatory Assets (in millions) Under-recovered Fuel Costs - earns a return $ 245.7 $ 357.4 1 year Under-recovered Fuel Costs - does not earn a return 116.0 62.7 1 year Unrecovered Winter Storm Fuel Costs - earns a return (a) 84.2 93.9 1 year Total Current Regulatory Assets $ 445.9 $ 514.0 Noncurrent Regulatory Assets Regulatory assets pending final regulatory approval: Regulatory Assets Currently Earning a Return Welsh Plant, Units 1 and 3 Accelerated Depreciation $ 168.6 $ 125.6 Pirkey Plant Accelerated Depreciation 121.3 114.4 Storm-Related Costs 51.0 — Unrecovered Winter Storm Fuel Costs (a) 33.5 60.1 Other Regulatory Assets Pending Final Regulatory Approval 20.7 49.8 Total Regulatory Assets Currently Earning a Return 395.1 349.9 Regulatory Assets Currently Not Earning a Return Plant Retirement Costs - Asset Retirement Obligation Costs (b) 357.4 25.9 Storm-Related Costs 300.8 408.9 NOLC - Costs (c) 92.8 — 2024-2025 Virginia Under-Earnings 78.4 — Other Regulatory Assets Pending Final Regulatory Approval 86.3 52.6 Total Regulatory Assets Currently Not Earning a Return 915.7 487.4 Total Regulatory Assets Pending Final Regulatory Approval 1,310.8 837.3 Regulatory assets approved for recovery: Regulatory Assets Currently Earning a Return Plant Retirement Costs - Unrecovered Plant (d) 661.2 664.2 22 years Long-term Under-recovered Fuel Costs - West Virginia 283.8 291.5 10 years Plant Retirement Costs - Asset Retirement Obligation Costs 111.0 110.8 16 years Storm-Related Costs 106.7 170.9 7 years Fuel Mine Closure Costs - Texas 70.6 74.3 11 years Pirkey Plant Accelerated Depreciation - Louisiana 66.4 65.8 8 years Unrecovered Winter Storm Fuel Costs (a) 62.8 99.3 3 years Kentucky Deferred Purchased Power Expenses 45.0 43.5 3 years Rockport Plant Dry Sorbent Injection System and Selective Catalytic Reduction 37.3 46.9 4 years Texas Mobile Temporary Emergency Electric Energy Facilities Rider 32.6 33.4 2 years Environmental Control Projects 29.1 31.4 16 years Ohio Basic Transmission Cost Rider 26.1 42.2 2 years Plant Retirement Costs - Unrecovered Plant, Dolet Hills Power Station, Louisiana 19.0 40.8 8 years Long-term Under-recovered Fuel Costs - Virginia — 107.0 Other Regulatory Assets Approved for Recovery 159.9 124.9 various Total Regulatory Assets Currently Earning a Return 1,711.5 1,946.9 Regulatory Assets Currently Not Earning a Return Pension and OPEB Funded Status 974.2 1,054.1 12 years Plant Retirement Costs - Asset Retirement Obligation Costs 360.1 330.2 18 years Unamortized Loss on Reacquired Debt 90.9 97.2 24 years Storm-Related Costs 66.5 38.5 7 years Fuel and Purchased Power Adjustment Rider 57.4 68.3 2 years Unrealized Loss on Forward Commitments 53.3 131.4 8 years OVEC Purchased Power 52.0 50.1 2 years Plant Retirement Costs - Unrecovered Plant, Texas 44.5 48.7 22 years Cook Plant Nuclear Refueling Outage Levelization 43.0 55.7 3 years Smart Grid Costs 33.8 26.3 2 years Postemployment Benefits 27.9 30.6 3 years Ohio Enhanced Service Reliability Plan 26.2 35.3 2 years 2020-2022 Virginia Triennial Under Earnings 26.0 37.4 3 years Ohio Distribution Investment Rider 11.0 35.3 2 years Other Regulatory Assets Approved for Recovery 240.1 269.1 various Total Regulatory Assets Currently Not Earning a Return 2,106.9 2,308.2 Total Regulatory Assets Approved for Recovery 3,818.4 4,255.1 Total Noncurrent Regulatory Assets $ 5,129.2 $ 5,092.4 (a) See “February 2021 Severe Winter Weather Impacts in SPP” section of Note 4 for additional information. (b) See “Federal EPA’s Revised CCR Rule” section of Note 6 for additional information. (c) In the second quarter of 2024, requests seeking to establish a recovery mechanism for these regulatory assets were filed in Indiana, Oklahoma and Texas. In Indiana and Oklahoma, certain intervenors have challenged the recovery, or have proposed ratemaking treatment that would offset the recovery, of the regulatory assets. In the third quarter of 2024, PUCT Staff and certain intervenors in Texas requested a hearing and direct testimony was filed by SWEPCo in October 2024. In the fourth quarter of 2024, hearings on the merits were held in Indiana and Oklahoma. In January 2025, a second hearing on the merits in Oklahoma was held. A hearing is scheduled for the first quarter of 2025 in Texas. (d) Northeastern Plant, Unit 3 is approved for recovery through 2040, but expected to retire in 2026. PSO records a regulatory asset for accelerated depreciation. See “Regulated Generating Units to be Retired” section above for additional information. AEP December 31, Remaining 2024 2023 Refund Period Current Regulatory Liabilities (in millions) Over-recovered Fuel Costs - pays a return $ 21.6 $ 3.3 1 year Over-recovered Fuel Costs - does not pay a return 31.9 23.2 1 year Total Current Regulatory Liabilities $ 53.5 $ 26.5 Noncurrent Regulatory Liabilities and Regulatory liabilities pending final regulatory determination: Regulatory Liabilities Currently Paying a Return Income Taxes, Net (a) $ 176.0 $ 103.1 Total Regulatory Liabilities Currently Paying a Return 176.0 103.1 Regulatory Liabilities Currently Not Paying a Return FERC 2021 Transmission Formula Rate Challenge Refunds 131.3 103.1 Other Regulatory Liabilities Pending Final Regulatory Determination 14.7 1.7 Total Regulatory Liabilities Currently Not Paying a Return 146.0 104.8 Total Regulatory Liabilities Pending Final Regulatory Determination 322.0 207.9 Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs 3,828.0 3,563.5 (b) Income Taxes, Net (a) 1,622.1 2,179.7 (c) Rockport Plant, Unit 2 Accelerated Depreciation for Leasehold Improvements 35.9 44.9 4 years Other Regulatory Liabilities Approved for Payment 40.4 35.0 various Total Regulatory Liabilities Currently Paying a Return 5,526.4 5,823.1 Regulatory Liabilities Currently Not Paying a Return Excess Nuclear Decommissioning Funding 2,137.3 1,721.9 (d) Deferred Investment Tax Credits 65.1 154.5 29 years Demand Side Management 52.6 31.3 2 years Spent Nuclear Fuel 50.4 47.6 (d) 2017-2019 Virginia Triennial Revenue Provision 35.2 37.1 25 years Peak Demand Reduction/Energy Efficiency 32.8 26.4 2 years Over-recovered Fuel Costs - Ohio 32.1 26.1 8 years Other Regulatory Liabilities Approved for Payment 90.1 106.5 various Total Regulatory Liabilities Currently Not Paying a Return 2,495.6 2,151.4 Total Regulatory Liabilities Approved for Payment 8,022.0 7,974.5 Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits $ 8,344.0 $ 8,182.4 (a) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (b) Relieved as removal costs are incurred. (c) Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $192 million and $228 million for the years ended December 31, 2024 and 2023, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2024 is to be refunded over 10 years. (d) Relieved when plant is decommissioned. AEP Texas December 31, Remaining Regulatory Assets: 2024 2023 (in millions) Noncurrent Regulatory Assets Regulatory assets pending final regulatory approval: Regulatory Assets Currently Earning a Return Storm-Related Costs $ 41.3 $ — Total Regulatory Assets Currently Earning a Return 41.3 — Regulatory Assets Currently Not Earning a Return Deferred Pension and OPEB Costs 15.6 — Storm-Related Costs 13.1 37.7 Line Inspection Costs 5.8 5.7 Other Regulatory Assets Pending Final Regulatory Approval 1.3 20.9 Total Regulatory Assets Currently Not Earning a Return 35.8 64.3 Total Regulatory Assets Pending Final Regulatory Approval 77.1 64.3 Regulatory assets approved for recovery: Regulatory Assets Currently Earning a Return Texas Mobile Temporary Emergency Electric Energy Facilities Rider 32.6 33.4 2 years Meter Replacement Costs 5.8 9.4 2 years Other Regulatory Assets Approved for Recovery 22.4 0.7 various Total Regulatory Assets Currently Earning a Return 60.8 43.5 Regulatory Assets Currently Not Earning a Return Pension and OPEB Funded Status 177.5 183.2 12 years Texas Transmission Cost Recovery Factor 14.2 — 2 years Peak Demand Reduction/Energy Efficiency 9.2 9.2 2 years Other Regulatory Assets Approved for Recovery 14.8 15.1 various Total Regulatory Assets Currently Not Earning a Return 215.7 207.5 Total Regulatory Assets Approved for Recovery 276.5 251.0 Total Noncurrent Regulatory Assets $ 353.6 $ 315.3 AEP Texas December 31, Remaining Regulatory Liabilities: 2024 2023 (in millions) Noncurrent Regulatory Liabilities and Regulatory liabilities pending final regulatory determination: Regulatory Liabilities Currently Paying a Return Income Taxes, Net (a) $ — $ 13.0 Total Regulatory Liabilities Currently Paying a Return — 13.0 Regulatory Liabilities Currently Not Paying a Return Other Regulatory Liabilities Pending Final Regulatory Determination — 1.5 Total Regulatory Liabilities Currently Not Paying a Return — 1.5 Total Regulatory Liabilities Pending Final Regulatory Determination — 14.5 Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs 844.0 797.1 (b) Income Taxes, Net (a) 409.4 412.0 (c) Other Regulatory Liabilities Approved for Payment 4.8 3.8 various Total Regulatory Liabilities Currently Paying a Return 1,258.2 1,212.9 Regulatory Liabilities Currently Not Paying a Return Transition and Restoration Charges 21.6 26.6 5 years Other Regulatory Liabilities Approved for Payment 5.6 7.4 various Total Regulatory Liabilities Currently Not Paying a Return 27.2 34.0 Total Regulatory Liabilities Approved for Payment 1,285.4 1,246.9 Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits $ 1,285.4 $ 1,261.4 (a) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (b) Relieved as removal costs are incurred. (c) Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements was $22 million for the year ended December 31, 2024. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2024 is to be refunded over 5 years. AEPTCo December 31, Remaining Regulatory Assets: 2024 2023 (in millions) Noncurrent Regulatory Assets Regulatory assets approved for recovery: Regulatory Assets Currently Not Earning a Return PJM/SPP Annual Formula Rate True-up $ 0.4 $ 3.1 2 years Total Regulatory Assets Approved for Recovery 0.4 3.1 Total Noncurrent Regulatory Assets $ 0.4 $ 3.1 AEPTCo December 31, Remaining Regulatory Liabilities: 2024 2023 (in millions) Noncurrent Regulatory Liabilities Regulatory liabilities pending final regulatory determination: Regulatory Liabilities Currently Paying a Return Income Taxes, Net (a) $ 8.8 $ 8.7 Total Regulatory Liabilities Pending Final Regulatory Determination 8.8 8.7 Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs 582.3 466.3 (b) Income Taxes, Net (a) 287.3 308.7 (c) Total Regulatory Liabilities Approved for Payment 869.6 775.0 Total Noncurrent Regulatory Liabilities $ 878.4 $ 783.7 (a) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (b) Relieved as removal costs are incurred. (c) Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $9 million and $13 million for the years ended December 31, 2024 and 2023, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2024 is to be refunded over 4 years. APCo December 31, Remaining Regulatory Assets: 2024 2023 (in millions) Current Regulatory Assets Under-recovered Fuel Costs, Virginia - earns a return $ 148.1 $ 147.4 1 year Under-recovered Fuel Costs, West Virginia - does not earn a return — 8.0 1 year Total Current Regulatory Assets $ 148.1 $ 155.4 Noncurrent Regulatory Assets Regulatory assets pending final regulatory approval: Regulatory Assets Currently Earning a Return Other Regulatory Assets Pending Final Regulatory Approval $ 1.1 $ 0.6 Total Regulatory Assets Currently Earning a Return 1.1 0.6 Regulatory Assets Currently Not Earning a Return Plant Retirement Costs - Asset Retirement Obligation Costs (a) 282.1 25.9 Storm-Related Costs - West Virginia 144.2 91.5 2024-2025 Virginia Under-Earnings 78.4 — Pension Settlement 17.8 — Other Regulatory Assets Pending Final Regulatory Approval 11.9 7.5 Total Regulatory Assets Currently Not Earning a Return 534.4 124.9 Total Regulatory Assets Pending Final Regulatory Approval 535.5 125.5 Regulatory assets approved for recovery: Regulatory Assets Currently Earning a Return Long-term Under-recovered Fuel Costs - West Virginia 154.1 154.2 10 years Plant Retirement Costs - Unrecovered Plant 68.0 72.0 19 years Long-term Under-recovered Fuel Costs - Virginia — 107.0 Other Regulatory Assets Approved for Recovery 5.2 7.1 various Total Regulatory Assets Currently Earning a Return 227.3 340.3 Regulatory Assets Currently Not Earning a Return Plant Retirement Costs - Asset Retirement Obligation Costs 307.5 324.7 15 years Pension and OPEB Funded Status 107.9 115.8 12 years Unamortized Loss on Reacquired Debt 67.0 70.7 21 years 2020-2022 Virginia Triennial Under-Earnings 26.0 37.4 3 years Peak Demand Reduction/Energy Efficiency 14.2 15.0 2 years Postemployment Benefits 13.2 14.9 3 years Vegetation Management Program - West Virginia 11.9 12.9 2 years Virginia Generation Rate Adjustment Clause 11.6 10.9 2 years Excess SO 2 Allowance Inventory - Virginia 10.5 11.8 8 years Virginia Transmission Rate Adjustment Clause 3.4 25.5 2 years Unrealized Loss on Forward Commitments — 21.9 Other Regulatory Assets Approved for Recovery 30.0 27.8 various Total Regulatory Assets Currently Not Earning a Return 603.2 689.3 Total Regulatory Assets Approved for Recovery 830.5 1,029.6 Total Noncurrent Regulatory Assets $ 1,366.0 $ 1,155.1 (a) See “Federal EPA’s Revised CCR Rule” section of Note 6 for additional information. APCo December 31, Remaining Regulatory Liabilities: 2024 2023 (in millions) Current Regulatory Liabilities Over-recovered Fuel Costs, West Virginia - does not pay a return $ 21.6 $ — 1 year Total Current Regulatory Liabilities $ 21.6 $ — Noncurrent Regulatory Liabilities and Regulatory liabilities pending final regulatory determination: Regulatory Liabilities Currently Paying a Return Income Taxes, Net (a) $ (6.3) $ 7.9 Total Regulatory Liabilities Currently Paying a Return (6.3) 7.9 Regulatory Liabilities Currently Not Paying a Return FERC 2021 Transmission Formula Rate Challenge Refunds 24.9 19.7 Total Regulatory Liabilities Currently Not Paying a Return 24.9 19.7 Total Regulatory Liabilities Pending Final Regulatory Determination 18.6 27.6 Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs 805.6 759.6 (b) Income Taxes, Net (a) 219.3 240.1 (c) Deferred Investment Tax Credits — 0.3 Total Regulatory Liabilities Currently Paying a Return 1,024.9 1,000.0 Regulatory Liabilities Currently Not Paying a Return 2017-2019 Virginia Triennial Revenue Provision 35.2 37.1 25 years Virginia Transmission Rate Adjustment Clause 10.2 1.5 2 years Energy Efficiency Rate Adjustment Clause - Virginia 10.0 3.2 2 years Other Regulatory Liabilities Approved for Payment 16.9 12.5 various Total Regulatory Liabilities Currently Not Paying a Return 72.3 54.3 Total Regulatory Liabilities Approved for Payment 1,097.2 1,054.3 Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits $ 1,115.8 $ 1,081.9 (a) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (b) Relieved as removal costs are incurred. (c) Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $12 million and $35 million for the years ended December 31, 2024 and 2023, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2024 is to be refunded over 4 years. I&M December 31, Remaining Regulatory Assets: 2024 2023 (in millions) Current Regulatory Assets Under-recovered Fuel Costs, Michigan - earns a return $ 10.6 $ 14.8 1 year Total Current Regulatory Assets $ 10.6 $ 14.8 Noncurrent Regulatory Assets Regulatory assets pending final regulatory approval: Regulatory Assets Currently Earning a Return Other Regulatory Assets Pending Final Regulatory Approval $ 6.4 $ 0.2 Total Regulatory Assets Currently Earning a Return 6.4 0.2 Regulatory Assets Currently Not Earning a Return Plant Retirement Costs - Asset Retirement Obligation Costs (a) 74.0 — NOLC Costs - Indiana (b) 26.7 — Storm-Related Costs - Indiana 6.3 29.7 Other Regulatory Assets Pending Final Regulatory Approval 1.6 3.3 Total Regulatory Assets Currently Not Earning a Return 108.6 33.0 Total Regulatory Assets Pending Final Regulatory Approval 115.0 33.2 Regulatory assets approved for recovery: Regulatory Assets Currently Earning a Return Plant Retirement Costs - Unrecovered Plant 98.0 122.5 4 years Rockport Plant Dry Sorbent Injection System and Selective Catalytic Reduction 37.3 46.9 4 years Cook Plant Uprate Project 20.5 22.9 9 years Deferred Cook Plant Life Cycle Management Project Costs - Michigan, FERC 10.1 11.1 10 years Cook Plant Turbine - Indiana 7.8 8.4 14 years Other Regulatory Assets Approved for Recovery 21.1 17.5 various Total Regulatory Assets Currently Earning a Return 194.8 229.3 Regulatory Assets Currently Not Earning a Return Income Taxes, Net 108.8 — (c) Cook Plant Nuclear Refueling Outage Levelization 43.0 55.7 3 years Storm-Related Costs - Indiana 20.2 3.4 4 years Pension and OPEB Funded Status 14.6 25.4 12 years Excess SO 2 Allowance Inventory - Indiana 11.9 14.8 4 years Unamortized Loss on Reacquired Debt 10.9 11.8 24 years Postemployment Benefits 7.3 7.0 3 years Environmental Cost Rider - Indiana 1.4 8.1 2 years Other Regulatory Assets Approved for Recovery 20.2 17.6 various Total Regulatory Assets Currently Not Earning a Return 238.3 143.8 Total Regulatory Assets Approved for Recovery 433.1 373.1 Total Noncurrent Regulatory Assets $ 548.1 $ 406.3 (a) See “Federal EPA’s Revised CCR Rule” section of Note 6 for additional information. (b) In the second quarter of 2024, a request seeking to establish a recovery mechanism for these regulatory assets were filed in Indiana. Certain intervenors have challenged the recovery, or have proposed ratemaking treatment that would offset the recovery, of the regulatory assets. In the fourth quarter of 2024, a hearing on the merits was held in Indiana. (c) Recovered over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements was $12 million for the year ended December 31, 2024 and is to be refunded over 4 years. I&M December 31, Remaining Regulatory Liabilities: 2024 2023 (in millions) Current Regulatory Liabilities Over-recovered Fuel Costs, Indiana - does not pay a return $ 10.3 $ 23.2 1 year Total Current Regulatory Liabilities $ 10.3 $ 23.2 Noncurrent Regulatory Liabilities and Regulatory liabilities pending final regulatory determination: Regulatory Liabilities Currently Paying a Return Income Taxes, Net (a) (b) $ — $ (103.0) Total Regulatory Liabilities Currently Paying a Return — (103.0) Regulatory Liabilities Currently Not Paying a Return FERC 2021 Transmission Formula Rate Challenge Refunds 28.9 22.8 Cook Plant PTC Deferral - Michigan 14.5 — Total Regulatory Liabilities Currently Not Paying a Return 43.4 22.8 Total Regulatory Liabilities Pending Final Regulatory Determination 43.4 (80.2) Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs 174.2 168.1 (c) Renewable Energy Surcharge - Michigan 24.3 26.6 2 years Income Taxes, Net (a) — 116.8 (d) Other Regulatory Liabilities Approved for Payment 0.1 0.1 various Total Regulatory

COMMITMENTS, GUARANTEES AND CON

COMMITMENTS, GUARANTEES AND CONTINGENCIES	12 Months Ended
	Dec. 31, 2024
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS, GUARANTEES AND CONTINGENCIES	COMMITMENTS, GUARANTEES AND CONTINGENCIES The disclosures in this note apply to all Registrants unless indicated otherwise. The Registrants are subject to certain claims and legal actions arising in the ordinary course of business. In addition, the Registrants’ business activities are subject to extensive governmental regulation related to public health and the environment. The ultimate outcome of such pending or potential litigation against the Registrants cannot be predicted. Management accrues contingent liabilities only when management concludes that it is both probable that a liability has been incurred at the date of the financial statements and the amount of loss can be reasonably estimated. When management determines that it is not probable, but rather reasonably possible that a liability has been incurred at the date of the financial statements, management discloses such contingencies and the possible loss or range of loss if such estimate can be made. Any estimated range is based on currently available information and involves elements of judgment and significant uncertainties. Any estimated range of possible loss may not represent the maximum possible loss exposure. Circumstances change over time and actual results may vary significantly from estimates. For current proceedings not specifically discussed below, management does not anticipate that the liabilities, if any, arising from such proceedings would have a material effect on the financial statements. COMMITMENTS (Applies to all Registrants except AEP Texas and AEPTCo) AEP subsidiaries have substantial commitments for fuel, energy and capacity contracts as part of the normal course of business. Certain contracts contain penalty provisions for early termination. In accordance with the accounting guidance for “Commitments”, the following tables summarize the Registrants’ actual contractual commitments as of December 31, 2024: Contractual Commitments - AEP Less Than 2-3 Years 4-5 Years After Total (in millions) Fuel Purchase Contracts (a) $ 1,002.0 $ 942.0 $ 475.7 $ 368.3 $ 2,788.0 Energy and Capacity Purchase Contracts 192.8 384.0 334.3 464.0 1,375.1 Total $ 1,194.8 $ 1,326.0 $ 810.0 $ 832.3 $ 4,163.1 Contractual Commitments - APCo Less Than 2-3 Years 4-5 Years After Total (in millions) Fuel Purchase Contracts (a) $ 506.7 $ 328.6 $ 167.0 $ 96.0 $ 1,098.3 Energy and Capacity Purchase Contracts 40.4 79.9 48.0 52.2 220.5 Total $ 547.1 $ 408.5 $ 215.0 $ 148.2 $ 1,318.8 Contractual Commitments - I&M Less Than 2-3 Years 4-5 Years After Total (in millions) Fuel Purchase Contracts (a) $ 151.5 $ 346.6 $ 220.7 $ 263.9 $ 982.7 Energy and Capacity Purchase Contracts 119.9 236.2 231.7 321.5 909.3 Total $ 271.4 $ 582.8 $ 452.4 $ 585.4 $ 1,892.0 Contractual Commitments - OPCo Less Than 2-3 Years 4-5 Years After Total (in millions) Energy and Capacity Purchase Contracts $ 33.2 $ 64.2 $ 66.3 $ 69.5 $ 233.2 Contractual Commitments - PSO Less Than 2-3 Years 4-5 Years After Total (in millions) Fuel Purchase Contracts (a) $ 27.4 $ 17.0 $ — $ — $ 44.4 Energy and Capacity Purchase Contracts 62.9 123.6 62.4 19.7 268.6 Total $ 90.3 $ 140.6 $ 62.4 $ 19.7 $ 313.0 Contractual Commitments - SWEPCo Less Than 2-3 Years 4-5 Years After Total (in millions) Fuel Purchase Contracts (a) $ 89.4 $ 46.6 $ — $ — $ 136.0 Energy and Capacity Purchase Contracts 11.5 13.2 — — 24.7 Total $ 100.9 $ 59.8 $ — $ — $ 160.7 (a) Represents contractual commitments to purchase coal, natural gas, uranium and other consumables as fuel for electric generation along with related transportation of the fuel. 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. In March 2024, AEP increased its $4 billion revolving credit facility to $5 billion and extended the due date from March 2027 to March 2029. Also, in March 2024, AEP extended the due date of its $1 billion revolving credit facility from March 2025 to March 2027. AEP may issue up to $1.2 billion as letters of credit under these revolving credit facilities on behalf of subsidiaries. As of December 31, 2024, 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 December 31, 2024 were as follows: Company Amount Maturity (in millions) AEP $ 238.0 January 2025 to November 2025 AEP Texas 1.8 July 2025 Indemnifications and Other Guarantees Contracts The Registrants enter into certain types of contracts which require indemnifications. Typically these contracts include, but are not limited to, sale agreements, lease agreements, purchase agreements and financing agreements. Generally, these agreements may include, but are not limited to, indemnifications around certain tax, contractual and environmental matters. With respect to sale agreements, exposure generally does not exceed the sale price. As of December 31, 2024, there were no material liabilities recorded for any indemnifications. AEPSC conducts power purchase-and-sale activity on behalf of APCo, I&M, KPCo and WPCo, who are jointly and severally liable for activity conducted on their behalf. AEPSC also conducts power purchase-and-sale activity on behalf of PSO and SWEPCo, who are jointly and severally liable for activity conducted on their behalf. Lease Obligations Certain Registrants lease equipment under master lease agreements. See “Master Lease Agreements” section of Note 13 for additional information. ENVIRONMENTAL CONTINGENCIES (Applies to All Registrants except AEPTCo) Federal EPA’s Revised CCR Rule In April 2024, the Federal EPA finalized revisions to the CCR Rule to expand the scope of the rule to include inactive impoundments at inactive facilities (“legacy CCR surface impoundments”) as well as to establish requirements for currently exempt solid waste management units that involve the direct placement of CCR on the land (“CCR management units”). The Federal EPA is requiring that owners and operators of legacy surface impoundments comply with all of the existing CCR Rule requirements applicable to inactive CCR surface impoundments at active facilities, except for the location restrictions and liner design criteria. The rule establishes compliance deadlines for legacy surface impoundments to meet regulatory requirements, including a requirement to initiate closure within five years after the effective date of the final rule. The rule requires evaluations to be completed at both active facilities and inactive facilities with one or more legacy surface impoundments. Closure may be accomplished by applying an impermeable cover system over the CCR material (“closure in place”) or the CCR material may be excavated and placed in a compliant landfill (“closure by removal”). Groundwater monitoring and other analysis over the next three years will provide additional information on the planned closure method. AEP evaluated the applicability of the rule to current and former plant sites and recorded incremental ARO in the second quarter of 2024, as shown in the table below, based on initial cost estimates primarily reflecting compliance with the rule through closure in place and future groundwater monitoring requirements pursuant to the revised CCR Rule. Registrant Increase in ARO Increase in Generation Property (a) Increase in Regulatory Assets (b) Charged to Operating Expenses (c) (in millions) APCo $ 312.2 $ 75.6 $ 236.6 $ — I&M 85.7 — 72.3 13.4 OPCo 52.9 — — 52.9 PSO 33.7 33.7 — — SWEPCo 23.8 23.8 — — Non-Registrants 166.1 43.8 46.1 76.2 Total $ 674.4 $ 176.9 $ 355.0 $ 142.5 (a) ARO is related to a legacy CCR surface impoundment or CCR management unit at an operating generation facility. (b) ARO is related to a legacy CCR surface impoundment or CCR management unit at a retired generation facility and recognition of a regulatory asset in accordance with the accounting guidance for “Regulated Operations” is supported. (c) ARO is related to a legacy CCR surface impoundment or CCR management unit and recognition of a regulatory asset in accordance with the accounting guidance for “Regulated Operations” is not yet supported. As further groundwater monitoring and other analysis is performed, management expects to refine the assumptions and underlying cost estimates used in recording the ARO. These refinements may include, but are not limited to, changes in the expected method of closure, changes in estimated quantities of CCR at each site, the identification of new CCR management units, among other items. These future changes could have a material impact on the ARO and materially reduce future net income and cash flows and further impact financial condition. AEP will seek cost recovery through regulated rates, including proposal of new regulatory mechanisms for cost recovery where existing mechanisms are not applicable. The rule could have an additional, material adverse impact on net income, cash flows and financial condition if AEP cannot ultimately recover these additional costs of compliance. Several parties, including AEP and one of its trade associations, have filed petitions for review of the rule with the U.S. Court of Appeals for the D.C. Circuit. One of the parties also filed a motion to stay the rule pending the outcome of the litigation. In November 2024, the court denied the stay motion. Management cannot predict the outcome of the litigation. The Comprehensive Environmental Response Compensation and Liability Act (Superfund) and State Remediation By-products from the generation of electricity include materials such as ash, slag, sludge, low-level radioactive waste and SNF. Coal combustion by-products, which constitute the overwhelming percentage of these materials, are typically treated and deposited in captive disposal facilities or are beneficially utilized. In addition, the generation plants and transmission and distribution facilities have used asbestos, polychlorinated biphenyls and other hazardous and non-hazardous materials. The Registrants currently incur costs to dispose of these substances safely. Superfund addresses clean-up of hazardous substances that are released to the environment. The Federal EPA administers the clean-up programs. Several states enacted similar laws. As of December 31, 2024, AGR, APCo, OPCo and SWEPCo are named as a Potentially Responsible Party (PRP) for one, one, two and one sites, respectively, by the Federal EPA for which alleged liability is unresolved. There are 11 additional sites for which APCo, I&M, KPCo, OPCo and SWEPCo received information requests which could lead to PRP designation. In those instances where a PRP or defendant has been named, disposal or recycling activities were in accordance with the then-applicable laws and regulations. Superfund does not recognize compliance as a defense, but imposes strict liability on parties who fall within its broad statutory categories. Liability has been resolved for a number of sites with no significant effect on net income. Management evaluates the potential liability for each Superfund site separately, but several general statements can be made about potential future liability. Allegations that materials were disposed at a particular site are often unsubstantiated and the quantity of materials deposited at a site can be small and often non-hazardous. Although Superfund liability has been interpreted by the courts as joint and several, typically many parties are named as PRPs for each site and several of the parties are financially sound enterprises. As of December 31, 2024, management’s estimates do not anticipate material clean-up costs for identified Superfund sites. NUCLEAR CONTINGENCIES (APPLIES TO AEP AND I&M) I&M owns and operates the two-unit 2,296 MW Cook Plant under licenses granted by the NRC. I&M has a significant future financial commitment to dispose of SNF and to safely decommission and decontaminate the plant. The licenses to operate the two nuclear units at the Cook Plant expire in 2034 and 2037. Management has started the application process for license extensions for both units that would extend Unit 1 and Unit 2 to 2054 and 2057, respectively. The operation of a nuclear facility also involves special risks, potential liabilities and specific regulatory and safety requirements. By agreement, I&M is partially liable, together with all other electric utility companies that own nuclear generation units, for a nuclear power plant incident at any nuclear plant in the U.S. Should a nuclear incident occur at any nuclear power plant in the U.S., the resultant liability could be substantial. Decommissioning and Low-Level Waste Accumulation Disposal The costs to decommission a nuclear plant are affected by NRC regulations and the SNF disposal program. Decommissioning costs are accrued over the service life of Cook Plant. The most recent decommissioning cost study was performed in 2024. According to that study, stated in 2024 undiscounted dollars, the estimated cost of decommissioning and disposal of low-level radioactive waste was $2.4 billion, with additional ongoing costs of $7 million per year for post decommissioning storage of SNF and an eventual cost of $45 million for the subsequent decommissioning of the SNF storage facility. I&M recovers estimated decommissioning costs for the Cook Plant in its rates. The amounts recovered in rates were $1 million, $2 million and $2 million for the years ended December 31, 2024, 2023 and 2022, respectively. Decommissioning costs recovered from customers are deposited in external trusts. As of December 31, 2024 and 2023, the total decommissioning trust fund balances were $4 billion and $3.5 billion, respectively. The increase in the trust fund balance was driven by favorable investment performance in 2024. Trust fund earnings increase the fund assets and may decrease the amount remaining to be recovered from customers. Trust fund losses decrease the fund assets and may increase the amount remaining to be recovered from customers. The decommissioning costs (including unrealized gains and losses, interest and trust funds expenses) increase or decrease the recorded liability. I&M continues to work with regulators and customers to establish rates designed to collect the estimated costs of decommissioning the Cook Plant. However, future net income and cash flows would be reduced and financial condition could be impacted if the cost of SNF disposal and decommissioning increases and cannot be recovered. Spent Nuclear Fuel Disposal The federal government is responsible for permanent SNF disposal and assesses fees to nuclear plant owners for SNF disposal. A fee of one-mill per KWh for fuel consumed after April 6, 1983 at the Cook Plant was collected from customers and remitted to the DOE through May 14, 2014. In May 2014, pursuant to court order from the U.S Court of Appeals for the District of Columbia Circuit, the DOE adjusted the fee to $0. As of December 31, 2024 and 2023, fees and related interest of $316 million and $300 million, respectively, for fuel consumed prior to April 7, 1983 were recorded as Long-term Debt and funds collected from customers along with related earnings totaling $367 million and $348 million, respectively, to pay the fee, were recorded as part of Spent Nuclear Fuel and Decommissioning Trusts on the balance sheets. I&M has not paid the government the pre-April 1983 fees due to continued delays and uncertainties related to the federal disposal program. In 2011, I&M signed a settlement agreement with the federal government which permits I&M to make annual filings to recover certain SNF storage costs incurred as a result of the government’s delay in accepting SNF for permanent storage. Under the settlement agreement, I&M received $12 million, $21 million and $3 million in 2024, 2023 and 2022, respectively, to recover costs and will be eligible to receive additional payment of annual claims for allowed costs that are incurred through December 31, 2024. The proceeds reduced costs for dry cask storage. As of December 31, 2024 and 2023, I&M deferred $11 million and $12 million, respectively, in Prepayments and Other Current Assets and $15 million and $9 million, respectively, in Deferred Charges and Other Noncurrent Assets on the balance sheets for dry cask storage and related operation and maintenance costs for recovery under this agreement. See “Fair Value Measurements of Trust Assets for Decommissioning and SNF Disposal” section of Note 11 for additional information. Nuclear Insurance I&M carries nuclear property insurance of $2.7 billion to cover a nuclear incident at Cook Plant including coverage for decontamination and stabilization, as well as premature decommissioning caused by a nuclear incident. Insurance coverage for a nonnuclear property incident at Cook Plant is $750 million. Additional insurance provides coverage for a weekly indemnity payment resulting from an insured accidental outage. I&M utilizes industry mutual insurers for the placement of this insurance coverage. Coverage from these industry mutual insurance programs require a contingent financial obligation of up to $47 million for I&M, which is assessable if the insurer’s financial resources would be inadequate to pay for industry losses. The Price-Anderson Act, extended through December 31, 2025, establishes insurance protection for public nuclear liability arising from a nuclear incident of $16.3 billion and applies to any incident at a licensed reactor in the U.S. Commercially available insurance, which must be carried for each licensed reactor, provides $500 million of primary coverage. In the event of a nuclear incident at any nuclear plant in the U.S., the remainder of the liability would be provided by a deferred premium assessment of $332 million per nuclear incident on Cook Plant’s reactors payable in annual installments of $49 million. The number of incidents for which payments could be required is not limited. In the event of an incident of a catastrophic nature, I&M is covered for public nuclear liability for the first $500 million through commercially available insurance. The next level of liability coverage of up to $15.8 billion would be covered by claim premium assessments made under the Price-Anderson Act. In the event nuclear losses or liabilities are underinsured or exceed accumulated funds, I&M would seek recovery of those amounts from customers through a rate increase. If recovery from customers is not possible, it could reduce future net income and cash flows and impact financial condition. OPERATIONAL CONTINGENCIES Insurance and Potential Losses The Registrants maintain insurance coverage normal and customary for electric utilities, subject to various deductibles. The Registrants also maintain property and casualty insurance that may cover certain physical damage or third-party injuries caused by cybersecurity incidents. Insurance coverage includes all risks of physical loss or damage to nonnuclear assets, subject to insurance policy conditions and exclusions. Covered property generally includes power plants, substations, facilities and inventories. Excluded property generally includes transmission and distribution lines, poles and towers. The insurance programs also generally provide coverage against loss arising from certain claims made by third-parties and are in excess of retentions absorbed by the Registrants. Coverage is generally provided by a combination of the protected cell of EIS and/or various industry mutual and/or commercial insurance carriers. See “Nuclear Contingencies” section above for additional information. In July 2024, the Registrants renewed insurance programs including coverage for wildfire liability. Some potential losses or liabilities may not be insurable or the amount of insurance carried may not be sufficient to meet potential losses and liabilities, including, but not limited to, liabilities relating to a cybersecurity incident, extreme weather or wildfire related liabilities or damage to the Cook Plant and costs of replacement power in the event of an incident at the Cook Plant. Future losses or liabilities, if they occur, which are not completely insured, unless recovered through the rate-making process, could reduce future net income and cash flows and impact financial condition. Litigation Related to Ohio House Bill 6 (HB 6) (Applies to AEP and OPCo) In 2019, Ohio adopted and implemented HB 6 which benefits OPCo by authorizing rate recovery for certain costs including renewable energy contracts and OVEC’s coal-fired generating units. OPCo engaged in lobbying efforts and provided testimony during the legislative process in connection with HB 6. In July 2020, an investigation led by the U.S. Attorney’s Office resulted in a federal grand jury indictment of an Ohio legislator and associates in connection with an alleged racketeering conspiracy involving the adoption of HB 6. After AEP learned of the criminal allegations against the Ohio legislator and others relating to HB 6, AEP, with assistance from outside advisors, conducted a review of the circumstances surrounding the passage of the bill. Management does not believe that AEP was involved in any wrongful conduct in connection with the passage of HB 6. In August 2020, an AEP shareholder filed a putative class action lawsuit in the 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 (collectively, the “Derivative Actions”) together assert claims for: (a) breach of fiduciary duty, (b) waste of corporate assets, (c) unjust enrichment, (d) breach of duty for insider trading and (e) contribution for violations of sections 10(b) and 21D of the Securities Exchange Act of 1934; and seek monetary damages and changes to AEP’s corporate governance and internal policies among other forms of relief. The court entered a scheduling order in the New York state court derivative action staying the case other than with respect to briefing the motion to dismiss. AEP filed substantive and forum-based motions to dismiss in April 2022. In June 2022, the Ohio state court entered an order continuing the stays of that case until the final resolution of the consolidated derivative actions pending in Ohio federal district court. In September 2022, the New York state court granted the forum-based motion to dismiss with prejudice and the plaintiff subsequently filed a notice of appeal with the New York appellate court. In January 2023, the New York plaintiff filed a motion to intervene in the pending Ohio federal court action and withdrew his appeal in New York. The two derivative actions pending in federal district court in Ohio have been consolidated and the plaintiffs in the consolidated action filed an amended complaint. AEP filed a motion to dismiss the amended complaint and subsequently filed a brief in opposition to the New York plaintiffs’ motion to intervene in the consolidated action in Ohio. In March 2023, the federal district court issued an order granting the motion to dismiss with prejudice and denying the New York plaintiffs’ motion to intervene. In April 2023, one of the plaintiffs filed a notice of appeal to the U.S. Court of Appeals for the Sixth Circuit of the Ohio federal district court order dismissing the consolidated action and denying the intervention. 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 letter from counsel representing the purported AEP shareholder who had 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). The Litigation Demand is directed to the AEP Board and contains factual allegations involving HB 6 that are generally consistent with those in the Derivative Actions. The Litigation Demand requested, 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 asserting claims similar to the claims asserted in the Derivative Actions. The AEP Board considered the Litigation Demand and formed a committee of the Board (the Demand Review Committee) to investigate, review, monitor and analyze the Litigation Demand and make a recommendation to the AEP Board regarding a reasonable and appropriate response to the same. In April 2024, AEP reached an agreement with the four shareholders to fully and finally resolve the Derivative Actions and the Litigation Demand, and all claims asserted or that could have been asserted by any AEP shareholder based on the facts alleged, in the manner and upon the terms and conditions set forth in the settlement documents (the Settlement). In July 2024, the U.S. District Court preliminarily approved the Settlement. The Settlement includes a payment of $450 thousand for attorneys’ fees and the implementation of certain governance changes outlined in the Settlement, many of which previously had been put in place. The Settlement does not include any admission of liability. In October 2024, the District Court issued an Order and Judgment approving the Settlement and granted an Order of Dismissal with Prejudice. Under the Settlement, all Derivative Actions have been dismissed, the Litigation Demand has been withdrawn, and those matters and claims have been resolved pursuant to the terms of the Settlement. 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. In January 2025, AEP and the SEC reached a settlement concluding and resolving the SEC’s investigation concerning AEP’s relationship with and statements about Empowering Ohio’s Economy, a 501(c)(4) organization and AEP’s related internal accounting and disclosure controls. Under the terms of the administrative order, in which AEP neither admits nor denies the SEC’s findings, AEP agreed to pay a civil penalty of $19 million and to cease and desist from committing or causing any violations and any future violations of the specified provisions of the federal securities laws. AEP recorded an accrual for the full amount of the penalty in the third quarter of 2024. The $19 million penalty is included in Other Operation expenses on AEP’s statements of income and in Other Current Liabilities on AEP’s balance sheet. Claims for Indemnification Made by Owners of the Gavin Power Station (Applies to AEP) In November 2022, the Federal EPA issued a final decision denying Gavin Power LLC’s requested extension to allow a CCR surface impoundment at the Gavin Power Station to continue to receive CCR and non-CCR waste streams after April 11, 2021 until May 4, 2023 (the Gavin Denial). As part of the Gavin Denial, the Federal EPA made several assertions related to the CCR Rule (see “Environmental Issues - CCR Rule” section of Management’s Discussion and Analysis of Financial Condition and Results of Operations for additional information), including an assertion that the closure of the 300 acre unlined fly ash reservoir (FAR) is noncompliant with the CCR Rule in multiple respects. The Gavin Power Station was formerly owned and operated by AEP and was sold to Gavin Power LLC and Lightstone Generation LLC in 2017. Pursuant to the PSA, AEP maintained responsibility to complete closure of the FAR in accordance with the closure plan approved by the Ohio EPA which was completed in July 2021. The PSA contains indemnification provisions, pursuant to which the owners of the Gavin Power Station have notified AEP they believe they are entitled to indemnification for any damages that may result from these claims, including any future enforcement or litigation resulting from any determinations of noncompliance by the Federal EPA with various aspects of the CCR Rule consistent with the Gavin Denial. The owners of the Gavin Power Station have also sought indemnification for landowner claims for property damage allegedly caused by modifications to the FAR. Management does not believe that the owners of the Gavin Power Station have any valid claim for indemnity or otherwise against AEP under the PSA. In January 2024, Gavin Power LLC also filed a complaint with the United States District Court for the Southern District of Ohio, alleging various violations of the Administrative Procedure Act and asserting that the Federal EPA, through its prior inaction, has waived and is estopped from raising certain objections raised in the Gavin Denial. Management is unable to determine a range of potential losses that is reasonably possible of occurring. Litigation Regarding Justice Thermal Coal Contract In December 2023, APCo filed a suit in the Franklin County Ohio Court of Common Pleas seeking a declaratory judgment confirming APCo’s right to terminate a long-term coal contract with Justice Thermal LLC (Justice Thermal) based on Justice Thermal’s failure to perform under the contract. APCo terminated that contract in January 2024, and in April 2024, APCo filed an amended complaint seeking a declaration that the termination was proper and also seeking damages for Justice Thermal’s breach of contract. Justice Thermal filed an answer and counterclaim in April 2024, contesting the validity of the contract termination and asserting counterclaims. The parties entered into a Settlement Agreement and Release pursuant to which the litigation was dismissed with prejudice in September 2024 and each party released the other from all claims relating to the contract or the litigation, and as a result this matter has been resolved.

ACQUISITIONS, DISPOSITIONS AND

ACQUISITIONS, DISPOSITIONS AND IMPAIRMENTS	12 Months Ended
	Dec. 31, 2024
Discontinued Operations and Disposal Groups [Abstract]
ACQUISITIONS, DISPOSITIONS AND IMPAIRMENTS	ACQUISITIONS, DISPOSITIONS AND IMPAIRMENTS The disclosures in this note apply to AEP unless indicated otherwise. ACQUISITIONS North Central Wind Energy Facilities (Vertically Integrated Utilities Segment) (Applies to AEP, PSO and SWEPCo) In 2020, PSO and SWEPCo received regulatory approvals to acquire the NCWF, comprised of three Oklahoma wind facilities totaling 1,484 MWs, on a fixed cost turn-key basis. PSO and SWEPCo own undivided interests of 45.5% and 54.5% of the NCWF, respectively. In total, the three wind facilities cost approximately $2 billion and consist of Traverse (998 MW), Maverick (287 MW) and Sundance (199 MW). Output from the NCWF serves retail load in PSO’s Oklahoma service territory and both retail and FERC wholesale load in SWEPCo’s service territories in Arkansas and Louisiana. The Oklahoma and Louisiana portions of the NCWF revenue requirement, net of PTC benefit, are recoverable through authorized riders until the amounts are reflected in base rates. Recovery of the Arkansas portion of the NCWF revenue requirement through base rates was approved by the APSC in May 2022. The NCWF are subject to various regulatory performance requirements. If these performance requirements are not met, PSO and SWEPCo would recognize a regulatory liability to refund retail customers. In March 2022, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Traverse, the final NCWF project, during its development and construction for $1.2 billion. Traverse was placed in-service in March 2022. Immediately following the acquisition, PSO and SWEPCo liquidated the entity and simultaneously distributed the assets in proportion to their undivided ownership interests. 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,” AEP management determined that the acquisition of the Rock Falls Wind Facility represents an asset acquisition. The lease obligations related to Rock Falls were not material at the time of acquisition. Diversion Wind Farm (Vertically Integrated Utilities Segment) (Applies to AEP and SWEPCo) In December 2024, SWEPCo acquired 100% of the equity interests in Diversion Wind Energy, LLC, the owner of Diversion wind farm. The Diversion wind farm is a newly constructed 201 MW wind facility located in Baylor County, Texas and was placed in service in December 2024. Output from Diversion serves FERC wholesale load and retail customers in Arkansas and Louisiana. SWEPCo’s Louisiana jurisdictional share of the Diversion revenue requirement, net of PTC benefit, is recoverable through an authorized rider until the amounts are reflected in base rates. Recovery of the Arkansas portion of the Diversion revenue requirement is expected to begin in 2026 through base rates. Regulatory commission approval of the inclusion of the output from Diversion in retail rates resulted in various capital cost, performance and other guarantees for retail customers which could subject SWEPCo to future regulatory liabilities to retail customers. In accordance with the guidance for “Business Combinations,” management determined that the acquisition of the Diversion project represents an asset acquisition. As of December 31, 2024, SWEPCo had approximately $423 million of gross Property, Plant and Equipment, inclusive of capital expenditures after the acquisition, on the balance sheets related to the Diversion project. The acquisition also resulted in the recognition of $20 million of operating leases that provide for easement and access rights to the land that Diversion was built upon and $6 million of AROs. DISPOSITIONS Disposition of AEP OnSite Partners (Generation & Marketing Segment) (Applies to AEP) In April 2023, AEP initiated a sales process for its ownership in AEP OnSite Partners. AEP OnSite Partners targeted opportunities in distributed solar, combined heat and power, energy storage, waste heat recovery, energy efficiency, peaking generation and other energy solutions. In May 2024, AEP signed an agreement to sell AEP OnSite Partners to a nonaffiliated third-party. In September 2024, AEP completed the sale and received cash proceeds of approximately $318 million, net of taxes and transaction costs. The proceeds were used to pay down short-term debt. Disposition of NMRD (Generation & Marketing Segment) (Applies to AEP) In December 2023, AEP and the joint owner signed an agreement to sell NMRD to a nonaffiliated third party and the sale was completed in February 2024. AEP received cash proceeds of approximately $107 million, net of taxes and transaction costs. The transaction did not have a material impact on net income or financial condition. 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. As a result of delays in the anticipated timing of the closing of the transaction and other factors, AEP recorded a $363 million pretax loss on the expected sale of the Kentucky Operations for the year ended December 31, 2022. 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. Upon termination of the sale and reverting to a held and used model, in the first quarter of 2023, AEP reversed $28 million of expected transaction costs included in the $363 million pretax loss and was required to present its investment in the Kentucky Operations at the lower of fair value or historical carrying value which resulted in a $335 million reduction recorded in Property, Plant and Equipment. The reduced investment in KPCo’s assets is being amortized over the 30-year average useful life of the KPCo assets. Disposition of the Competitive Contracted Renewables Portfolio (Generation & Marketing Segment) (Applies to AEP) In February 2022, AEP management announced the initiation of a process to sell all or a portion of AEP Renewables’ competitive contracted renewables portfolio (the portfolio) within the Generation & Marketing segment. In late January 2023, AEP received final bids from interested parties. In February 2023, AEP’s Board of Directors approved management’s plan to sell the portfolio and AEP signed an agreement with a nonaffiliated party. In August 2023, AEP completed the sale of the entire portfolio to the nonaffiliated party and received cash proceeds of approximately $1.2 billion, net of taxes and transaction costs. AEP recorded a pretax loss of $93 million ($73 million after-tax) for the year ended December 31, 2023 related to the sale. Disposition of Mineral Rights (Generation & Marketing Segment) (Applies to AEP) In June 2022, AEP closed on the sale of certain mineral rights to a nonaffiliated third-party and received $120 million of proceeds. The sale resulted in a pretax gain of $116 million in the second quarter of 2022. IMPAIRMENTS 2012 Texas Base Rate Case (Vertically Integrated Utilities Segment) (Applies to AEP and SWEPCo) In December 2023, SWEPCo recorded a pretax, non-cash disallowance of $86 million in Asset Impairments and Other Related Charges on the statements of income due to regulatory disallowance of recovery of AFUDC on Turk Plant in the 2012 Texas Base Rate case. See the “2012 Texas Base Rate Case” section of Note 4 for additional information. NMRD (Generation & Marketing Segment) (Applies to AEP) In December 2023, as a result of sale negotiations AEP determined a decline in the fair value of AEP’s investment in NMRD was other than temporary. In accordance with the accounting guidance for “Investment - Equity Method and Joint Ventures”, in the fourth quarter of 2023 AEP recorded a pretax other than temporary impairment charge of $19 million which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s statement of income. AEP’s determination of fair value utilized the accounting guidance for Fair Value Measurement market approach to valuation and was based on negotiations to sell the investment to a nonaffiliated third-party. The carrying value of the investment in NMRD was not material to AEP as of December 31, 2023. Flat Ridge 2 Wind LLC (Generation & Marketing Segment) (Applies to AEP) In 2019, AEP acquired a 50% ownership interest in five non-consolidated joint ventures, including Flat Ridge 2 Wind LLC (Flat Ridge 2), and two tax equity partnerships. The five non-consolidated joint ventures are jointly owned and operated by BP Wind Energy. Flat Ridge 2 sells electricity to three counterparties through long-term PPAs. Regarding AEP’s investment in Flat Ridge 2, in June 2022, as a result of Flat Ridge 2’s deteriorating financial performance, sale negotiations and AEP’s ongoing evaluation and ultimate decision to exit the investment in the near term, AEP determined a decline in the fair value of AEP’s investment in Flat Ridge 2 was other than temporary. In accordance with the accounting guidance for “Investments - Equity Method and Joint Ventures”, in the second quarter of 2022 AEP recorded a pretax other than temporary impairment charge of $186 million which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s statement of income. AEP’s determination of fair value utilized the accounting guidance for Fair Value Measurement market approach to valuation and was based on negotiations to sell the investment to a nonaffiliated third-party. In the third quarter of 2022, AEP recorded an additional $2 million pretax other than temporary impairment charge which is presented in Equity Earnings (Losses) of Unconsolidated Subsidiaries on AEP’s statement of income. In September 2022, AEP signed a Purchase and Sale Agreement with a nonaffiliate third-party for AEP’s interest in Flat Ridge 2. The transaction closed in the fourth quarter of 2022 and had an immaterial impact on the financial statements. 2020 Texas Base Rate Case (Vertically Integrated Utilities Segment) (Applies to AEP and SWEPCo) In January 2022, the PUCT issued a final order which included a return of investment only for the recovery of the Dolet Hills Power Station. As a result of the final order, SWEPCo recorded a disallowance of $12 million associated with the lack of return on the Dolet Hills Power Station. In February 2022, SWEPCo filed a motion for rehearing with the PUCT challenging denial of a reasonable return or carrying costs on the Dolet Hills Power Station among other items. In April 2022, the PUCT denied the motion for rehearing. In May 2022, SWEPCo filed a petition for review with the Texas District Court seeking a judicial review of the several errors challenged in the PUCT’s final order. See “2020 Texas Base Rate Case” section of Note 4 for additional information.

BENEFIT PLANS

BENEFIT PLANS	12 Months Ended
	Dec. 31, 2024
Retirement Benefits [Abstract]
BENEFIT PLANS	BENEFIT PLANS The disclosures in this note apply to all Registrants except AEPTCo unless indicated otherwise. For a discussion of investment strategy, investment limitations, target asset allocations and the classification of investments within the fair value hierarchy, see “Fair Value Measurements of Assets and Liabilities” and “Investments Held in Trust for Future Liabilities” sections of Note 1. AEPSC sponsors a qualified pension plan and two unfunded non-qualified pension plans. Substantially all AEP subsidiary employees are covered by the qualified plan or both the qualified and a non-qualified pension plan. AEPSC also sponsors OPEB plans to provide health and life insurance benefits for retired employees. Due to the Registrant Subsidiaries’ participation in AEP’s benefit plans, the assumptions used by the actuary, with the exception of the rate of compensation increase, and the accounting for the plans by each subsidiary are the same. This section details the assumptions that apply to all Registrants and the rate of compensation increase for each Registrant. The Registrants recognize the funded status associated with defined benefit pension and OPEB plans on the balance sheets. Disclosures about the plans are required by the “Compensation – Retirement Benefits” accounting guidance. The Registrants recognize an asset for a plan’s overfunded status or a liability for a plan’s underfunded status, and recognize, as a component of other comprehensive income, the changes in the funded status of the plan that arise during the year that are not recognized as a component of net periodic benefit cost. The Registrants record a regulatory asset instead of other comprehensive income for qualifying benefit costs of regulated operations that for rate-making purposes are deferred for future recovery. The cumulative funded status adjustment is equal to the remaining unrecognized deferrals for unamortized actuarial losses or gains, prior service costs and transition obligations, such that remaining deferred costs result in an AOCI equity reduction or regulatory asset and deferred gains result in an AOCI equity addition or regulatory liability. Actuarial Assumptions for Benefit Obligations The weighted-average assumptions used in the measurement of the Registrants’ benefit obligations are shown in the following tables: Pension Plans OPEB December 31, Assumption 2024 2023 2024 2023 Discount Rate 5.65 % 5.15 % 5.60 % 5.15 % Interest Crediting Rate 4.55 % 4.00 % NA NA NA Not applicable. Assumption – Rate of Compensation Increase (a) - Pension Plans AEP AEP Texas APCo I&M OPCo PSO SWEPCo December 31, 2024 5.55 % 5.70 % 5.55 % 5.50 % 6.00 % 5.70 % 5.55 % December 31, 2023 5.05 % 5.20 % 4.95 % 5.05 % 5.45 % 5.20 % 5.00 % (a) Rates are for base pay only. In addition, an amount is added to reflect target incentive compensation for exempt employees and overtime and incentive pay for nonexempt employees. A duration-based method is used to determine the discount rate for the plans. A hypothetical portfolio of high quality corporate bonds is constructed with cash flows matching the benefit plan liability. The composite yield on the hypothetical bond portfolio is used as the discount rate for the plan. The discount rate is the same for each Registrant. For 2024, the rate of compensation increase assumed varies with the age of the employee, ranging from 3% per year to 11.5% per year, with the average increase shown in the table above. The compensation increase rates reflect variations in each Registrants’ population participating in the pension plan. Actuarial Assumptions for Net Periodic Benefit Costs The weighted-average assumptions used in the measurement of each Registrants’ benefit costs are shown in the following tables: Pension Plans OPEB Year Ended December 31, Assumption 2024 2023 2022 2024 2023 2022 Discount Rate 5.20 % 5.50 % 2.90 % 5.15 % 5.50 % 2.90 % Interest Crediting Rate 4.05 % 4.25 % 4.00 % NA NA NA Expected Return on Plan Assets 7.30 % 7.50 % 5.25 % 6.75 % 7.25 % 5.50 % NA Not applicable. Assumption – Rate of Compensation Increase (a) - Pension Plans AEP AEP Texas APCo I&M OPCo PSO SWEPCo December 31, 2024 5.10 % 5.25 % 5.10 % 5.10 % 5.50 % 5.20 % 5.10 % December 31, 2023 5.05 % 5.20 % 4.95 % 5.05 % 5.45 % 5.20 % 5.00 % December 31, 2022 5.05 % 5.15 % 4.90 % 5.00 % 5.35 % 5.15 % 5.00 % (a) Rates are for base pay only. In addition, an amount is added to reflect target incentive compensation for exempt employees and overtime and incentive pay for nonexempt employees . The expected return on plan assets was determined by evaluating historical returns, the current investment climate (yield on fixed income securities and other recent investment market indicators), rate of inflation, third-party forecasts and current prospects for economic growth. The expected return on plan assets is the same for each Registrant. The health care trend rate assumptions used for OPEB plans measurement purposes are shown below: Health Care Trend Rates December 31, 2024 December 31, 2023 Initial 6.50 % 7.00 % Ultimate 4.50 % 4.50 % Year Ultimate Reached 2029 2030 Significant Concentrations of Risk within Plan Assets In addition to establishing the target asset allocation of plan assets, the investment policy also places restrictions on securities to limit significant concentrations within plan assets. The investment policy establishes guidelines that govern maximum market exposure, security restrictions, prohibited asset classes, prohibited types of transactions, minimum credit quality, average portfolio credit quality, portfolio duration and concentration limits. The guidelines were established to mitigate the risk of loss due to significant concentrations in any investment. Management monitors the plans to control security diversification and ensure compliance with the investment policy. As of December 31, 2024, the assets were invested in compliance with all investment limits. See “Investments Held in Trust for Future Liabilities” section of Note 1 for limit details. Benefit Plan Obligations, Plan Assets, Funded Status and Amounts Recognized on the Balance Sheets For the year ended December 31, 2024, the pension plans had an actuarial gain primarily due to an increase in discount rates, and to a lesser extent the effect of demographic experience (updated census data on January 1, 2024). These gains were partially offset by increasing the cash balance account interest crediting rate, increasing the rate used to convert lump sums to annuities and updating the compensation increase rate to reflect the results of an experience study conducted in 2024. For the year ended December 31, 2024, the OPEB plans had an actuarial gain primarily due to updated per capita cost assumptions and updated discount rates. These gains were partially offset by the addition of a life insurance administrative load of 5%, the effect of special termination benefits and earlier retirements due to the voluntary severance program that occurred in the second quarter of 2024 and assumption changes as a result of an experience study conducted in 2024. For the year ended December 31, 2023, the pension plans had an actuarial loss primarily due to a decrease in the discount rate, and to a lesser extent the effect of demographic experience (updated census data on January 1, 2023). These losses were partially offset by decreasing the cash balance account interest crediting rate. For the year ended December 31, 2023, the OPEB plans had an actuarial loss primarily due to discount rates, as well as actual benefit payments above expected. These losses were partially offset by updated per capita cost assumptions. The following tables provide a reconciliation of the changes in the plans’ benefit obligations, fair value of plan assets, funded status and the presentation on the balance sheets. The benefit obligation for the defined benefit pension and OPEB plans are the projected benefit obligation and the accumulated benefit obligation, respectively. Pension Plans 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Change in Benefit Obligation (in millions) Benefit Obligation as of January 1, $ 4,161.6 $ 343.1 $ 504.1 $ 477.0 $ 378.4 $ 202.2 $ 261.2 Service Cost 100.6 8.9 9.5 13.0 9.2 5.9 7.8 Interest Cost 207.4 17.3 24.7 23.9 18.8 10.1 12.5 Actuarial (Gain) Loss (44.6) 5.5 (12.9) (8.4) (8.3) 0.1 (11.2) Settlements (329.4) (34.8) (42.0) (33.1) (23.2) (18.5) (33.1) Benefit Payments (223.8) (17.3) (30.4) (22.6) (24.2) (9.6) (9.4) Benefit Obligation as of December 31, $ 3,871.8 $ 322.7 $ 453.0 $ 449.8 $ 350.7 $ 190.2 $ 227.8 Change in Fair Value of Plan Assets Fair Value of Plan Assets as of January 1, $ 4,118.2 $ 332.7 $ 549.8 $ 550.6 $ 419.5 $ 222.7 $ 227.5 Actual Gain on Plan Assets 87.2 7.1 10.4 11.6 8.6 5.0 3.6 Company Contributions (a) 14.0 0.4 — — — 0.1 0.2 Settlements (329.4) (34.8) (42.0) (33.1) (23.2) (18.5) (33.1) Benefit Payments (223.8) (17.3) (30.4) (22.6) (24.2) (9.6) (9.4) Fair Value of Plan Assets as of December 31, $ 3,666.2 $ 288.1 $ 487.8 $ 506.5 $ 380.7 $ 199.7 $ 188.8 Funded (Underfunded) Status as of December 31, $ (205.6) $ (34.6) $ 34.8 $ 56.7 $ 30.0 $ 9.5 $ (39.0) 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Change in Benefit Obligation (in millions) Benefit Obligation as of January 1, $ 4,072.7 $ 334.1 $ 485.7 $ 466.8 $ 363.6 $ 192.3 $ 250.7 Service Cost 94.3 8.2 9.1 11.9 8.4 5.5 7.7 Interest Cost 219.2 18.3 26.4 24.9 19.8 10.7 13.9 Actuarial Loss 144.0 20.1 23.2 8.5 17.5 13.6 16.8 Benefit Payments (368.6) (37.6) (40.3) (35.1) (30.9) (19.9) (27.9) Benefit Obligation as of December 31, $ 4,161.6 $ 343.1 $ 504.1 $ 477.0 $ 378.4 $ 202.2 $ 261.2 Change in Fair Value of Plan Assets Fair Value of Plan Assets as of January 1, $ 4,124.7 $ 335.1 $ 531.7 $ 533.7 $ 406.4 $ 218.5 $ 231.3 Actual Gain on Plan Assets 353.8 34.8 58.4 51.5 44.0 24.0 23.9 Company Contributions (a) 8.3 0.4 — 0.5 — 0.1 0.2 Benefit Payments (368.6) (37.6) (40.3) (35.1) (30.9) (19.9) (27.9) Fair Value of Plan Assets as of December 31, $ 4,118.2 $ 332.7 $ 549.8 $ 550.6 $ 419.5 $ 222.7 $ 227.5 Funded (Underfunded) Status as of December 31, $ (43.4) $ (10.4) $ 45.7 $ 73.6 $ 41.1 $ 20.5 $ (33.7) (a) No contributions were made to the qualified pension plan for the years ended December 31, 2024 and 2023, respectively. Contributions to the non-qualified pension plans were $14 million and $8 million for the years ended December 31, 2024 and 2023, respectively. OPEB 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Change in Benefit Obligation (in millions) Benefit Obligation as of January 1, $ 849.5 $ 66.4 $ 134.6 $ 98.8 $ 85.9 $ 43.7 $ 53.7 Service Cost 4.5 0.3 0.5 0.6 0.4 0.3 0.4 Interest Cost 42.0 3.3 6.6 4.8 4.2 2.1 2.7 Actuarial (Gain) Loss (192.3) (15.4) (30.4) (24.7) (20.7) (10.4) (11.5) Special/Contractual Termination Benefits 3.5 0.4 0.6 0.4 0.3 0.1 0.3 Benefit Payments (105.8) (8.3) (16.7) (13.4) (11.3) (5.8) (7.4) Participant Contributions 44.9 3.5 6.8 6.0 4.6 2.6 3.3 Medicare Subsidy 0.3 — 0.1 — — — — Benefit Obligation as of December 31, $ 646.6 $ 50.2 $ 102.1 $ 72.5 $ 63.4 $ 32.6 $ 41.5 Change in Fair Value of Plan Assets Fair Value of Plan Assets as of January 1, $ 1,673.3 $ 137.5 $ 243.0 $ 204.6 $ 177.8 $ 90.2 $ 111.1 Actual Gain on Plan Assets 159.2 14.0 22.5 14.7 14.1 8.3 14.2 Company Contributions 4.3 — 0.8 — — — — Participant Contributions 44.9 3.5 6.8 6.0 4.6 2.6 3.3 Benefit Payments (105.8) (8.3) (16.7) (13.4) (11.3) (5.8) (7.4) Fair Value of Plan Assets as of December 31, $ 1,775.9 $ 146.7 $ 256.4 $ 211.9 $ 185.2 $ 95.3 $ 121.2 Funded Status as of December 31, $ 1,129.3 $ 96.5 $ 154.3 $ 139.4 $ 121.8 $ 62.7 $ 79.7 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Change in Benefit Obligation (in millions) Benefit Obligation as of January 1, $ 872.6 $ 68.6 $ 140.7 $ 101.9 $ 88.9 $ 45.7 $ 55.1 Service Cost 4.6 0.3 0.5 0.6 0.4 0.3 0.4 Interest Cost 46.2 3.6 7.4 5.4 4.7 2.4 2.9 Actuarial Loss 19.8 1.2 0.9 3.2 2.2 0.4 1.2 Benefit Payments (137.8) (10.7) (21.6) (18.3) (15.0) (7.6) (8.8) Participant Contributions 43.6 3.4 6.6 6.0 4.7 2.5 2.9 Medicare Subsidy 0.5 — 0.1 — — — — Benefit Obligation as of December 31, $ 849.5 $ 66.4 $ 134.6 $ 98.8 $ 85.9 $ 43.7 $ 53.7 Change in Fair Value of Plan Assets Fair Value of Plan Assets as of January 1, $ 1,549.3 $ 128.3 $ 228.6 $ 190.5 $ 166.2 $ 85.4 $ 103.0 Actual Gain on Plan Assets 213.2 16.5 28.1 26.4 21.9 9.9 14.0 Company Contributions 5.0 — 1.3 — — — — Participant Contributions 43.6 3.4 6.6 6.0 4.7 2.5 2.9 Benefit Payments (137.8) (10.7) (21.6) (18.3) (15.0) (7.6) (8.8) Fair Value of Plan Assets as of December 31, $ 1,673.3 $ 137.5 $ 243.0 $ 204.6 $ 177.8 $ 90.2 $ 111.1 Funded Status as of December 31, $ 823.8 $ 71.1 $ 108.4 $ 105.8 $ 91.9 $ 46.5 $ 57.4 Amounts Included on the Balance Sheets Related to Funded Status Pension Plans December 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Other Noncurrent Assets - Employee Benefits and Pension Assets $ — $ — $ 35.2 $ 58.2 $ 30.3 $ 10.9 $ — Other Current Liabilities – Accrued Short-term Benefit Liability (5.2) (0.3) — — — (0.1) (0.1) Other Noncurrent Liabilities – Accrued Long-term Benefit Liability (200.4) (34.3) (0.4) (1.5) (0.3) (1.3) (38.9) Funded (Underfunded) Status $ (205.6) $ (34.6) $ 34.8 $ 56.7 $ 30.0 $ 9.5 $ (39.0) December 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Other Noncurrent Assets - Employee Benefits and Pension Assets $ 17.3 $ 0.1 $ 46.0 $ 74.8 $ 41.4 $ 21.8 $ — Other Current Liabilities – Accrued Short-term Benefit Liability (6.7) (0.3) — — — (0.1) (0.1) Other Noncurrent Liabilities – Accrued Long-term Benefit Liability (54.0) (10.2) (0.3) (1.2) (0.3) (1.2) (33.6) Funded (Underfunded) Status $ (43.4) $ (10.4) $ 45.7 $ 73.6 $ 41.1 $ 20.5 $ (33.7) OPEB December 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Other Noncurrent Assets - Employee Benefits and Pension Assets $ 1,130.8 $ 96.5 $ 168.7 $ 139.4 $ 121.8 $ 62.7 $ 79.7 Other Current Liabilities – Accrued Short-term Benefit Liability (2.2) — (1.4) — — — — Other Noncurrent Liabilities – Accrued Long-term Benefit Liability 0.7 — (13.0) — — — — Funded Status $ 1,129.3 $ 96.5 $ 154.3 $ 139.4 $ 121.8 $ 62.7 $ 79.7 December 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Other Noncurrent Assets - Employee Benefits and Pension Assets $ 838.0 $ 71.1 $ 125.6 $ 105.8 $ 91.9 $ 46.5 $ 57.4 Other Current Liabilities – Accrued Short-term Benefit Liability (2.4) — (1.6) — — — — Other Noncurrent Liabilities – Accrued Long-term Benefit Liability (11.8) — (15.6) — — — — Funded Status $ 823.8 $ 71.1 $ 108.4 $ 105.8 $ 91.9 $ 46.5 $ 57.4 Amounts Included in Regulatory Assets, Deferred Income Taxes and AOCI The following tables show the components of the plans included in Regulatory Assets, Deferred Income Taxes and AOCI and the items attributable to the change in these components: Pension Plans December 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Components (in millions) Net Actuarial Loss $ 1,153.5 $ 189.3 $ 112.1 $ 7.5 $ 140.9 $ 53.8 $ 82.9 Prior Service Cost 0.2 — — — — — — Recorded as Regulatory Assets $ 1,019.8 $ 176.7 $ 109.9 $ 17.5 $ 140.9 $ 53.8 $ 83.0 Deferred Income Taxes 28.2 2.8 0.4 (2.2) — — — Net of Tax AOCI 105.7 9.8 1.8 (7.8) — — (0.1) December 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Components (in millions) Actuarial Loss During the Year $ 188.0 $ 24.2 $ 19.4 $ 23.0 $ 15.8 $ 12.5 $ 2.7 Amortization of Actuarial Loss (4.5) (0.3) (0.4) (0.4) (0.3) (0.2) (0.1) Amounts Recognized Due to Settlement (93.4) (9.8) (11.8) (9.3) (6.5) (5.2) (9.3) Change for the Year Ended December 31, $ 90.1 $ 14.1 $ 7.2 $ 13.3 $ 9.0 $ 7.1 $ (6.7) December 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Components (in millions) Net Actuarial (Gain) Loss $ 1,063.4 $ 175.2 $ 104.9 $ (5.8) $ 131.9 $ 46.7 $ 89.6 Prior Service Cost 0.2 — — — — — — Recorded as Regulatory Assets $ 938.6 $ 163.4 $ 102.6 $ 6.4 $ 131.9 $ 46.7 $ 89.7 Deferred Income Taxes 26.4 2.7 0.4 (2.6) — — — Net of Tax AOCI 98.6 9.1 1.9 (9.6) — — (0.1) December 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Components (in millions) Actuarial Loss During the Year $ 129.2 $ 13.4 $ 9.3 $ 1.2 $ 7.6 $ 7.9 $ 12.1 Amortization of Actuarial Loss (1.4) (0.1) — (0.1) — — (0.1) Change for the Year Ended December 31, $ 127.8 $ 13.3 $ 9.3 $ 1.1 $ 7.6 $ 7.9 $ 12.0 OPEB December 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Components (in millions) Net Actuarial (Gain) Loss $ (41.6) $ 1.6 $ (9.9) $ 2.3 $ (5.3) $ 4.7 $ — Prior Service Credit (14.7) (1.3) (2.3) (2.0) (1.6) (0.9) (1.0) Recorded as Regulatory Assets $ (55.4) $ 0.8 $ (2.0) $ (2.9) $ (6.9) $ 3.8 $ 0.5 Deferred Income Taxes (0.1) — (2.2) 0.7 — — (0.3) Net of Tax AOCI (0.8) (0.5) (8.0) 2.5 — — (1.2) December 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Components (in millions) Actuarial Gain During the Year $ (240.1) $ (20.3) $ (36.6) $ (25.9) $ (23.0) $ (12.6) $ (18.1) Amortization of Actuarial Loss (3.0) (0.2) (0.4) (0.5) (0.4) (0.2) (0.3) Amortization of Prior Service Credit 12.7 1.0 1.9 1.7 1.3 0.7 1.1 Change for the Year Ended December 31, $ (230.4) $ (19.5) $ (35.1) $ (24.7) $ (22.1) $ (12.1) $ (17.3) December 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Components (in millions) Net Actuarial Loss $ 201.5 $ 22.1 $ 27.1 $ 28.7 $ 18.1 $ 17.5 $ 18.4 Prior Service Credit (27.4) (2.3) (4.2) (3.7) (2.9) (1.6) (2.1) Recorded as Regulatory Assets $ 106.1 $ 19.8 $ 13.2 $ 19.0 $ 15.2 $ 15.9 $ 10.2 Deferred Income Taxes 14.3 — 2.0 1.3 — — 1.3 Net of Tax AOCI 53.7 — 7.7 4.7 — — 4.8 December 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Components (in millions) Actuarial Gain During the Year $ (83.7) $ (6.4) $ (11.1) $ (9.6) $ (7.9) $ (3.7) $ (5.6) Amortization of Actuarial Loss (14.8) (1.2) (2.3) (1.9) (1.6) (0.8) (1.0) Amortization of Prior Service Credit 63.1 5.3 9.2 8.7 6.3 4.0 4.9 Change for the Year Ended December 31, $ (35.4) $ (2.3) $ (4.2) $ (2.8) $ (3.2) $ (0.5) $ (1.7) Determination of Pension Expense The determination of pension expense or income is based on a market-related valuation of assets which reduces year-to-year volatility. This market-related valuation recognizes investment gains or losses over a five-year period from the year in which they occur. Investment gains or losses for this purpose are the difference between the expected return calculated using the market-related value of assets and the actual return. Pension and OPEB Assets The fair value tables within Pension and OPEB Assets present the classification of assets for AEP within the fair value hierarchy. All Level 1, 2, 3 and Other amounts can be allocated to the Registrant Subsidiaries using the percentages in the table below: Pension Plan OPEB December 31, Company 2024 2023 2024 2023 AEP Texas 7.9 % 8.1 % 8.3 % 8.2 % APCo 13.3 % 13.4 % 14.4 % 14.5 % I&M 13.8 % 13.4 % 11.9 % 12.2 % OPCo 10.4 % 10.2 % 10.4 % 10.6 % PSO 5.5 % 5.4 % 5.4 % 5.4 % SWEPCo 5.2 % 5.5 % 6.8 % 6.6 % The following table presents the classification of pension plan assets for AEP within the fair value hierarchy as of December 31, 2024: Asset Class Level 1 Level 2 Level 3 Other Total Year End (in millions) Equities (a): Domestic $ 327.0 $ — $ — $ — $ 327.0 8.9 % International 290.2 — — — 290.2 7.9 % Common Collective Trusts (b) 176.1 — — 472.6 648.7 17.7 % Subtotal – Equities 793.3 — — 472.6 1,265.9 34.5 % Fixed Income (a): United States Government and Agency Securities (2.3) 865.6 — — 863.3 23.6 % Corporate Debt — 719.2 — — 719.2 19.6 % Foreign Debt — 136.1 — — 136.1 3.7 % State and Local Government — 25.8 — — 25.8 0.7 % Other – Asset Backed — 0.9 — — 0.9 — % Subtotal – Fixed Income (2.3) 1,747.6 — — 1,745.3 47.6 % Infrastructure (b) — — — 112.9 112.9 3.1 % Real Estate (b) — — — 227.9 227.9 6.2 % Alternative Investments (b) — — — 223.8 223.8 6.1 % Cash and Cash Equivalents (b) — 41.3 — 27.2 68.5 1.9 % Other – Pending Transactions and Accrued Income (c) — — — 21.9 21.9 0.6 % Total $ 791.0 $ 1,788.9 $ — $ 1,086.3 $ 3,666.2 100.0 % (a) Includes investment securities loaned to borrowers under the securities lending program. See the “Investments Held in Trust for Future Liabilities” section of Note 1 for additional information. (b) Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share. (c) Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement. The following table presents the classification of OPEB plan assets for AEP within the fair value hierarchy as of December 31, 2024: Asset Class Level 1 Level 2 Level 3 Other Total Year End (in millions) Equities: Domestic $ 616.8 $ — $ — $ — $ 616.8 34.7 % International 267.2 — — — 267.2 15.0 % Common Collective Trusts (a) 64.2 — — 129.4 193.6 10.9 % Subtotal – Equities 948.2 — — 129.4 1,077.6 60.6 % Fixed Income: Common Collective Trust – Debt (a) — — — 132.9 132.9 7.5 % United States Government and Agency Securities (0.5) 157.6 — — 157.1 8.9 % Corporate Debt — 132.3 — — 132.3 7.5 % Foreign Debt — 27.1 — — 27.1 1.5 % State and Local Government 57.8 5.0 — — 62.8 3.5 % Other – Asset Backed — 0.2 — — 0.2 — % Subtotal – Fixed Income 57.3 322.2 — 132.9 512.4 28.9 % Trust Owned Life Insurance: International Equities — 23.1 — — 23.1 1.3 % United States Bonds — 118.2 — — 118.2 6.7 % Subtotal – Trust Owned Life Insurance — 141.3 — — 141.3 8.0 % Cash and Cash Equivalents (a) 27.6 — — 3.1 30.7 1.7 % Other – Pending Transactions and Accrued Income (b) — — — 13.9 13.9 0.8 % Total $ 1,033.1 $ 463.5 $ — $ 279.3 $ 1,775.9 100.0 % (a) Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share. (b) Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement. The following table presents the classification of pension plan assets for AEP within the fair value hierarchy as of December 31, 2023: Asset Class Level 1 Level 2 Level 3 Other Total Year End (in millions) Equities (a): Domestic $ 411.3 $ — $ — $ — $ 411.3 10.0 % International 389.8 — — — 389.8 9.5 % Common Collective Trusts (b) — — — 420.9 420.9 10.2 % Subtotal – Equities 801.1 — — 420.9 1,222.0 29.7 % Fixed Income (a): United States Government and Agency Securities 8.3 1,099.2 — — 1,107.5 26.9 % Corporate Debt — 894.8 — — 894.8 21.7 % Foreign Debt — 167.1 — — 167.1 4.1 % State and Local Government — 38.7 — — 38.7 0.9 % Other – Asset Backed — 1.3 — — 1.3 — % Subtotal – Fixed Income 8.3 2,201.1 — — 2,209.4 53.6 % Infrastructure (b) — — — 101.4 101.4 2.5 % Real Estate (b) — — — 239.3 239.3 5.8 % Alternative Investments (b) — — — 241.8 241.8 5.8 % Cash and Cash Equivalents (b) — 51.0 — 33.8 84.8 2.1 % Other – Pending Transactions and Accrued Income (c) — — 0.1 19.4 19.5 0.5 % Total $ 809.4 $ 2,252.1 $ 0.1 $ 1,056.6 $ 4,118.2 100.0 % (a) Includes investment securities loaned to borrowers under the securities lending program. See the “Investments Held in Trust for Future Liabilities” section of Note 1 for additional information. (b) Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share. (c) Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement. The following table presents the classification of OPEB plan assets for AEP within the fair value hierarchy as of December 31, 2023: Asset Class Level 1 Level 2 Level 3 Other Total Year End (in millions) Equities: Domestic $ 540.6 $ — $ — $ — $ 540.6 32.3 % International 288.4 — — — 288.4 17.2 % Common Collective Trusts (a) — — — 131.6 131.6 7.9 % Subtotal – Equities 829.0 — — 131.6 960.6 57.4 % Fixed Income: Common Collective Trust – Debt (a) — — — 146.7 146.7 8.8 % United States Government and Agency Securities 1.4 163.3 — — 164.7 9.8 % Corporate Debt — 149.0 — — 149.0 8.9 % Foreign Debt — 28.6 — — 28.6 1.7 % State and Local Government 41.5 7.8 — — 49.3 3.0 % Other – Asset Backed — 0.2 — — 0.2 — % Subtotal – Fixed Income 42.9 348.9 — 146.7 538.5 32.2 % Trust Owned Life Insurance: International Equities — 22.3 — — 22.3 1.3 % United States Bonds — 130.0 — — 130.0 7.8 % Subtotal – Trust Owned Life Insurance — 152.3 — — 152.3 9.1 % Cash and Cash Equivalents (a) 25.9 — — 2.9 28.8 1.7 % Other – Pending Transactions and Accrued Income (b) — — — (6.9) (6.9) (0.4) % Total $ 897.8 $ 501.2 $ — $ 274.3 $ 1,673.3 100.0 % (a) Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share. (b) Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement. Accumulated Benefit Obligation The accumulated benefit obligation for the pension plans is as follows: Accumulated Benefit Obligation AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Qualified Pension Plan $ 3,602.4 $ 300.6 $ 434.3 $ 422.3 $ 326.4 $ 174.6 $ 209.5 Nonqualified Pension Plans 46.9 2.1 0.2 0.9 0.1 1.1 1.0 Total as of December 31, 2024 $ 3,649.3 $ 302.7 $ 434.5 $ 423.2 $ 326.5 $ 175.7 $ 210.5 Accumulated Benefit Obligation AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Qualified Pension Plan $ 3,878.7 $ 321.1 $ 485.6 $ 450.3 $ 354.0 $ 186.6 $ 241.9 Nonqualified Pension Plans 54.8 2.1 0.1 0.7 0.1 1.2 1.0 Total as of December 31, 2023 $ 3,933.5 $ 323.2 $ 485.7 $ 451.0 $ 354.1 $ 187.8 $ 242.9 Obligations in Excess of Fair Values The tables below show the underfunded pension plans that had obligations in excess of plan assets. Projected Benefit Obligation AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Projected Benefit Obligation $ 3,871.8 $ 322.7 $ 0.5 $ 1.5 $ 0.4 $ 1.4 $ 227.8 Fair Value of Plan Assets 3,666.2 288.1 — — — — 188.8 Underfunded Projected Benefit Obligation as of December 31, 2024 $ (205.6) $ (34.6) $ (0.5) $ (1.5) $ (0.4) $ (1.4) $ (39.0) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Projected Benefit Obligation $ 60.7 $ 343.1 $ 0.4 $ 1.2 $ 0.3 $ 1.4 $ 261.2 Fair Value of Plan Assets — 332.7 — — — — 227.5 Underfunded Projected Benefit Obligation as of December 31, 2023 $ (60.7) $ (10.4) $ (0.4) $ (1.2) $ (0.3) $ (1.4) $ (33.7) Accumulated Benefit Obligation AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Accumulated Benefit Obligation $ 46.9 $ 302.7 $ 0.2 $ 0.9 $ 0.1 $ 1.1 $ 210.5 Fair Value of Plan Assets — 288.0 — — — — 188.9 Underfunded Accumulated Benefit Obligation as of December 31, 2024 $ (46.9) $ (14.7) $ (0.2) $ (0.9) $ (0.1) $ (1.1) $ (21.6) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Accumulated Benefit Obligation $ 54.8 $ 2.1 $ 0.1 $ 0.7 $ 0.1 $ 1.2 $ 242.9 Fair Value of Plan Assets — — — — — — 227.5 Underfunded Accumulated Benefit Obligation as of December 31, 2023 $ (54.8) $ (2.1) $ (0.1) $ (0.7) $ (0.1) $ (1.2) $ (15.4) Estimated Future Benefit Payments and Contributions The estimated pension benefit payments and contributions to the trust are at least the minimum amount required by the Employee Retirement Income Security Act plus payment of unfunded non-qualified benefits. For the qualified pension plan, additional discretionary contributions may also be made to maintain the funded status of the plan. For OPEB plans, expected payments include the payment of unfunded benefits. The following table provides the estimated contributions and payments by Registrant for 2025: AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Pension Plans $ 101.2 $ 11.8 $ 0.5 $ 2.6 $ — $ 2.0 $ 8.8 OPEB 2.7 — 1.4 — — — — The tables below reflect the total benefits expected to be paid from the plan or from the Registrants’ assets. The payments include the participants’ contributions to the plan for their share of the cost. Future benefit payments are dependent on the number of employees retiring, whether the retiring employees elect to receive pension benefits as annuities or as lump sum distributions, future integration of the benefit plans with changes to Medicare and other legislation, future levels of interest rates and variances in actuarial results. The estimated payments for the pension benefits and OPEB are as follows: Pension Plans AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) 2025 $ 341.5 $ 32.2 $ 42.3 $ 40.1 $ 31.6 $ 17.3 $ 20.7 2026 340.4 31.0 42.1 40.1 31.0 17.1 19.2 2027 334.8 28.8 40.0 39.0 30.8 17.1 20.4 2028 335.7 29.5 40.2 38.8 30.0 16.9 19.4 2029 322.7 27.8 38.6 37.1 29.5 15.1 19.0 Years 2030 to 2034, in Total 1,530.3 120.9 181.6 179.0 137.8 73.3 88.4 OPEB Benefit Payments AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) 2025 $ 117.6 $ 9.5 $ 18.8 $ 14.5 $ 12.0 $ 6.6 $ 8.6 2026 116.4 9.7 18.4 14.5 11.7 6.6 8.3 2027 114.6 9.7 18.1 14.2 11.5 6.3 8.0 2028 112.4 9.3 17.9 13.9 11.4 6.0 8.0 2029 109.7 8.9 17.4 13.6 11.0 5.9 7.8 Years 2030 to 2034, in Total 504.7 39.7 78.1 61.0 50.6 27.2 35.7 OPEB Medicare AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) 2025 $ 0.2 $ — $ 0.1 $ — $ — $ — $ — 2026 0.3 — 0.1 — — — — 2027 0.3 — 0.1 — — — — 2028 0.3 — 0.1 — — — — 2029 0.3 — 0.1 — — — — Years 2030 to 2034, in Total 1.4 — 0.4 — — — — Components of Net Periodic Benefit Cost The following tables provide the components of net periodic benefit cost (credit) by Registrant for the plans: Pension Plans 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 100.6 $ 8.9 $ 9.5 $ 13.0 $ 9.2 $ 5.9 $ 7.8 Interest Cost 207.4 17.3 24.7 23.9 18.8 10.1 12.5 Expected Return on Plan Assets (319.8) (25.7) (42.6) (42.9) (32.6) (17.3) (17.4) Amortization of Net Actuarial Loss 4.5 0.3 0.4 0.4 0.3 0.2 0.1 Settlements (a) 93.4 9.8 11.8 9.3 6.5 5.2 9.3 Net Periodic Benefit Cost 86.1 10.6 3.8 3.7 2.2 4.1 12.3 Capitalized Portion (46.6) (5.3) (4.4) (3.9) (5.5) (2.8) (3.1) Net Periodic Benefit Cost (Credit) Recognized in Expense $ 39.5 $ 5.3 $ (0.6) $ (0.2) $ (3.3) $ 1.3 $ 9.2 (a) AEP will seek recovery for the portion of pension settlement costs related to regulated operations. These costs were deferred as a regulatory asset for AEP, AEP Texas, APCo and PSO in the fourth quarter of 2024. 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 94.3 $ 8.2 $ 9.1 $ 11.9 $ 8.4 $ 5.5 $ 7.7 Interest Cost 219.2 18.3 26.4 24.9 19.8 10.7 13.9 Expected Return on Plan Assets (339.2) (28.1) (44.6) (44.2) (34.0) (18.3) (19.4) Amortization of Net Actuarial Loss 1.4 0.1 — 0.1 — — 0.1 Net Periodic Benefit Cost (Credit) (24.3) (1.5) (9.1) (7.3) (5.8) (2.1) 2.3 Capitalized Portion (43.6) (4.7) (4.2) (3.6) (4.7) (2.5) (3.0) Net Periodic Benefit Credit Recognized in Expense $ (67.9) $ (6.2) $ (13.3) $ (10.9) $ (10.5) $ (4.6) $ (0.7) 2022 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 123.1 $ 11.1 $ 11.4 $ 16.2 $ 11.2 $ 7.4 $ 10.6 Interest Cost 148.2 12.1 17.5 17.0 13.3 7.0 9.1 Expected Return on Plan Assets (253.4) (21.0) (32.3) (32.4) (24.8) (13.4) (14.6) Amortization of Net Actuarial Loss 63.0 5.2 7.4 7.1 5.5 2.9 3.8 Net Periodic Benefit Cost 80.9 7.4 4.0 7.9 5.2 3.9 8.9 Capitalized Portion (53.8) (6.2) (5.0) (4.6) (6.1) (3.2) (4.0) Net Periodic Benefit Cost (Credit) Recognized in Expense $ 27.1 $ 1.2 $ (1.0) $ 3.3 $ (0.9) $ 0.7 $ 4.9 OPEB 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 4.5 $ 0.3 $ 0.5 $ 0.6 $ 0.4 $ 0.3 $ 0.4 Interest Cost 42.0 3.3 6.6 4.8 4.2 2.1 2.7 Expected Return on Plan Assets (111.3) (9.1) (16.3) (13.5) (11.8) (6.0) (7.5) Amortization of Prior Service Credit (12.7) (1.0) (1.9) (1.7) (1.3) (0.7) (1.1) Amortization of Net Actuarial Loss 3.0 0.2 0.4 0.5 0.4 0.2 0.3 Special/Contractual Termination Benefits 3.5 0.3 0.6 0.3 0.2 0.2 0.3 Net Periodic Benefit Credit (71.0) (6.0) (10.1) (9.0) (7.9) (3.9) (4.9) Capitalized Portion (2.1) (0.2) (0.2) (0.2) (0.2) (0.1) (0.2) Net Periodic Benefit Credit Recognized in Expense $ (73.1) $ (6.2) $ (10.3) $ (9.2) $ (8.1) $ (4.0) $ (5.1) 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 4.6 $ 0.3 $ 0.5 $ 0.6 $ 0.4 $ 0.3 $ 0.4 Interest Cost 46.2 3.6 7.4 5.4 4.7 2.4 2.9 Expected Return on Plan Assets (109.6) (9.0) (16.1) (13.5) (11.8) (5.9) (7.2) Amortization of Prior Service Credit (63.1) (5.3) (9.2) (8.7) (6.3) (4.0) (4.9) Amortization of Net Actuarial Loss 14.8 1.2 2.3 1.9 1.6 0.8 1.0 Net Periodic Benefit Credit (107.1) (9.2) (15.1) (14.3) (11.4) (6.4) (7.8) Capitalized Portion (2.1) (0.2) (0.2) (0.2) (0.2) (0.1) (0.2) Net Periodic Benefit Credit Recognized in Expense $ (109.2) $ (9.4) $ (15.3) $ (14.5) $ (11.6) $ (6.5) $ (8.0) 2022 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 7.4 $ 0.5 $ 0.8 $ 0.9 $ 0.6 $ 0.4 $ 0.6 Interest Cost 29.2 2.2 4.7 3.4 3.0 1.5 1.8 Expected Return on Plan Assets (110.0) (9.1) (16.3) (13.7) (12.0) (6.1) (7.3) Amortization of Prior Service Credit (71.4) (6.1) (10.4) (9.7) (7.1) (4.4) (5.3) Net Periodic Benefit Credit (144.8) (1

BUSINESS SEGMENTS

BUSINESS SEGMENTS	12 Months Ended
	Dec. 31, 2024
Segment Reporting [Abstract]
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 • Marketing, risk management and retail activities in ERCOT, MISO, PJM and SPP. • Competitive generation in PJM. The remainder of AEP’s activities are presented as Corporate and Other. While not considered a reportable segment, Corporate and Other primarily includes the purchasing of receivables from certain AEP utility subsidiaries, Parent’s guarantee revenue received from affiliates, investment income, interest income and interest expense, income tax expense and other nonallocated costs. The CODM of AEP is the President and CEO of AEP, who makes operating decisions, allocates resources to and assesses performance based on these reportable segments. The CODM uses earnings (loss) attributable to AEP common shareholders (presented on a GAAP basis) as a measure of segment profit or loss in making these decisions. Earnings (loss) attributable to AEP common shareholders includes intercompany revenues and expenses that are eliminated on the consolidated financial statements. The tables below present AEP’s reportable segment income statement information for the years ended December 31, 2024, 2023 and 2022 and reportable segment balance sheet information as of December 31, 2024 and 2023. The significant expenses disclosed below align with the segment-level information that is regularly provided to the CODM. VIU T&D AEPTHCo G&M Total Reportable Segments Corporate and Other (a) Reconciling Adjustments Consolidated 2024 (in millions) Revenues from: External Customers $ 11,414.0 $ 5,879.6 $ 425.0 $ 1,944.7 $ 19,663.3 $ 58.0 $ — $ 19,721.3 Other Operating Segments 182.6 28.1 1,525.8 100.7 1,837.2 125.1 (1,962.3) (b) — Total Revenues 11,596.6 5,907.7 1,950.8 2,045.4 21,500.5 183.1 (1,962.3) 19,721.3 Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 3,796.2 909.1 — 1,542.4 6,247.7 — (311.4) 5,936.3 Other Operation and Maintenance 3,528.0 2,166.1 162.8 129.9 5,986.8 136.3 (1,670.4) 4,452.7 Asset Impairments and Other Related Charges 13.4 52.9 — 76.2 142.5 — — 142.5 Depreciation and Amortization 1,970.6 879.5 439.7 20.9 3,310.7 (20.8) — 3,289.9 Taxes Other Than Income Taxes 535.3 724.2 314.9 2.0 1,576.4 0.4 19.5 1,596.3 Allowance for Equity Funds Used During Construction 52.4 69.2 89.4 — 211.0 — — 211.0 Interest Expense 724.3 405.5 222.3 16.6 1,368.7 612.5 (118.4) 1,862.8 Income Tax Expense (Benefit) (282.2) 154.5 214.7 25.9 112.9 (152.1) — (39.2) Equity Earnings (Loss) of Unconsolidated Subsidiaries 1.4 (1.1) 98.9 0.9 100.1 (6.4) — 93.7 Other Segment Items (c) (88.4) (41.7) (5.5) (56.8) (192.4) (108.4) 118.4 (182.4) Earnings (Loss) Attributable to AEP Common Shareholders $ 1,453.2 $ 725.7 $ 790.2 $ 289.2 $ 3,258.3 $ (291.2) $ — $ 2,967.1 Gross Property Additions $ 3,643.5 $ 2,343.6 $ 1,572.5 $ 35.1 $ 7,594.7 $ 466.6 $ (31.1) $ 8,030.2 Total Assets $ 54,996.5 $ 26,864.3 $ 18,011.9 $ 1,633.9 $ 101,506.6 $ 5,550.8 (d) $ (3,979.4) (e) $ 103,078.0 Investments in Equity Method Investees $ 9.1 $ 2.0 $ 996.1 $ — $ 1,007.2 $ 48.7 $ — $ 1,055.9 VIU T&D AEPTHCo G&M Total Reportable Segments Corporate and Other (a) Reconciling Adjustments Consolidated 2023 (in millions) Revenues from: External Customers $ 11,303.7 $ 5,677.2 $ 397.4 $ 1,543.3 $ 18,921.6 $ 60.7 $ — $ 18,982.3 Other Operating Segments 145.8 36.1 1,331.1 88.9 1,601.9 107.3 (1,709.2) (b) — Total Revenues 11,449.5 5,713.3 1,728.5 1,632.2 20,523.5 168.0 (1,709.2) 18,982.3 Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 4,150.3 1,214.8 — 1,487.8 6,852.9 — (274.6) 6,578.3 Other Operation and Maintenance 3,211.1 1,947.8 141.6 132.9 5,433.4 103.1 (1,449.7) 4,086.8 Asset Impairments and Other Related Charges 85.6 — — — 85.6 — — 85.6 Loss on the Sale of the Competitive Contracted Renewables Portfolio — — — 92.7 92.7 — — 92.7 Depreciation and Amortization 1,876.4 784.7 402.6 42.7 3,106.4 (16.0) — 3,090.4 Taxes Other Than Income Taxes 512.5 668.0 290.1 6.6 1,477.2 0.2 14.9 1,492.3 Allowance for Equity Funds Used During Construction 46.3 45.5 83.1 — 174.9 — — 174.9 Interest Expense 764.5 363.6 202.6 76.0 1,406.7 594.7 (194.5) 1,806.9 Income Tax Expense (Benefit) (45.2) 140.2 166.0 (122.9) 138.1 (83.5) — 54.6 Equity Earnings (Loss) of Unconsolidated Subsidiaries 1.4 — 82.9 (16.5) 67.8 (9.3) — 58.5 Other Segment Items (c) (148.4) (59.0) (11.3) (73.8) (292.5) (182.2) 194.7 (280.0) Earnings (Loss) Attributable to AEP Common Shareholders $ 1,090.4 $ 698.7 $ 702.9 $ (26.3) $ 2,465.7 $ (257.6) $ — $ 2,208.1 Gross Property Additions $ 3,486.8 $ 2,467.4 $ 1,528.7 $ 12.6 $ 7,495.5 $ 36.6 $ 1.4 $ 7,533.5 Total Assets $ 51,802.1 $ 24,838.4 $ 16,575.6 $ 2,598.5 $ 95,814.6 $ 5,194.0 (d) $ (4,324.6) (e) $ 96,684.0 Investments in Equity Method Investees $ 10.0 $ 3.0 $ 905.8 $ 100.6 $ 1,019.4 $ 54.2 $ — $ 1,073.6 VIU T&D AEPTHCo G&M Total Reportable Segments Corporate and Other (a) Reconciling Adjustments Consolidated 2022 (in millions) Revenues from: External Customers $ 11,292.8 $ 5,489.6 $ 357.5 $ 2,448.9 $ 19,588.8 $ 50.7 $ — $ 19,639.5 Other Operating Segments 184.7 22.4 1,319.5 18.0 1,544.6 59.2 (1,603.8) (b) — Total Revenues 11,477.5 5,512.0 1,677.0 2,466.9 21,133.4 109.9 (1,603.8) 19,639.5 Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 4,007.9 1,287.3 — 1,984.3 7,279.5 — (181.6) 7,097.9 Other Operation and Maintenance 3,287.2 1,864.2 165.7 118.7 5,435.8 130.0 (1,438.3) 4,127.5 Loss on the Expected Sale of the Kentucky Operations — — — — — 363.3 — 363.3 Asset Impairments and Other Related Charges 24.9 — — — 24.9 23.9 — 48.8 Gain on Sale of Mineral Rights — — — (116.3) (116.3) — — (116.3) Depreciation and Amortization 2,007.2 746.7 355.0 93.0 3,201.9 0.9 — 3,202.8 Taxes Other Than Income Taxes 504.9 659.9 277.6 11.1 1,453.5 0.2 16.1 1,469.8 Allowance for Equity Funds Used During Construction 29.5 33.6 70.6 — 133.7 — — 133.7 Interest Expense 650.9 328.0 169.3 51.8 1,200.0 308.9 (112.8) 1,396.1 Income Tax Expense (Benefit) (93.8) 116.9 193.6 (83.1) 133.6 (128.2) — 5.4 Equity Earnings (Loss) of Unconsolidated Subsidiaries 1.4 0.6 83.4 (192.4) (107.0) (2.4) — (109.4) Other Segment Items (c) (172.8) (52.5) (3.7) (68.6) (297.6) (53.9) 112.8 (238.7) Earnings (Loss) Attributable to AEP Common Shareholders $ 1,292.0 $ 595.7 $ 673.5 $ 283.6 $ 2,844.8 $ (537.6) $ — $ 2,307.2 Gross Property Additions $ 4,164.6 $ 2,177.3 $ 1,470.8 $ 69.2 $ 7,881.9 $ 25.9 $ (28.8) $ 7,879.0 Investments in Equity Method Investees $ 10.1 $ 3.0 $ 858.3 $ 337.6 $ 1,209.0 $ 67.7 $ — $ 1,276.7 (a) Corporate and Other primarily includes the purchasing of receivables from certain AEP utility subsidiaries. This segment also includes Parent’s guarantee revenue received from affiliates, investment income, interest income and interest expense, income tax expense and other nonallocated costs. (b) Represents inter-segment revenues. (c) Other segment items included in segment earnings (loss) attributable to AEP common shareholders primarily includes Non-Service Cost Components of Net Period Benefit Cost, Net Income (Loss) Attributable to Noncontrolling Interests and Establishment of the VA Triennial Review Regulatory Asset (2022). (d) Includes elimination of AEP Parent’s investments in wholly-owned subsidiary companies. (e) Reconciling Adjustments for Total Assets primarily include elimination of intercompany advances to affiliates and intercompany accounts receivable. Registrant Subsidiaries’ Reportable Segments (Applies to all Registrant Subsidiaries except AEPTCo) The Registrant Subsidiaries each have one reportable segment, an integrated electricity generation, transmission and distribution business for APCo, I&M, PSO and SWEPCo, and an integrated electricity transmission and distribution business for AEP Texas and OPCo. Other activities are insignificant. The Registrant Subsidiaries’ operations are managed on an integrated basis because of the substantial impact of cost-based rates and regulatory oversight on the business process, cost structures and operating results. The CODM of each Registrant Subsidiary is th e AEP President and CEO, who makes operating decisions, allocates resources to and assesses performance based on these reportable segments. The CODM uses net income (loss) that is reported on the Registrant Subsidiaries’ statements of income as a measure of segment profit or loss in making these decisions . Net income (l oss) includes intercompany revenues and expenses that are eliminated on the consolidated financial statements. The expenses disclosed on the Registrant Subsidiaries’ statements of income align with the segment-level significant expenses that are regularly provided to the CODM. Total Assets is reported on the consolidated financial statements. Gross Property Additions for the Registrant Subsidiaries is represented by the sum of Construction Expenditures and Acquisition of Assets on the consolidated financial statements. See Registrant Subsidiaries statements of income, balance sheets and cash flows for details. 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. The CODM of AEPTCo is the AEP President and CEO, who 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 reportable segment. As a result, AEPTCo has one reportable segment. The remainder of AEPTCo’s activity is presented in AEPTCo Parent. While not considered a reportable segment, AEPTCo Parent represents the activity of the holding company which primarily relates to debt financing activity and general corporate activities. The tables below present AEPTCo’s reportable segment income statement information for the years ended December 31, 2024, 2023 and 2022 and reportable segment balance sheet information as of December 31, 2024 and 2023. The significant expenses disclosed below align with the segment-level information that is regularly provided to the CODM. State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo 2024 (in millions) Revenues from: External Customers $ 378.6 $ — $ — $ 378.6 Sales to AEP Affiliates 1,512.3 — — 1,512.3 Total Revenues 1,890.9 — — 1,890.9 Other Operation and Maintenance 156.6 1.7 — 158.3 Depreciation and Amortization 430.9 — — 430.9 Taxes Other Than Income Taxes 308.7 — — 308.7 Interest Income 7.9 241.1 (238.5) (a) 10.5 Allowance for Equity Funds Used During Construction 89.4 — — 89.4 Interest Expense 214.0 238.7 (238.5) (a) 214.2 Income Tax Expense 190.2 0.1 — 190.3 Net Income $ 687.8 $ 0.6 (b) $ — $ 688.4 Gross Property Additions $ 1,481.8 $ — $ — $ 1,481.8 Total Assets $ 16,887.7 $ 8,670.4 (c) $ (9,187.8) (d) $ 16,370.3 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo 2023 (in millions) Revenues from: External Customers $ 354.2 $ — $ — $ 354.2 Sales to AEP Affiliates 1,317.8 — — 1,317.8 Total Revenues 1,672.0 — — 1,672.0 Other Operation and Maintenance 129.2 0.2 — 129.4 Depreciation and Amortization 393.8 — — 393.8 Taxes Other Than Income Taxes 283.2 — — 283.2 Interest Income 3.8 218.0 (214.8) (a) 7.0 Allowance for Equity Funds Used During Construction 83.2 — — 83.2 Interest Expense 194.2 215.1 (214.8) (a) 194.5 Income Tax Expense 145.7 1.4 — 147.1 Net Income $ 612.9 $ 1.3 (b) $ — $ 614.2 Gross Property Additions $ 1,503.1 $ — $ — $ 1,503.1 Total Assets $ 15,120.6 $ 5,486.6 (c) $ (5,534.7) (d) $ 15,072.5 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo 2022 (in millions) Revenues from: External Customers $ 340.9 $ — $ — $ 340.9 Sales to AEP Affiliates 1,283.8 — — 1,283.8 Other Revenues (0.2) — — (0.2) Total Revenues 1,624.5 — — 1,624.5 Other Operation and Maintenance 152.8 0.7 — 153.5 Depreciation and Amortization 346.2 — — 346.2 Taxes Other Than Income Taxes 271.1 — — 271.1 Interest Income 0.7 177.8 (176.9) (a) 1.6 Allowance for Equity Funds Used During Construction 70.7 — — 70.7 Interest Expense 162.5 177.1 (176.9) (a) 162.7 Income Tax Expense 169.1 — — 169.1 Net Income $ 594.2 $ — (b) $ — $ 594.2 Gross Property Additions $ 1,468.3 $ — $ — $ 1,468.3 (a) Elimination of intercompany interest income/interest expense on affiliated debt arrangement. (b) Includes elimination of AEPTCo Parent’s equity earnings in the State Transcos. (c) Primarily relates to Notes Receivable from the State Transcos. (d) Primarily relates to elimination of Notes Receivable from the State Transcos.

DERIVATIVES AND HEDGING

DERIVATIVES AND HEDGING	12 Months Ended
	Dec. 31, 2024
Derivative Instruments and Hedging Activities Disclosure [Abstract]
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 table represents the gross notional volume of the Registrants’ outstanding derivative contracts: Notional Volume of Derivative Instruments December 31, 2024 December 31, 2023 Primary Risk AEP AEP Texas APCo I&M OPCo PSO SWEPCo AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power (MWhs) 282.4 — 23.6 7.7 2.0 5.0 4.6 246.8 — 16.8 5.9 2.2 4.1 2.9 Natural Gas (MMBtus) 152.8 — 42.2 — — 46.2 15.4 151.6 — 37.3 — — 34.9 17.9 Heating Oil and Gasoline (Gallons) 7.9 2.0 0.9 2.0 1.1 0.7 0.9 6.5 1.8 1.0 0.6 1.2 0.7 0.9 Interest Rate (USD) $ 59.3 $ — $ — $ — $ — $ — $ — $ 80.1 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt (USD) $ 950.0 $ — $ — $ — $ — $ — $ — $ 1,300.0 $ 150.0 $ — $ — $ — $ — $ — Fair Value Hedging Strategies (Applies to AEP) Parent enters into interest rate derivative transactions as part of an overall strategy to manage the mix of fixed-rate and floating-rate debt. Certain interest rate derivative transactions effectively modify exposure to interest rate risk by converting a portion of fixed-rate debt to a floating-rate. Provided specific criteria are met, these interest rate derivatives may be designated as fair value hedges. Cash Flow Hedging Strategies The Registrants utilize cash flow hedges on certain derivative transactions for the purchase and sale of power (“Commodity”) in order to manage the variable price risk related to forecasted purchases and sales. Management monitors the potential impacts of commodity price changes and, where appropriate, enters into derivative transactions to protect profit margins for a portion of future electricity sales and purchases. The Registrants do not hedge all commodity price risk. The Registrants utilize a variety of interest rate derivative transactions in order to manage interest rate risk exposure. The Registrants also utilize interest rate derivative contracts to manage interest rate exposure related to future borrowings of fixed-rate debt. The Registrants do not hedge all interest rate exposure. ACCOUNTING FOR DERIVATIVE INSTRUMENTS AND THE IMPACT ON THE FINANCIAL STATEMENTS The accounting guidance for “Derivatives and Hedging” requires recognition of all qualifying derivative instruments as either assets or liabilities on the balance sheets at fair value. The fair values of derivative instruments accounted for using MTM accounting or hedge accounting are based on exchange prices and broker quotes. If a quoted market price is not available, the estimate of fair value is based on the best information available including valuation models that estimate future energy prices based on existing market and broker quotes and other assumptions. In order to determine the relevant fair values of the derivative instruments, the Registrants apply valuation adjustments for discounting, liquidity and credit quality. Credit risk is the risk that a counterparty will fail to perform on the contract or fail to pay amounts due. Liquidity risk represents the risk that imperfections in the market will cause the price to vary from estimated fair value based upon prevailing market supply and demand conditions. Since energy markets are imperfect and volatile, there are inherent risks related to the underlying assumptions in models used to fair value risk management contracts. Unforeseen events may cause reasonable price curves to differ from actual price curves throughout a contract’s term and at the time a contract settles. Consequently, there could be significant adverse or favorable effects on future net income and cash flows if market prices are not consistent with management’s estimates of current market consensus for forward prices in the current period. This is particularly true for longer term contracts. Cash flows may vary based on market conditions, margin requirements and the timing of settlement of risk management contracts. According to the accounting guidance for “Derivatives and Hedging,” the Registrants reflect the fair values of derivative instruments subject to netting agreements with the same counterparty net of related cash collateral. For certain risk management contracts, the Registrants are required to post or receive cash collateral based on third-party contractual agreements and risk profiles. AEP netted cash collateral received from third-parties against short-term and long-term risk management assets in the amounts of $87 million and $46 million as of December 31, 2024 and 2023, respectively. There was no cash collateral received from third-parties netted against short-term and long-term risk management assets for the Registrant Subsidiaries as of December 31, 2024 and 2023. The amount of cash collateral paid to third-parties netted against short-term and long-term risk management liabilities was not material for the Registrants as of December 31, 2024 and 2023. Location and Fair Value of Derivative Assets and Liabilities Recognized In the Balance Sheet The following tables represent the gross fair value of the Registrants’ derivative activity on the balance sheets. The derivative instruments are disclosed as gross. They are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with the accounting guidance for “Derivatives and Hedging.” Unless shown as a separate line on the balance sheets due to materiality, Current Risk Management Assets are included in Prepayments and Other Current Assets, Long-term Risk Management Assets are included in Deferred Charges and Other Noncurrent Assets, Current Risk Management Liabilities are included in Other Current Liabilities and Long-term Risk Management Liabilities are included in Deferred Credits and Other Noncurrent Liabilities on the balance sheets. December 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Assets: (in millions) Current Risk Management Assets Risk Management Contracts - Commodity $ 425.0 $ — $ 40.2 $ 28.5 $ — $ 22.3 $ 19.1 Hedging Contracts - Commodity 54.1 — — — — — — Hedging Contracts - Interest Rate — — — — — — — Total Current Risk Management Assets 479.1 — 40.2 28.5 — 22.3 19.1 Long-term Risk Management Assets Risk Management Contracts - Commodity 475.4 — 2.0 1.2 — 1.6 — Hedging Contracts - Commodity 84.6 — — — — — — Hedging Contracts - Interest Rate — — — — — — — Total Long-term Risk Management Assets 560.0 — 2.0 1.2 — 1.6 — Total Assets $ 1,039.1 $ — $ 42.2 $ 29.7 $ — $ 23.9 $ 19.1 Liabilities: Current Risk Management Liabilities Risk Management Contracts - Commodity $ 304.1 $ 0.3 $ 6.6 $ 10.5 $ 7.5 $ 7.6 $ 3.4 Hedging Contracts - Commodity 11.3 — — — — — — Hedging Contracts - Interest Rate 36.3 — — — — — — Total Current Risk Management Liabilities 351.7 0.3 6.6 10.5 7.5 7.6 3.4 Long-term Risk Management Liabilities Risk Management Contracts - Commodity 390.7 — 0.8 2.1 40.2 0.2 — Hedging Contracts - Commodity 2.7 — — — — — — Hedging Contracts - Interest Rate 35.3 — — — — — — Total Long-term Risk Management Liabilities 428.7 — 0.8 2.1 40.2 0.2 — Total Liabilities $ 780.4 $ 0.3 $ 7.4 $ 12.6 $ 47.7 $ 7.8 $ 3.4 Total MTM Derivative Contract Net Assets (Liabilities) Recognized $ 258.7 $ (0.3) $ 34.8 $ 17.1 $ (47.7) $ 16.1 $ 15.7 December 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Assets: (in millions) Current Risk Management Assets Risk Management Contracts - Commodity $ 555.1 $ — $ 24.6 $ 30.1 $ — $ 19.7 $ 12.0 Hedging Contracts - Commodity 56.7 — — — — — — Hedging Contracts - Interest Rate — — — — — — — Total Current Risk Management Assets 611.8 — 24.6 30.1 — 19.7 12.0 Long-term Risk Management Assets Risk Management Contracts - Commodity 468.8 — 0.3 12.0 — — 0.5 Hedging Contracts - Commodity 86.8 — — — — — — Hedging Contracts - Interest Rate — — — — — — — Total Long-term Risk Management Assets 555.6 — 0.3 12.0 — — 0.5 Total Assets $ 1,167.4 $ — $ 24.9 $ 42.1 $ — $ 19.7 $ 12.5 Liabilities: Current Risk Management Liabilities Risk Management Contracts - Commodity $ 588.0 $ 0.2 $ 18.5 $ 5.4 $ 6.9 $ 29.7 $ 14.9 Hedging Contracts - Commodity 8.2 — — — — — — Hedging Contracts - Interest Rate 50.5 2.7 — — — — — Total Current Risk Management Liabilities 646.7 2.9 18.5 5.4 6.9 29.7 14.9 Long-term Risk Management Liabilities Risk Management Contracts - Commodity 377.6 — 6.9 0.2 43.9 1.0 1.7 Hedging Contracts - Commodity 2.2 — — — — — — Hedging Contracts - Interest Rate 56.9 — — — — — — Total Long-term Risk Management Liabilities 436.7 — 6.9 0.2 43.9 1.0 1.7 Total Liabilities $ 1,083.4 $ 2.9 $ 25.4 $ 5.6 $ 50.8 $ 30.7 $ 16.6 Total MTM Derivative Contract Net Assets (Liabilities) Recognized $ 84.0 $ (2.9) $ (0.5) $ 36.5 $ (50.8) $ (11.0) $ (4.1) Offsetting Assets and Liabilities The following tables show the net amounts of assets and liabilities presented on the balance sheets. The gross amounts offset include counterparty netting of risk management and hedging contracts and associated cash collateral in accordance with accounting guidance for “Derivatives and Hedging.” All derivative contracts subject to a master netting arrangement or similar agreement are offset on the balance sheets. December 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Assets: (in millions) Current Risk Management Assets Gross Amounts Recognized $ 479.1 $ — $ 40.2 $ 28.5 $ — $ 22.3 $ 19.1 Gross Amounts Offset (268.7) — (4.5) (10.1) — (1.7) (1.0) Net Amounts Presented 210.4 — 35.7 18.4 — 20.6 18.1 Long-term Risk Management Assets Gross Amounts Recognized 560.0 — 2.0 1.2 — 1.6 — Gross Amounts Offset (270.9) — (0.6) (1.2) — (0.2) — Net Amounts Presented 289.1 — 1.4 — — 1.4 — Total Assets $ 499.5 $ — $ 37.1 $ 18.4 $ — $ 22.0 $ 18.1 Liabilities: Current Risk Management Liabilities Gross Amounts Recognized $ 351.7 $ 0.3 $ 6.6 $ 10.5 $ 7.5 $ 7.6 $ 3.4 Gross Amounts Offset (251.7) (0.3) (4.6) (10.2) (0.2) (1.8) (1.1) Net Amounts Presented 100.0 — 2.0 0.3 7.3 5.8 2.3 Long-term Risk Management Liabilities Gross Amounts Recognized 428.7 — 0.8 2.1 40.2 0.2 — Gross Amounts Offset (204.3) — (0.6) (1.7) — (0.2) — Net Amounts Presented 224.4 — 0.2 0.4 40.2 — — Total Liabilities $ 324.4 $ — $ 2.2 $ 0.7 $ 47.5 $ 5.8 $ 2.3 Total MTM Derivative Contract Net Assets (Liabilities) $ 175.1 $ — $ 34.9 $ 17.7 $ (47.5) $ 16.2 $ 15.8 December 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Assets: (in millions) Current Risk Management Assets Gross Amounts Recognized $ 611.8 $ — $ 24.6 $ 30.1 $ — $ 19.7 $ 12.0 Gross Amounts Offset (394.3) — (2.2) (2.3) — (0.7) (0.4) Net Amounts Presented 217.5 — 22.4 27.8 — 19.0 11.6 Long-term Risk Management Assets Gross Amounts Recognized 555.6 — 0.3 12.0 — — 0.5 Gross Amounts Offset (234.4) — (0.3) (0.2) — — (0.5) Net Amounts Presented 321.2 — — 11.8 — — — Total Assets $ 538.7 $ — $ 22.4 $ 39.6 $ — $ 19.0 $ 11.6 Liabilities: Current Risk Management Liabilities Gross Amounts Recognized $ 646.7 $ 2.9 $ 18.5 $ 5.4 $ 6.9 $ 29.7 $ 14.9 Gross Amounts Offset (417.1) (0.2) (2.6) (3.4) (0.1) (0.8) (0.5) Net Amounts Presented 229.6 2.7 15.9 2.0 6.8 28.9 14.4 Long-term Risk Management Liabilities Gross Amounts Recognized 436.7 — 6.9 0.2 43.9 1.0 1.7 Gross Amounts Offset (194.9) — (0.3) (0.2) — — (0.5) Net Amounts Presented 241.8 — 6.6 — 43.9 1.0 1.2 Total Liabilities $ 471.4 $ 2.7 $ 22.5 $ 2.0 $ 50.7 $ 29.9 $ 15.6 Total MTM Derivative Contract Net Assets (Liabilities) $ 67.3 $ (2.7) $ (0.1) $ 37.6 $ (50.7) $ (10.9) $ (4.0) The tables below present the Registrants’ amount of gain (loss) recognized on risk management contracts: Amount of Gain (Loss) Recognized on Risk Management Contracts Year Ended December 31, 2024 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ (23.7) $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues (171.5) — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.2 (23.9) — — — Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 3.0 — 2.7 0.2 — — — Other Operation (0.2) — — — — — (0.1) Maintenance (0.2) (0.1) — — — — — Regulatory Assets (a) 73.0 (0.1) 21.7 2.8 (1.8) 26.0 14.2 Regulatory Liabilities (a) 270.7 — 53.4 13.4 — 93.6 95.0 Total Gain (Loss) on Risk Management Contracts $ 151.1 $ (0.2) $ 78.0 $ (7.5) $ (1.8) $ 119.6 $ 109.1 Year Ended December 31, 2023 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 24.6 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues (423.8) — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.1 24.5 — — — Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 2.5 — 2.3 0.1 — — — Other Operation (0.2) (0.1) — — — — — Maintenance (0.8) (0.3) (0.1) (0.1) (0.1) (0.1) (0.2) Regulatory Assets (a) (94.8) (0.2) (21.9) (3.1) (14.0) (29.8) (15.5) Regulatory Liabilities (a) 169.7 — 1.0 7.8 — 88.7 70.7 Total Gain (Loss) on Risk Management Contracts $ (322.8) $ (0.6) $ (18.6) $ 29.2 $ (14.1) $ 58.8 $ 55.0 Year Ended December 31, 2022 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 11.1 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 313.8 — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.5 10.6 — — — Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 5.0 — 4.5 0.1 — 0.2 — Other Operation 4.8 1.5 0.4 0.5 0.8 0.6 0.8 Maintenance 6.7 1.8 0.9 0.6 1.2 0.8 1.1 Regulatory Assets (a) 52.6 0.1 (0.1) (0.8) 52.1 3.6 (2.1) Regulatory Liabilities (a) 299.7 (0.6) 82.4 8.6 3.7 98.5 77.9 Total Gain on Risk Management Contracts $ 693.7 $ 2.8 $ 88.6 $ 19.6 $ 57.8 $ 103.7 $ 77.7 (a) Represents realized and unrealized gains and losses subject to regulatory accounting treatment recorded as either current or noncurrent on the balance sheets. Certain qualifying derivative instruments have been designated as normal purchase or normal sale contracts, as provided in the accounting guidance for “Derivatives and Hedging.” Derivative contracts that have been designated as normal purchases or normal sales under that accounting guidance are not subject to MTM accounting treatment and are recognized on the statements of income on an accrual basis. The accounting for the changes in the fair value of a derivative instrument depends on whether it qualifies for and has been designated as part of a hedging relationship and further, on the type of hedging relationship. Depending on the exposure, management designates a hedging instrument as a fair value hedge or a cash flow hedge. For contracts that have not been designated as part of a hedging relationship, the accounting for changes in fair value depends on whether the derivative instrument is held for trading purposes. Unrealized and realized gains and losses on derivative instruments held for trading purposes are included in revenues on a net basis on the statements of income. Unrealized and realized gains and losses on derivative instruments not held for trading purposes are included in revenues or expenses on the statements of income depending on the relevant facts and circumstances. Certain derivatives that economically hedge future commodity risk are recorded in the same line item on the statements of income as that of the associated risk being hedged. However, unrealized and some realized gains and losses in regulated jurisdictions for both trading and non-trading derivative instruments are recorded as regulatory assets (for losses) or regulatory liabilities (for gains) in accordance with the accounting guidance for “Regulated Operations.” Accounting for Fair Value Hedging Strategies (Applies to AEP) For fair value hedges (i.e. hedging the exposure to changes in the fair value of an asset, liability or an identified portion thereof attributable to a particular risk), the gain or loss on the derivative instrument as well as the offsetting gain or loss on the hedged item associated with the hedged risk impacts net income during the period of change. AEP records realized and unrealized gains or losses on interest rate swaps that are designated and qualify for fair value hedge accounting treatment and any offsetting changes in the fair value of the debt being hedged in Interest Expense on the statements of income. The following table shows the impacts recognized on the balance sheets related to the hedged items in fair value hedging relationships: Carrying Amount of the Hedged Liabilities Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of the Hedged Liabilities December 31, 2024 December 31, 2023 December 31, 2024 December 31, 2023 (in millions) Long-term Debt (a) (b) $ (898.6) $ (878.2) $ 49.3 $ 68.4 (a) Amounts included within Noncurrent Liabilities line item Long-term Debt and Current Liabilities line item Long-term Debt Due Within One Year on the balance sheet. (b) Amounts include $(22) million and $(30) million as of December 31, 2024 and 2023, respectively, for the fair value hedge adjustment of hedged debt obligations for which hedge accounting has been discontinued. The pretax effects of fair value hedge accounting on income were as follows: Years Ended December 31, 2024 2023 2022 (in millions) Gain (Loss) on Interest Rate Contracts: Fair Value Hedging Instruments (a) $ 26.8 $ 29.0 $ (90.4) Fair Value Portion of Long-term Debt (a) (26.8) (29.0) 90.4 (a) Gain (Loss) is included in Interest Expense on the statements of income. Accounting for Cash Flow Hedging Strategies (Applies to AEP, AEP Texas, APCo, I&M, PSO and SWEPCo) For cash flow hedges (i.e. hedging the exposure to variability in expected future cash flows that is attributable to a particular risk), the Registrants initially report the gain or loss on the derivative instrument as a component of Accumulated Other Comprehensive Income (Loss) on the balance sheets until the period the hedged item affects net income. Realized gains and losses on derivative contracts for the purchase and sale of power designated as cash flow hedges are included in Total Revenues or Purchased Electricity, Fuel and Other Consumables Used for Electric Generation on the statements of income or in Regulatory Assets or Regulatory Liabilities on the balance sheets, depending on the specific nature of the risk being hedged. During the years ended 2024, 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 year ended 2024, AEP, AEP Texas and PSO applied cash flow hedging to outstanding interest rate derivatives and the other Registrant Subsidiaries did not. During the year ended 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 year ended 2022, AEP and PSO applied cash flow hedging to outstanding interest rate derivatives and the other Registrant Subsidiaries did not. For details on effective cash flow hedges included in Accumulated Other Comprehensive Income (Loss) on the balance sheets and the reasons for changes in cash flow hedges, see Note 3 - Comprehensive Income. Cash flow hedges included in Accumulated Other Comprehensive Income (Loss) on the balance sheets were: Impact of Cash Flow Hedges on the Registrants’ Balance Sheets December 31, 2024 December 31, 2023 Portion Expected to Portion Expected to AOCI be Reclassed to AOCI be Reclassed to Gain (Loss) Net Income During Gain (Loss) Net Income During Net of Tax the Next Twelve Months Net of Tax the Next Twelve Months Commodity Interest Rate Commodity Interest Rate Commodity Interest Rate Commodity Interest Rate (in millions) AEP $ 98.5 $ 3.3 $ 33.9 $ 2.8 $ 104.9 $ (8.1) $ 38.3 $ 3.2 AEP Texas — 6.3 — 0.7 — 0.5 — 0.2 APCo — 5.1 — 0.8 — 5.9 — 0.8 I&M — (5.1) — (0.4) — (5.5) — (0.4) PSO — 3.6 — 0.2 — (0.2) — — SWEPCo — 1.0 — 0.3 — 1.3 — 0.3 As of December 31, 2024 the maximum length of time that AEP is hedging its exposure to variability in future cash flows related to forecasted transactions is approximately 10 years. 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) A limited number of derivative contracts include collateral triggering events, which include a requirement to maintain certain credit ratings. On an ongoing basis, AEP’s risk management organization assesses the appropriateness of these collateral triggering events in contracts. The Registrants have not experienced a downgrade below a specified credit rating threshold that would require the posting of additional collateral. The total exposure of AEP’s derivative contracts with collateral triggering events in a net liability position was immaterial as of December 31, 2024 and 2023. The Registrant Subsidiaries had no derivative contracts with collateral triggering events in a net liability position as of December 31, 2024 and 2023. Cross-Acceleration Triggers (Applies to AEP) 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 $72 million and $107 million and no cash collateral posted as of December 31, 2024 and 2023, respectively. If a cross-acceleration provision would have been triggered, settlement at fair value would have been required. The Registrant Subsidiaries’ derivative contracts with cross-acceleration provisions outstanding as of December 31, 2024 and 2023 were immaterial. Cross-Default Triggers (Applies to AEP, APCo, PSO and SWEPCo)

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	12 Months Ended
	Dec. 31, 2024
Fair Value Disclosures [Abstract]
FAIR VALUE MEASUREMENTS	FAIR VALUE MEASUREMENTS The disclosures in this note apply to all Registrants except AEPTCo unless indicated otherwise. Fair Value Measurements of Long-term Debt (Applies to all Registrants) The fair values of Long-term Debt are based on quoted market prices, without credit enhancements, for the same or similar issues and the current interest rates offered for instruments with similar maturities classified as Level 2 measurement inputs. These instruments are not marked-to-market. The estimates presented are not necessarily indicative of the amounts that could be realized in a current market exchange. The fair value of AEP’s Equity Units (Level 1) are valued based on publicly-traded securities issued by AEP. The book values and fair values of Long-term Debt are summarized in the following table: December 31, 2024 2023 Company Book Value Fair Value Book Value Fair Value (in millions) AEP $ 42,642.8 $ 38,964.7 $ 40,143.2 $ 37,325.7 AEP Texas 6,441.6 5,831.4 5,889.8 5,400.7 AEPTCo 5,768.1 4,853.1 5,414.4 4,796.9 APCo 5,660.3 5,346.0 5,588.3 5,390.1 I&M 3,494.3 3,153.8 3,499.4 3,291.6 OPCo 3,715.7 3,203.4 3,366.8 2,992.1 PSO 2,855.6 2,562.1 2,384.6 2,154.3 SWEPCo 3,980.8 3,431.5 3,646.9 3,209.7 Fair Value Measurements of Other Temporary Investments (Applies to AEP) Other Temporary Investments include marketable securities that management intends to hold for less than one year and investments by AEP’s protected cell of EIS. See “Other Temporary Investments” section of Note 1 for additional information. The following is a summary of Other Temporary Investments and Restricted Cash: December 31, 2024 Gross Gross Unrealized Unrealized Fair Other Temporary Investments and Restricted Cash Cost Gains Losses Value (in millions) Restricted Cash (a) $ 43.1 $ — $ — $ 43.1 Other Cash Deposits 13.9 — — 13.9 Fixed Income Securities – Mutual Funds (b) 167.2 — (5.3) 161.9 Equity Securities – Mutual Funds 12.7 26.9 — 39.6 Total Other Temporary Investments and Restricted Cash $ 236.9 $ 26.9 $ (5.3) $ 258.5 December 31, 2023 Gross Gross Unrealized Unrealized Fair Other Temporary Investments and Restricted Cash Cost Gains Losses Value (in millions) Restricted Cash (a) $ 48.9 $ — $ — $ 48.9 Other Cash Deposits 13.9 — — 13.9 Fixed Income Securities – Mutual Funds (b) 165.9 — (6.2) 159.7 Equity Securities – Mutual Funds 14.8 25.9 — 40.7 Total Other Temporary Investments and Restricted Cash $ 243.5 $ 25.9 $ (6.2) $ 263.2 (a) Primarily represents amounts held for the repayment of debt. (b) Primarily short and intermediate maturities which may be sold and do not contain maturity dates. The following table provides the activity for fixed income and equity securities within Other Temporary Investments: Years Ended December 31, 2024 2023 2022 (in millions) Proceeds from Investment Sales $ 26.8 $ 7.6 $ 30.2 Purchases of Investments 20.1 18.5 18.8 Gross Realized Gains on Investment Sales 6.3 1.1 6.1 Gross Realized Losses on Investment Sales 0.8 0.3 1.3 Fair Value Measurements of Trust Assets for Decommissioning and SNF Disposal (Applies to AEP and I&M) Securities held in trust funds for decommissioning nuclear facilities and for the disposal of SNF are recorded at fair value. See “Nuclear Trust Funds” section of Note 1 for additional information. The following is a summary of nuclear trust fund investments: December 31, 2024 2023 Gross Gross Other-Than- Gross Gross Other-Than- Fair Unrealized Unrealized Temporary Fair Unrealized Unrealized Temporary Value Gains Losses Impairments Value Gains Losses Impairments (in millions) Cash and Cash Equivalents $ 23.3 $ — $ — $ — $ 16.8 $ — $ — $ — Fixed Income Securities: United States Government 1,322.8 8.2 (5.3) (20.2) 1,273.0 28.6 (3.9) (33.2) Corporate Debt 211.3 0.7 (9.8) (5.8) 132.1 4.8 (5.2) (8.6) State and Local Government — — — — 1.7 — — — Subtotal Fixed Income Securities 1,534.1 8.9 (15.1) (26.0) 1,406.8 33.4 (9.1) (41.8) Equity Securities - Domestic 2,837.7 2,288.9 (0.4) — 2,436.6 1,869.5 (0.9) — Spent Nuclear Fuel and Decommissioning Trusts $ 4,395.1 $ 2,297.8 $ (15.5) $ (26.0) $ 3,860.2 $ 1,902.9 $ (10.0) $ (41.8) The following table provides the securities activity within the decommissioning and SNF trusts: Years Ended December 31, 2024 2023 2022 (in millions) Proceeds from Investment Sales $ 2,851.2 $ 2,787.5 $ 2,713.6 Purchases of Investments 2,902.4 2,845.1 2,765.4 Gross Realized Gains on Investment Sales 125.5 99.0 52.4 Gross Realized Losses on Investment Sales 11.5 26.6 42.6 The base cost of fixed income securities was $1.5 billion and $1.4 billion as of December 31, 2024 and 2023, respectively. The base cost of equity securities was $549 million and $568 million as of December 31, 2024 and 2023, respectively. The fair value of fixed income securities held in the nuclear trust funds, summarized by contractual maturities, as of December 31, 2024 was as follows: Fair Value of Fixed Income Securities (in millions) Within 1 year $ 376.4 After 1 year through 5 years 598.8 After 5 years through 10 years 236.2 After 10 years 322.7 Total $ 1,534.1 Fair Value Measurements of Financial Assets and Liabilities For a discussion of fair value accounting and the classification of assets and liabilities within the fair value hierarchy, see the “Fair Value Measurements of Assets and Liabilities” section of Note 1. The following tables set forth, by level within the fair value hierarchy, the Registrants’ financial assets and liabilities that were accounted for at fair value on a recurring basis. As required by the accounting guidance for “Fair Value Measurements and Disclosures,” financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. Management’s assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. There have not been any significant changes in management’s valuation techniques. AEP December 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments and Restricted Cash Restricted Cash $ 43.1 $ — $ — $ — $ 43.1 Other Cash Deposits (a) — — — 13.9 13.9 Fixed Income Securities – Mutual Funds 161.9 — — — 161.9 Equity Securities – Mutual Funds (b) 39.6 — — — 39.6 Total Other Temporary Investments and Restricted Cash 244.6 — — 13.9 258.5 Risk Management Assets Risk Management Commodity Contracts (c) (d) 2.9 597.3 291.6 (517.2) 374.6 Cash Flow Hedges: Commodity Hedges (c) — 115.6 21.9 (12.6) 124.9 Total Risk Management Assets 2.9 712.9 313.5 (529.8) 499.5 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 9.6 — — 13.7 23.3 Fixed Income Securities: United States Government — 1,322.8 — — 1,322.8 Corporate Debt — 211.3 — — 211.3 State and Local Government — — — — — Subtotal Fixed Income Securities — 1,534.1 — — 1,534.1 Equity Securities – Domestic (b) 2,837.7 — — — 2,837.7 Total Spent Nuclear Fuel and Decommissioning Trusts 2,847.3 1,534.1 — 13.7 4,395.1 Total Assets $ 3,094.8 $ 2,247.0 $ 313.5 $ (502.2) $ 5,153.1 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (d) $ 4.4 $ 534.1 $ 147.7 $ (433.6) $ 252.6 Cash Flow Hedges: Commodity Hedges (c) — 12.6 0.2 (12.6) 0.2 Fair Value Hedges — 71.6 — — 71.6 Total Risk Management Liabilities $ 4.4 $ 618.3 $ 147.9 $ (446.2) $ 324.4 December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments and Restricted Cash Restricted Cash $ 48.9 $ — $ — $ — $ 48.9 Other Cash Deposits (a) — — — 13.9 13.9 Fixed Income Securities – Mutual Funds 159.7 — — — 159.7 Equity Securities – Mutual Funds (b) 40.7 — — — 40.7 Total Other Temporary Investments and Restricted Cash 249.3 — — 13.9 263.2 Risk Management Assets Risk Management Commodity Contracts (c) (f) 9.7 736.9 274.3 (617.0) 403.9 Cash Flow Hedges: Commodity Hedges (c) — 123.5 19.8 (8.5) 134.8 Total Risk Management Assets 9.7 860.4 294.1 (625.5) 538.7 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 7.8 — — 9.0 16.8 Fixed Income Securities: United States Government — 1,273.0 — — 1,273.0 Corporate Debt — 132.1 — — 132.1 State and Local Government — 1.7 — — 1.7 Subtotal Fixed Income Securities — 1,406.8 — — 1,406.8 Equity Securities – Domestic (b) 2,436.6 — — — 2,436.6 Total Spent Nuclear Fuel and Decommissioning Trusts 2,444.4 1,406.8 — 9.0 3,860.2 Total Assets $ 2,703.4 $ 2,267.2 $ 294.1 $ (602.6) $ 4,662.1 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (f) $ 24.7 $ 783.8 $ 154.1 $ (600.3) $ 362.3 Cash Flow Hedges: Commodity Hedges (c) — 9.6 0.6 (8.5) 1.7 Interest Rate Hedges — 9.0 — — 9.0 Fair Value Hedges — 98.4 — — 98.4 Total Risk Management Liabilities $ 24.7 $ 900.8 $ 154.7 $ (608.8) $ 471.4 AEP Texas December 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 23.5 $ — $ — $ — $ 23.5 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 0.3 $ — $ (0.3) $ — December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 34.0 $ — $ — $ — $ 34.0 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 0.2 $ — $ (0.2) $ — Cash Flow Hedges: Interest Rate Hedges — 2.7 — — 2.7 Total Risk Management Liabilities $ — $ 2.9 $ — $ (0.2) $ 2.7 APCo December 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 16.2 $ — $ — $ — $ 16.2 Risk Management Assets Risk Management Commodity Contracts (c) — 6.5 35.2 (4.6) 37.1 Total Assets $ 16.2 $ 6.5 $ 35.2 $ (4.6) $ 53.3 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 6.9 $ — $ (4.7) $ 2.2 December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 14.9 $ — $ — $ — $ 14.9 Risk Management Assets Risk Management Commodity Contracts (c) — 1.1 23.5 (2.2) 22.4 Total Assets $ 14.9 $ 1.1 $ 23.5 $ (2.2) $ 37.3 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 24.0 $ 1.1 $ (2.6) $ 22.5 I&M December 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ 19.9 $ 6.9 $ (8.4) $ 18.4 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 9.6 — — 13.7 23.3 Fixed Income Securities: United States Government — 1,322.8 — — 1,322.8 Corporate Debt — 211.3 — — 211.3 State and Local Government — — — — — Subtotal Fixed Income Securities — 1,534.1 — — 1,534.1 Equity Securities - Domestic (b) 2,837.7 — — — 2,837.7 Total Spent Nuclear Fuel and Decommissioning Trusts 2,847.3 1,534.1 — 13.7 4,395.1 Total Assets $ 2,847.3 $ 1,554.0 $ 6.9 $ 5.3 $ 4,413.5 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 9.2 $ 0.5 $ (9.0) $ 0.7 December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ 37.4 $ 4.5 $ (2.3) $ 39.6 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 7.8 — — 9.0 16.8 Fixed Income Securities: United States Government — 1,273.0 — — 1,273.0 Corporate Debt — 132.1 — — 132.1 State and Local Government — 1.7 — — 1.7 Subtotal Fixed Income Securities — 1,406.8 — — 1,406.8 Equity Securities - Domestic (b) 2,436.6 — — — 2,436.6 Total Spent Nuclear Fuel and Decommissioning Trusts 2,444.4 1,406.8 — 9.0 3,860.2 Total Assets $ 2,444.4 $ 1,444.2 $ 4.5 $ 6.7 $ 3,899.8 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 3.7 $ 1.7 $ (3.4) $ 2.0 OPCo December 31, 2024 Level 1 Level 2 Level 3 Other Total Liabilities: (in millions) Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 0.2 $ 47.5 $ (0.2) $ 47.5 December 31, 2023 Level 1 Level 2 Level 3 Other Total Liabilities: (in millions) Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 0.2 $ 50.6 $ (0.1) $ 50.7 PSO December 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ 3.1 $ 20.8 $ (1.9) $ 22.0 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 7.0 $ 0.8 $ (2.0) $ 5.8 December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ — $ 19.7 $ (0.7) $ 19.0 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 29.6 $ 1.1 $ (0.8) $ 29.9 SWEPCo December 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 3.4 $ — $ — $ — $ 3.4 Risk Management Assets Risk Management Commodity Contracts (c) — 1.0 18.1 (1.0) 18.1 Total Assets $ 3.4 $ 1.0 $ 18.1 $ (1.0) $ 21.5 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 2.8 $ 0.6 $ (1.1) $ 2.3 December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ 0.5 $ 12.0 $ (0.9) $ 11.6 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 15.7 $ 0.9 $ (1.0) $ 15.6 (a) Amounts in “Other” column primarily represent cash deposits in bank accounts with financial institutions or third-parties. Level 1 and Level 2 amounts primarily represent investments in money market funds. (b) Amounts represent publicly-traded equity securities and equity-based mutual funds. (c) Amounts in “Other” column primarily represent counterparty netting of risk management and hedging contracts and associated cash collateral under the accounting guidance for “Derivatives and Hedging.” (d) The December 31, 2024 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $(1) million in 2025; Level 2 matures $16 million in 2025, $43 million in periods 2026-2028, $4 million in periods 2029-2030; Level 3 matures $106 million in 2025, $45 million in periods 2026-2028, $9 million in periods 2029-2030 and $(16) million in periods 2031-2034. Risk management commodity contracts are substantially comprised of energy contracts. (e) Amounts in “Other” column primarily represent accrued interest receivables from financial institutions. Level 1 amounts primarily represent investments in money market funds. (f) The December 31, 2023 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $(11) million in 2024 and $(4) million in 2025-2027; Level 2 matures $(99) million in 2024, $(44) million in periods 2025-2027; $7 million in periods 2028-2029 and $2 million in periods 2030-2033; Level 3 matures $74 million in 2024, $43 million in periods 2025-2027, $18 million in periods 2028-2029 and $(16) million in periods 2030-2033. Risk management commodity contracts are substantially comprised of energy contracts. The following tables set forth a reconciliation of changes in the fair value of net trading derivatives classified as Level 3 in the fair value hierarchy: Year Ended December 31, 2024 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of December 31, 2023 $ 139.4 $ 22.4 $ 2.8 $ (50.6) $ 18.6 $ 11.1 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 90.3 24.1 7.3 (1.1) 26.2 23.6 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) 3.9 — — — — — Settlements (167.6) (46.5) (10.0) 7.9 (44.8) (36.0) Transfers into Level 3 (d) (e) 6.8 — — — — — Transfers out of Level 3 (e) (6.4) — — — — 0.5 Changes in Fair Value Allocated to Regulated Jurisdictions (f) 84.4 35.2 6.3 (3.7) 20.0 18.3 Balance as of December 31, 2024 $ 165.6 $ 35.2 $ 6.4 $ (47.5) $ 20.0 $ 17.5 Year Ended December 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) 52.1 (11.7) 4.2 (3.6) 29.8 20.0 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) 71.1 — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) (17.4) — — — — — Settlements (172.2) (57.3) (8.8) 5.6 (53.4) (34.2) Transfers into Level 3 (d) (e) (6.1) — — — — — Transfers out of Level 3 (e) 3.8 — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 47.7 22.3 2.8 (12.6) 18.5 11.1 Balance as of December 31, 2023 $ 139.4 $ 22.4 $ 2.8 $ (50.6) $ 18.6 $ 11.1 Year Ended December 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) 69.5 3.0 3.7 6.5 24.2 35.8 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (34.9) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 9.6 — — — — — Settlements (154.6) (44.7) (3.0) 0.3 (36.3) (45.0) Transfers into Level 3 (d) (e) 1.7 — — — — — Transfers out of Level 3 (e) 0.1 — — — — 6.9 Changes in Fair Value Allocated to Regulated Jurisdictions (f) 165.9 69.1 4.6 45.7 23.7 5.6 Balance as of December 31, 2022 $ 160.4 $ 69.1 $ 4.6 $ (40.0) $ 23.7 $ 14.2 (a) Included in revenues on the statements of income. (b) Represents the change in fair value between the beginning of the reporting period and the settlement of the risk management commodity contract. (c) Included in cash flow hedges on the statements of comprehensive income. (d) Represents existing assets or liabilities that were previously categorized as Level 2. (e) Transfers are recognized based on their value at the beginning of the reporting period that the transfer occurred. (f) Relates to the net gains (losses) of those contracts that are not reflected on the statements of income. These changes in fair value are recorded as regulatory liabilities for net gains and as regulatory assets for net losses or accounts payable. The following tables quantify the significant unobservable inputs used in developing the fair value of Level 3 positions: Significant Unobservable Inputs December 31, 2024 Significant Input/Range Type of Fair Value Valuation Unobservable Weighted Company Input Assets Liabilities Technique Input (a) Low High Average (c) (in millions) AEP Energy Contracts $ 221.2 $ 144.6 Discounted Cash Flow Forward Market Price $ 2.75 $ 149.30 $ 49.34 AEP FTRs 92.3 3.3 Discounted Cash Flow Forward Market Price (29.48) 19.70 0.24 APCo FTRs 35.2 — Discounted Cash Flow Forward Market Price (0.25) 9.32 1.56 I&M FTRs 6.9 0.5 Discounted Cash Flow Forward Market Price (4.07) 9.32 1.34 OPCo Energy Contracts — 47.5 Discounted Cash Flow Forward Market Price 14.53 72.40 42.44 PSO FTRs 20.8 0.8 Discounted Cash Flow Forward Market Price (29.48) 10.54 (3.88) SWEPCo FTRs 18.1 0.6 Discounted Cash Flow Forward Market Price (29.48) 10.54 (3.88) December 31, 2023 Significant Input/Range Type of Fair Value Valuation Unobservable Weighted Company Input Assets Liabilities Technique Input Low High Average (c) (in millions) AEP Energy Contracts $ 225.5 $ 144.9 Discounted Cash Flow Forward Market Price (a) $ 5.21 $ 153.77 $ 45.05 AEP Natural Gas Contracts — 0.5 Discounted Cash Flow Forward Market Price (b) 3.11 3.11 3.11 AEP FTRs 68.6 9.3 Discounted Cash Flow Forward Market Price (a) (25.45) 17.07 — APCo FTRs 23.5 1.1 Discounted Cash Flow Forward Market Price (a) (1.04) 6.45 1.36 I&M FTRs 4.5 1.7 Discounted Cash Flow Forward Market Price (a) (1.48) 8.40 0.85 OPCo Energy Contracts — 50.6 Discounted Cash Flow Forward Market Price (a) 22.92 67.53 42.85 PSO FTRs 19.7 1.1 Discounted Cash Flow Forward Market Price (a) (25.45) 4.80 (4.33) SWEPCo Natural Gas Contracts — 0.5 Discounted Cash Flow Forward Market Price (b) 3.11 3.11 3.11 SWEPCo FTRs 12.0 0.4 Discounted Cash Flow Forward Market Price (a) (25.45) 4.80 (4.33) (a) Represents market prices in dollars per MWh. (b) Represents market prices in dollars per MMBtu. (c) The weighted-average is the product of the forward market price of the underlying commodity and volume weighted by term. The following table provides the measurement uncertainty of fair value measurements to increases (decreases) in significant unobservable inputs related to Energy Contracts, Natural Gas Contracts, FTRs and Other Investments for the Registrants as of December 31, 2024 and 2023: 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	12 Months Ended
	Dec. 31, 2024
Income Tax Disclosure [Abstract]
INCOME TAXES	INCOME TAXES The disclosures in this note apply to all Registrants unless indicated otherwise. Income Tax Expense (Benefit) The details of the Registrants’ Income Tax Expense (Benefit) as reported are as follows: Year Ended December 31, 2024 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Federal: Current $ (2.8) $ 22.1 $ 75.1 $ 79.9 $ 16.6 $ 41.5 $ (119.0) $ (111.4) Deferred (57.9) 77.1 89.1 (17.8) (118.8) (2.7) 20.1 (86.1) Total Federal (60.7) 99.2 164.2 62.1 (102.2) 38.8 (98.9) (197.5) State and Local: Current (5.2) 2.9 5.6 12.6 7.0 3.1 (0.2) 1.8 Deferred 26.7 — 20.5 0.4 — 10.5 (0.5) 11.7 Total State and Local 21.5 2.9 26.1 13.0 7.0 13.6 (0.7) 13.5 Income Tax Expense (Benefit) $ (39.2) $ 102.1 $ 190.3 $ 75.1 $ (95.2) $ 52.4 $ (99.6) $ (184.0) Year Ended December 31, 2023 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Federal: Current $ (116.7) $ 19.8 $ 93.9 $ 62.2 $ 93.2 $ 46.6 $ (60.8) $ (88.1) Deferred 115.9 63.5 52.3 (60.5) (56.9) 2.8 2.9 59.9 Total Federal (0.8) 83.3 146.2 1.7 36.3 49.4 (57.9) (28.2) State and Local: Current 69.0 2.7 9.1 6.3 21.1 (0.3) 0.3 1.0 Deferred (13.6) (0.1) (8.2) 6.2 1.2 5.2 4.0 (6.1) Total State and Local 55.4 2.6 0.9 12.5 22.3 4.9 4.3 (5.1) Income Tax Expense (Benefit) $ 54.6 $ 85.9 $ 147.1 $ 14.2 $ 58.6 $ 54.3 $ (53.6) $ (33.3) Year Ended December 31, 2022 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Federal: Current $ 113.1 $ 29.0 $ 98.0 $ (61.0) $ 43.4 $ (27.0) $ (3.3) $ (32.3) Deferred (88.8) 41.4 46.0 86.6 (51.3) 73.3 (50.5) 13.4 Total Federal 24.3 70.4 144.0 25.6 (7.9) 46.3 (53.8) (18.9) State and Local: Current 26.6 2.2 8.8 (0.4) 10.9 (0.3) — (1.8) Deferred (45.5) — 16.3 (7.0) 1.2 (1.8) 4.6 (4.5) Total State and Local (18.9) 2.2 25.1 (7.4) 12.1 (2.1) 4.6 (6.3) Income Tax Expense (Benefit) $ 5.4 $ 72.6 $ 169.1 $ 18.2 $ 4.2 $ 44.2 $ (49.2) $ (25.2) The following are reconciliations for the Registrants between the federal income taxes computed by multiplying pretax income by the federal statutory tax rate and the income taxes reported: Year Ended December 31, 2024 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Net Income $ 2,975.8 $ 420.1 $ 688.4 $ 421.7 $ 391.4 $ 305.6 $ 249.3 $ 325.7 Less: Equity Earnings (1.4) — — — — — — (1.4) Income Tax Expense (Benefit) (39.2) 102.1 190.3 75.1 (95.2) 52.4 (99.6) (184.0) Pretax Income $ 2,935.2 $ 522.2 $ 878.7 $ 496.8 $ 296.2 $ 358.0 $ 149.7 $ 140.3 Income Taxes on Pretax Income at Statutory Rate (21%) $ 616.5 $ 109.7 $ 184.5 $ 104.3 $ 62.2 $ 75.2 $ 31.4 $ 29.5 Increase (Decrease) in Income Taxes Resulting from the Following Items: Reversal of Origination Flow-Through 20.5 0.8 2.7 6.6 4.0 2.7 0.4 2.1 Investment Tax Credit Amortization (58.4) (0.9) — 0.1 (2.0) 0.1 (1.4) (0.1) Production Tax Credits (214.2) — — (0.3) (69.0) — (73.8) (70.7) State and Local Income Taxes, Net 16.7 2.3 20.5 10.3 5.5 10.7 (0.6) 10.6 Removal Costs (14.6) — — (11.2) (3.7) — — — AFUDC Equity (46.5) (9.6) (18.8) (5.3) (2.8) (4.9) (1.6) (2.8) Tax Reform Excess ADIT Reversal (91.6) (5.1) 1.6 (30.1) (15.5) (31.1) (5.5) (4.0) Remeasurement of Excess ADIT (262.2) 6.4 — — (73.3) — (48.6) (146.8) Other (5.4) (1.5) (0.2) 0.7 (0.6) (0.3) 0.1 (1.8) Income Tax Expense (Benefit) $ (39.2) $ 102.1 $ 190.3 $ 75.1 $ (95.2) $ 52.4 $ (99.6) $ (184.0) Effective Income Tax Rate (1.3) % 19.6 % 21.7 % 15.1 % (32.1) % 14.6 % (66.5) % (131.1) % . Year Ended December 31, 2023 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Net Income $ 2,212.6 $ 370.4 $ 614.2 $ 294.4 $ 335.9 $ 328.2 $ 208.8 $ 223.8 Less: Equity Earnings (1.4) — — — — — — (1.4) Income Tax Expense (Benefit) 54.6 85.9 147.1 14.2 58.6 54.3 (53.6) (33.3) Pretax Income $ 2,265.8 $ 456.3 $ 761.3 $ 308.6 $ 394.5 $ 382.5 $ 155.2 $ 189.1 Income Taxes on Pretax Income at Statutory Rate (21%) $ 475.8 $ 95.8 $ 159.9 $ 64.8 $ 82.8 $ 80.3 $ 32.6 $ 39.7 Increase (Decrease) in Income Taxes Resulting from the Following Items: Reversal of Origination Flow-Through 26.0 0.6 2.4 9.9 6.4 2.6 0.4 2.1 Investment Tax Credit Amortization (50.3) (0.7) — — (1.6) — (1.4) (0.2) Production Tax Credits (175.2) — — (0.1) — — (64.3) (67.1) State and Local Income Taxes, Net 43.7 2.1 0.7 9.9 17.5 3.9 3.5 (4.0) Removal Costs (22.0) — — (5.1) (11.8) — — — AFUDC Equity (39.8) (6.0) (17.5) (5.5) (2.3) (3.6) (1.8) (2.4) Tax Reform Excess ADIT Reversal (151.1) (6.0) 1.7 (17.3) (30.0) (28.9) (23.3) (12.6) Remeasurement of Excess ADIT (46.0) — — (46.0) — — — — Federal Return to Provision — (0.1) — 3.4 (2.5) (0.4) 0.6 1.0 Disallowance Cost — — — — — — — 12.0 Other (6.5) 0.2 (0.1) 0.2 0.1 0.4 0.1 (1.8) Income Tax Expense (Benefit) $ 54.6 $ 85.9 $ 147.1 $ 14.2 $ 58.6 $ 54.3 $ (53.6) $ (33.3) Effective Income Tax Rate 2.4 % 18.8 % 19.3 % 4.6 % 14.9 % 14.2 % (34.5) % (17.6) % Year Ended December 31, 2022 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Net Income $ 2,305.6 $ 307.9 $ 594.2 $ 394.2 $ 324.7 $ 287.8 $ 167.6 $ 294.3 Less: Equity Earnings (1.4) — — — — (0.6) — (1.4) Income Tax Expense (Benefit) 5.4 72.6 169.1 18.2 4.2 44.2 (49.2) (25.2) Pretax Income $ 2,309.6 $ 380.5 $ 763.3 $ 412.4 $ 328.9 $ 331.4 $ 118.4 $ 267.7 Income Taxes on Pretax Income at Statutory Rate (21%) $ 485.0 $ 79.9 $ 160.3 $ 86.6 $ 69.1 $ 69.6 $ 24.9 $ 56.2 Increase (Decrease) in Income Taxes Resulting from the Following Items: Reversal of Origination Flow-Through 17.1 — — 4.7 2.9 3.0 — 2.3 Investment Tax Credit Amortization (14.3) — — — (3.1) — (1.6) — Production Tax Credits (197.1) — — — — — (47.7) (57.1) State and Local Income Taxes, Net (14.0) 1.7 19.8 (5.9) 9.6 (1.6) 4.3 (4.9) Removal Costs (26.5) — — (9.8) (12.4) — — — AFUDC Equity (29.3) (4.1) (14.8) (3.7) (2.1) (2.9) — — Tax Reform Excess ADIT Reversal (214.5) (5.5) — (50.9) (54.0) (27.5) (25.4) (14.8) Federal Return to Provision (17.4) — — (2.8) (6.2) 3.5 (3.7) — Other 16.4 0.6 3.8 — 0.4 0.1 — (6.9) Income Tax Expense (Benefit) $ 5.4 $ 72.6 $ 169.1 $ 18.2 $ 4.2 $ 44.2 $ (49.2) $ (25.2) Effective Income Tax Rate 0.2 % 19.1 % 22.2 % 4.4 % 1.3 % 13.3 % (41.6) % (9.4) Net Deferred Tax Liability The following tables show elements of the net deferred tax liability and significant temporary differences for each Registrant. Amounts presented for 2023 were recast to allocate “Deferred State Income Taxes”, and other miscellaneous temporary differences, amongst other categories to substantively reflect the elements of the net deferred tax liability. Year Ended December 31, 2024 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Deferred Tax Assets $ 2,651.9 $ 139.1 $ 172.6 $ 379.1 $ 1,072.2 $ 186.5 $ 266.9 $ 292.8 Deferred Tax Liabilities (12,624.3) (1,461.8) (1,451.2) (2,412.6) (2,248.0) (1,387.6) (1,197.5) (1,564.1) Net Deferred Tax Liabilities $ (9,972.4) $ (1,322.7) $ (1,278.6) $ (2,033.5) $ (1,175.8) $ (1,201.1) $ (930.6) $ (1,271.3) Property Related Temporary Differences $ (8,939.7) $ (1,364.0) $ (1,416.6) $ (1,784.8) $ (189.9) $ (1,290.9) $ (1,009.8) $ (1,353.1) Amounts Due to Customers for Future Income Taxes 779.6 109.3 121.4 119.0 73.1 95.6 80.7 90.2 Securitized Assets (133.4) (26.5) — (25.7) — — — (81.1) Regulatory Assets (966.2) (63.2) (0.2) (302.4) (49.2) (45.3) (53.1) (87.0) Accrued Nuclear Decommissioning (1,052.2) — — — (1,052.2) — — — Net Operating Loss Carryforward 110.3 — 2.5 0.4 — 2.9 27.8 36.5 Valuation Allowance (35.0) — (0.1) — — — — — Tax Credit Carryforward 197.5 4.3 — 0.1 39.6 38.5 26.5 31.7 Operating Lease Liability 145.3 12.3 0.3 16.2 13.5 13.3 27.1 35.7 Investment in Partnership (302.1) — — (0.1) — (0.8) — (1.5) All Other, Net 223.5 5.1 14.1 (56.2) (10.7) (14.4) (29.8) 57.3 Net Deferred Tax Liabilities $ (9,972.4) $ (1,322.7) $ (1,278.6) $ (2,033.5) $ (1,175.8) $ (1,201.1) $ (930.6) $ (1,271.3) Year Ended December 31, 2023 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Deferred Tax Assets $ 3,216.1 $ 173.6 $ 188.0 $ 472.9 $ 1,014.0 $ 271.5 $ 282.4 $ 441.5 Deferred Tax Liabilities (12,631.8) (1,401.4) (1,335.7) (2,484.8) (2,183.9) (1,424.2) (1,113.6) (1,620.8) Net Deferred Tax Liabilities $ (9,415.7) $ (1,227.8) $ (1,147.7) $ (2,011.9) $ (1,169.9) $ (1,152.7) $ (831.2) $ (1,179.3) Property Related Temporary Differences $ (8,809.0) $ (1,274.0) $ (1,304.2) $ (1,805.9) $ (315.6) $ (1,243.2) $ (941.9) $ (1,306.0) Amounts Due to Customers for Future Income Taxes 898.1 109.3 120.8 128.0 103.2 104.6 99.0 142.5 Securitized Assets (81.8) (46.7) — (32.6) — (5.3) — 2.8 Regulatory Assets (825.9) (56.2) (0.7) (284.3) (27.7) (50.1) (67.2) (146.9) Accrued Nuclear Decommissioning (923.5) — — — (923.5) — — — Net Operating Loss Carryforward 155.6 — 3.9 0.2 — 2.6 25.3 47.5 Valuation Allowance (37.4) — (0.1) — — — — (1.8) Tax Credit Carryforward 321.4 13.7 — 0.1 7.2 41.0 53.8 68.6 Operating Lease Liability 154.7 17.3 0.4 18.0 14.1 15.4 28.2 33.3 Investment in Partnership (296.3) — — (0.1) — (0.7) — (1.5) All Other, Net 28.4 8.8 32.2 (35.3) (27.6) (17.0) (28.4) (17.8) Net Deferred Tax Liabilities $ (9,415.7) $ (1,227.8) $ (1,147.7) $ (2,011.9) $ (1,169.9) $ (1,152.7) $ (831.2) $ (1,179.3) Federal and State Income Tax Audit Status AEP is not currently under IRS audit and the statute of limitations (“SOL”) for the IRS to examine AEP and subsidiaries originally filed federal return has expired for tax years prior to 2017. AEP agreed to extend the SOL on the 2017-2020 tax returns to May 31, 2025, to allow the Congressional Joint Committee on Taxation (“JCT”) adequate time to complete its review of the now closed IRS audit. Following JCT’s approval, AEP received IRS confirmation that tax years 2017-2020 are now effectively closed as they only remain open for changes to other non-consolidated entities that AEP holds an interest in. AEP and subsidiaries file income tax returns in various state and local jurisdictions. AEP and subsidiaries are not currently under any state and local income tax examinations. Generally, the SOL 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. Net Income Tax Operating Loss Carryforward As of December 31, 2024, AEP, OPCo, PSO, and SWEPCo have pretax state NOLC as indicated in the table below. Net of tax, the NOLCs for AEP and subsidiaries amount to $110.3 million of future tax benefit. Additionally, the amounts presented below for OPCo, PSO, and SWEPCo amount to $2.7 million, $27.8 million, and $36.1 million, respectively.: State Net Income Tax Operating Loss Years of Company State/Municipality Carryforward Expiration (in millions) AEP Arkansas $ 273.9 2031 - 2034 AEP Colorado 70.5 2041 AEP Illinois 53.9 2039 - 2041 AEP Kentucky 186.7 2030 - 2037 AEP Louisiana 644.8 NA AEP Michigan 30.9 2029 - 2032 AEP Ohio Municipal 2,155.8 2025 - 2029 AEP Oklahoma 889.8 2037 AEP Pennsylvania 61.2 2030 - 2044 AEP Tennessee 46.1 2032 - 2039 OPCo Ohio Municipal 93.7 2025 - 2029 PSO Oklahoma 1,010.0 2037 SWEPCo Arkansas 273.5 2031 - 2034 SWEPCo Louisiana 634.5 NA NA Not applicable. Tax Credit Carryforward Federal and state net income tax operating losses sustained in 2017, 2019 and 2021 resulted in unused federal and state income tax credits. As of December 31, 2024, the Registrants have federal tax credit carryforwards and AEP and PSO have state tax credit carryforwards as indicated in the table below. If these credits are not utilized, federal general business tax credits will expire in the years 2036 through 2041 and state tax credits will remain available indefinitely. Total Federal Total State Tax Credit Tax Credit Company Carryforward Carryforward (in millions) AEP $ 197.9 40.2 I&M 37.5 — PSO 26.5 40.2 SWEPCo 31.7 — The Registrants anticipate future federal taxable income will be sufficient to realize the tax benefits of the federal tax credits before they expire unused. Valuation Allowance AEP assesses the available positive and negative evidence to estimate whether sufficient future taxable income of the appropriate tax character will be generated to realize the benefits of existing deferred tax assets. When the evaluation of the evidence indicates that it is more-likely-than-not that AEP will not be able to realize the benefits of existing deferred tax assets, a valuation allowance is recorded to reduce existing deferred tax assets to the net realizable amount. Objective evidence evaluated includes whether AEP has a history of recognizing income, future reversals of existing temporary differences and tax planning strategies. Valuation allowance activity for the years ended December 31, 2024, 2023 and 2022 were not material. Uncertain Tax Positions The amount and activity of unrecognized tax benefits was not material for the Registrants for the years ended December 31, 2024, 2023 and 2022. Management believes that there will be no significant net increase or decrease in unrecognized benefits within 12 months of the reporting date. The total amount of unrecognized tax benefits that, if recognized, would affect the effective tax rate for AEP as of December 31, 2024, 2023 and 2022 were $19 million , $13 million, and $23 million, respectively.

LEASES

LEASES	12 Months Ended
	Dec. 31, 2024
Leases [Abstract]
LEASES	LEASES The disclosures in this note apply to all Registrants unless indicated otherwise. The Registrants lease property, plant and equipment including, but not limited to, fleet, information technology and real estate leases. These leases require payments of non-lease components, including related property taxes, operating and maintenance costs. AEP does not separate non-lease components from associated lease components. Many of these leases have purchase or renewal options. Leases not renewed are often replaced by other leases. Options to renew or purchase a lease are included in the measurement of lease assets and liabilities if it is reasonably certain the Registrant will exercise the option. Lease obligations are measured using the discount rate implicit in the lease when that rate is readily determinable. AEP has visibility into the rate implicit in the lease when assets are leased from selected financial institutions under master leasing agreements. When the implicit rate is not readily determinable, the Registrants measure their lease obligation using their estimated secured incremental borrowing rate. Incremental borrowing rates are comprised of an underlying risk-free rate and a secured credit spread relative to the lessee on a matched maturity basis. Operating lease rentals and finance lease amortization costs are generally charged to Other Operation and Maintenance expense in accordance with rate-making treatment for regulated operations. The amortization costs related to the Rockport finance lease, which ended in December 2022, were charged to Depreciation and Amortization. Interest on finance lease liabilities is generally charged to Interest Expense. Lease costs associated with capital projects are included in Property, Plant and Equipment on the balance sheets. For regulated operations with finance leases, a finance lease asset and offsetting liability are recorded at the present value of the remaining lease payments for each reporting period. Finance leases for nonregulated property are accounted for as if the assets were owned and financed. The components of rental costs were as follows: Year Ended December 31, 2024 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Cost $ 145.9 $ 32.3 $ 1.3 $ 18.4 $ 19.6 $ 16.8 $ 13.5 $ 17.8 Finance Lease Cost: Amortization of Right-of-Use Assets 63.7 7.5 — 8.7 7.2 5.3 3.3 13.0 Interest on Lease Liabilities 11.9 1.4 — 1.5 2.2 0.9 0.7 1.6 Total Lease Rental Costs (a) $ 221.5 $ 41.2 $ 1.3 $ 28.6 $ 29.0 $ 23.0 $ 17.5 $ 32.4 Year Ended December 31, 2023 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Cost $ 149.9 $ 34.0 $ 1.3 $ 18.5 $ 19.6 $ 17.3 $ 13.5 $ 17.5 Finance Lease Cost: Amortization of Right-of-Use Assets 69.1 7.4 — 8.3 7.3 5.0 3.3 19.9 Interest on Lease Liabilities 11.9 1.4 — 1.8 2.5 0.9 0.7 1.4 Total Lease Rental Costs (a) $ 230.9 $ 42.8 $ 1.3 $ 28.6 $ 29.4 $ 23.2 $ 17.5 $ 38.8 Year Ended December 31, 2022 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Cost $ 157.5 $ 18.4 $ 1.1 $ 17.9 $ 29.5 $ 16.9 $ 11.8 $ 15.3 Finance Lease Cost: Amortization of Right-of-Use Assets 205.5 6.8 — 7.9 78.7 4.9 3.2 10.8 Interest on Lease Liabilities 13.4 1.3 — 2.0 3.1 0.8 0.6 2.1 Total Lease Rental Costs (a) $ 376.4 $ 26.5 $ 1.1 $ 27.8 $ 111.3 $ 22.6 $ 15.6 $ 28.2 (a) Excludes variable and short-term lease costs, which were immaterial. Supplemental information related to leases are shown in the tables below: December 31, 2024 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo Weighted-Average Remaining Lease Term (years): Operating Leases 12.80 4.45 2.29 5.39 4.43 4.64 23.68 21.97 Finance Leases 4.81 5.04 0.00 4.09 4.83 4.58 5.44 6.14 Weighted-Average Discount Rate: Operating Leases 3.89 % 4.29 % 4.55 % 4.20 % 4.11 % 4.17 % 3.76 % 3.60 % Finance Leases 6.43 % 5.73 % — % 6.69 % 9.07 % 5.59 % 5.48 % 5.73 % December 31, 2023 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo Weighted-Average Remaining Lease Term (years): Operating Leases 12.58 3.99 2.76 6.01 4.53 5.36 23.85 22.50 Finance Leases 4.63 5.13 0.00 4.16 4.95 4.97 5.76 4.78 Weighted-Average Discount Rate: Operating Leases 3.73 % 4.23 % 3.61 % 3.50 % 3.89 % 3.93 % 3.72 % 3.53 % Finance Leases 6.19 % 5.27 % — % 7.04 % 8.62 % 5.32 % 5.14 % 5.22 % Year Ended December 31, 2024 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Cash paid for amounts included in the measurement of lease liabilities: Operating Cash Flows Used for Operating Leases $ 143.9 $ 32.2 $ 1.3 $ 18.4 $ 19.6 $ 16.8 $ 12.5 $ 16.8 Operating Cash Flows Used for Finance Leases 12.0 1.4 — 1.5 2.2 0.9 0.7 1.7 Financing Cash Flows Used for Finance Leases 64.8 7.5 — 8.7 7.1 5.3 3.3 14.0 Non-cash Acquisitions Under Operating Leases $ 82.3 $ 6.0 $ 1.0 $ 9.3 $ 15.0 $ 4.6 $ 2.5 $ 26.9 Year Ended December 31, 2023 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Cash paid for amounts included in the measurement of lease liabilities: Operating Cash Flows Used for Operating Leases $ 146.8 $ 33.6 $ 1.3 $ 18.3 $ 19.5 $ 17.0 $ 12.5 $ 16.5 Operating Cash Flows Used for Finance Leases 11.9 1.4 — 1.8 2.5 0.9 0.7 1.4 Financing Cash Flows Used for Finance Leases 68.3 7.4 — 8.3 7.4 5.0 3.3 19.1 Non-cash Acquisitions Under Operating Leases $ 99.8 $ 12.4 $ 1.2 $ 15.7 $ 7.9 $ 10.2 $ 15.5 $ 14.3 The following tables show property, plant and equipment under finance leases and noncurrent assets under operating leases and related obligations recorded on the balance sheets. Unless shown as a separate line on the balance sheets due to materiality, net operating lease assets are included in Deferred Charges and Other Noncurrent Assets, current finance lease obligations are included in Other Current Liabilities Deferred Credits and Other Noncurrent Liabilities balance sheets December 31, 2024 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Property, Plant and Equipment Under Finance Leases: Generation $ 73.8 $ — $ — $ 41.6 $ 16.6 $ — $ 0.6 $ 2.0 Other Property, Plant and Equipment 283.7 52.4 — 19.4 38.8 30.4 23.0 29.8 Total Property, Plant and Equipment 357.5 52.4 — 61.0 55.4 30.4 23.6 31.8 Accumulated Amortization 193.9 27.7 — 42.0 33.4 16.1 11.3 13.3 Net Property, Plant and Equipment Under Finance Leases $ 163.6 $ 24.7 $ — $ 19.0 $ 22.0 $ 14.3 $ 12.3 $ 18.5 Obligations Under Finance Leases: Noncurrent Liability $ 117.1 $ 18.2 $ — $ 11.2 $ 15.9 $ 10.2 $ 9.5 $ 14.8 Liability Due Within One Year 46.5 6.5 — 7.8 6.1 4.1 2.8 3.7 Total Obligations Under Finance Leases $ 163.6 $ 24.7 $ — $ 19.0 $ 22.0 $ 14.3 $ 12.3 $ 18.5 December 31, 2023 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Property, Plant and Equipment Under Finance Leases: Generation $ 120.1 $ — $ — $ 41.0 $ 28.2 $ — $ 0.6 $ 25.3 Other Property, Plant and Equipment 305.9 53.9 — 22.1 42.3 33.7 25.5 32.0 Total Property, Plant and Equipment 426.0 53.9 — 63.1 70.5 33.7 26.1 57.3 Accumulated Amortization 221.5 26.3 — 37.1 39.0 15.5 12.3 28.3 Net Property, Plant and Equipment Under Finance Leases $ 204.5 $ 27.6 $ — $ 26.0 $ 31.5 $ 18.2 $ 13.8 $ 29.0 Obligations Under Finance Leases: Noncurrent Liability $ 139.9 $ 20.6 $ — $ 17.8 $ 20.8 $ 13.2 $ 10.7 $ 18.8 Liability Due Within One Year 65.7 7.0 — 8.2 10.7 5.0 3.1 11.3 Total Obligations Under Finance Leases $ 205.6 $ 27.6 $ — $ 26.0 $ 31.5 $ 18.2 $ 13.8 $ 30.1 December 31, 2024 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Assets $ 580.1 $ 54.4 $ 2.3 $ 67.0 $ 51.5 $ 60.4 $ 106.2 $ 141.0 Obligations Under Operating Leases: Noncurrent Liability $ 504.3 $ 43.4 $ 1.2 $ 54.0 $ 40.1 $ 48.4 $ 101.9 $ 137.5 Liability Due Within One Year 91.9 13.1 1.3 13.7 12.3 12.3 10.4 8.2 Total Obligations Under Operating Leases $ 596.2 $ 56.5 $ 2.5 $ 67.7 $ 52.4 $ 60.7 $ 112.3 $ 145.7 December 31, 2023 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Assets $ 620.2 $ 77.6 $ 2.6 $ 73.7 $ 53.8 $ 69.9 $ 112.8 $ 126.3 Obligations Under Operating Leases: Noncurrent Liability $ 519.4 $ 50.9 $ 1.4 $ 59.8 $ 37.7 $ 56.7 $ 106.8 $ 122.5 Liability Due Within One Year 115.7 28.7 1.3 14.6 16.8 13.5 10.1 9.0 Total Obligations Under Operating Leases $ 635.1 $ 79.6 $ 2.7 $ 74.4 $ 54.5 $ 70.2 $ 116.9 $ 131.5 Future minimum lease payments consisted of the following as of December 31, 2024: Finance Leases AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) 2025 $ 55.6 $ 7.8 $ — $ 8.9 $ 7.7 $ 4.8 $ 3.4 $ 4.7 2026 39.8 6.2 — 4.0 4.9 3.6 2.9 4.0 2027 30.5 4.5 — 2.5 4.1 2.6 2.3 3.3 2028 23.1 3.1 — 2.0 3.4 2.0 1.8 2.7 2029 15.5 2.4 — 1.6 2.8 1.4 1.3 2.4 After 2029 26.4 4.7 — 2.5 4.7 1.9 2.6 5.0 Total Future Minimum Lease Payments 190.9 28.7 — 21.5 27.6 16.3 14.3 22.1 Less: Imputed Interest 27.3 4.0 — 2.5 5.6 2.0 2.0 3.6 Estimated Present Value of Future Minimum Lease Payments $ 163.6 $ 24.7 $ — $ 19.0 $ 22.0 $ 14.3 $ 12.3 $ 18.5 Operating Leases AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) 2025 $ 123.0 $ 16.7 $ 1.3 $ 17.3 $ 15.9 $ 16.3 $ 11.6 $ 17.6 2026 107.8 14.5 0.7 15.3 15.0 15.1 10.8 15.5 2027 94.0 11.9 0.3 13.6 11.0 13.5 9.8 14.1 2028 78.5 8.9 0.3 11.4 9.0 11.3 8.4 12.1 2029 52.3 4.9 — 8.2 4.4 6.6 6.5 9.0 After 2029 340.0 6.5 — 10.2 2.4 4.9 123.7 178.1 Total Future Minimum Lease Payments 795.6 63.4 2.6 76.0 57.7 67.7 170.8 246.4 Less: Imputed Interest 199.4 6.9 0.1 8.3 5.3 7.0 58.5 100.7 Estimated Present Value of Future Minimum Lease Payments $ 596.2 $ 56.5 $ 2.5 $ 67.7 $ 52.4 $ 60.7 $ 112.3 $ 145.7 Master Lease Agreements (Applies to all Registrants except AEPTCo) The Registrants lease certain equipment under master lease agreements. Under the lease agreements, the lessor is guaranteed a residual value up to a stated percentage of the equipment cost at the end of the lease term. If the actual fair value of the leased equipment is below the guaranteed residual value at the end of the lease term, the Registrants are committed to pay the difference between the actual fair value and the residual value guarantee. Historically, at the end of the lease term the fair value has been in excess of the amount guaranteed. As of December 31, 2024, the maximum potential loss by the Registrants for these lease agreements assuming the fair value of the equipment is zero at the end of the lease term was as follows: Company Maximum (in millions) AEP $ 41.3 AEP Texas 9.4 APCo 5.4 I&M 3.9 OPCo 6.8 PSO 3.9 SWEPCo 4.7 Lessor Activity The Registrants’ lessor activity was immaterial as of and for the years ended December 31, 2024 and December 31, 2023, respectively.
LEASES	LEASES The disclosures in this note apply to all Registrants unless indicated otherwise. The Registrants lease property, plant and equipment including, but not limited to, fleet, information technology and real estate leases. These leases require payments of non-lease components, including related property taxes, operating and maintenance costs. AEP does not separate non-lease components from associated lease components. Many of these leases have purchase or renewal options. Leases not renewed are often replaced by other leases. Options to renew or purchase a lease are included in the measurement of lease assets and liabilities if it is reasonably certain the Registrant will exercise the option. Lease obligations are measured using the discount rate implicit in the lease when that rate is readily determinable. AEP has visibility into the rate implicit in the lease when assets are leased from selected financial institutions under master leasing agreements. When the implicit rate is not readily determinable, the Registrants measure their lease obligation using their estimated secured incremental borrowing rate. Incremental borrowing rates are comprised of an underlying risk-free rate and a secured credit spread relative to the lessee on a matched maturity basis. Operating lease rentals and finance lease amortization costs are generally charged to Other Operation and Maintenance expense in accordance with rate-making treatment for regulated operations. The amortization costs related to the Rockport finance lease, which ended in December 2022, were charged to Depreciation and Amortization. Interest on finance lease liabilities is generally charged to Interest Expense. Lease costs associated with capital projects are included in Property, Plant and Equipment on the balance sheets. For regulated operations with finance leases, a finance lease asset and offsetting liability are recorded at the present value of the remaining lease payments for each reporting period. Finance leases for nonregulated property are accounted for as if the assets were owned and financed. The components of rental costs were as follows: Year Ended December 31, 2024 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Cost $ 145.9 $ 32.3 $ 1.3 $ 18.4 $ 19.6 $ 16.8 $ 13.5 $ 17.8 Finance Lease Cost: Amortization of Right-of-Use Assets 63.7 7.5 — 8.7 7.2 5.3 3.3 13.0 Interest on Lease Liabilities 11.9 1.4 — 1.5 2.2 0.9 0.7 1.6 Total Lease Rental Costs (a) $ 221.5 $ 41.2 $ 1.3 $ 28.6 $ 29.0 $ 23.0 $ 17.5 $ 32.4 Year Ended December 31, 2023 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Cost $ 149.9 $ 34.0 $ 1.3 $ 18.5 $ 19.6 $ 17.3 $ 13.5 $ 17.5 Finance Lease Cost: Amortization of Right-of-Use Assets 69.1 7.4 — 8.3 7.3 5.0 3.3 19.9 Interest on Lease Liabilities 11.9 1.4 — 1.8 2.5 0.9 0.7 1.4 Total Lease Rental Costs (a) $ 230.9 $ 42.8 $ 1.3 $ 28.6 $ 29.4 $ 23.2 $ 17.5 $ 38.8 Year Ended December 31, 2022 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Cost $ 157.5 $ 18.4 $ 1.1 $ 17.9 $ 29.5 $ 16.9 $ 11.8 $ 15.3 Finance Lease Cost: Amortization of Right-of-Use Assets 205.5 6.8 — 7.9 78.7 4.9 3.2 10.8 Interest on Lease Liabilities 13.4 1.3 — 2.0 3.1 0.8 0.6 2.1 Total Lease Rental Costs (a) $ 376.4 $ 26.5 $ 1.1 $ 27.8 $ 111.3 $ 22.6 $ 15.6 $ 28.2 (a) Excludes variable and short-term lease costs, which were immaterial. Supplemental information related to leases are shown in the tables below: December 31, 2024 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo Weighted-Average Remaining Lease Term (years): Operating Leases 12.80 4.45 2.29 5.39 4.43 4.64 23.68 21.97 Finance Leases 4.81 5.04 0.00 4.09 4.83 4.58 5.44 6.14 Weighted-Average Discount Rate: Operating Leases 3.89 % 4.29 % 4.55 % 4.20 % 4.11 % 4.17 % 3.76 % 3.60 % Finance Leases 6.43 % 5.73 % — % 6.69 % 9.07 % 5.59 % 5.48 % 5.73 % December 31, 2023 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo Weighted-Average Remaining Lease Term (years): Operating Leases 12.58 3.99 2.76 6.01 4.53 5.36 23.85 22.50 Finance Leases 4.63 5.13 0.00 4.16 4.95 4.97 5.76 4.78 Weighted-Average Discount Rate: Operating Leases 3.73 % 4.23 % 3.61 % 3.50 % 3.89 % 3.93 % 3.72 % 3.53 % Finance Leases 6.19 % 5.27 % — % 7.04 % 8.62 % 5.32 % 5.14 % 5.22 % Year Ended December 31, 2024 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Cash paid for amounts included in the measurement of lease liabilities: Operating Cash Flows Used for Operating Leases $ 143.9 $ 32.2 $ 1.3 $ 18.4 $ 19.6 $ 16.8 $ 12.5 $ 16.8 Operating Cash Flows Used for Finance Leases 12.0 1.4 — 1.5 2.2 0.9 0.7 1.7 Financing Cash Flows Used for Finance Leases 64.8 7.5 — 8.7 7.1 5.3 3.3 14.0 Non-cash Acquisitions Under Operating Leases $ 82.3 $ 6.0 $ 1.0 $ 9.3 $ 15.0 $ 4.6 $ 2.5 $ 26.9 Year Ended December 31, 2023 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Cash paid for amounts included in the measurement of lease liabilities: Operating Cash Flows Used for Operating Leases $ 146.8 $ 33.6 $ 1.3 $ 18.3 $ 19.5 $ 17.0 $ 12.5 $ 16.5 Operating Cash Flows Used for Finance Leases 11.9 1.4 — 1.8 2.5 0.9 0.7 1.4 Financing Cash Flows Used for Finance Leases 68.3 7.4 — 8.3 7.4 5.0 3.3 19.1 Non-cash Acquisitions Under Operating Leases $ 99.8 $ 12.4 $ 1.2 $ 15.7 $ 7.9 $ 10.2 $ 15.5 $ 14.3 The following tables show property, plant and equipment under finance leases and noncurrent assets under operating leases and related obligations recorded on the balance sheets. Unless shown as a separate line on the balance sheets due to materiality, net operating lease assets are included in Deferred Charges and Other Noncurrent Assets, current finance lease obligations are included in Other Current Liabilities Deferred Credits and Other Noncurrent Liabilities balance sheets December 31, 2024 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Property, Plant and Equipment Under Finance Leases: Generation $ 73.8 $ — $ — $ 41.6 $ 16.6 $ — $ 0.6 $ 2.0 Other Property, Plant and Equipment 283.7 52.4 — 19.4 38.8 30.4 23.0 29.8 Total Property, Plant and Equipment 357.5 52.4 — 61.0 55.4 30.4 23.6 31.8 Accumulated Amortization 193.9 27.7 — 42.0 33.4 16.1 11.3 13.3 Net Property, Plant and Equipment Under Finance Leases $ 163.6 $ 24.7 $ — $ 19.0 $ 22.0 $ 14.3 $ 12.3 $ 18.5 Obligations Under Finance Leases: Noncurrent Liability $ 117.1 $ 18.2 $ — $ 11.2 $ 15.9 $ 10.2 $ 9.5 $ 14.8 Liability Due Within One Year 46.5 6.5 — 7.8 6.1 4.1 2.8 3.7 Total Obligations Under Finance Leases $ 163.6 $ 24.7 $ — $ 19.0 $ 22.0 $ 14.3 $ 12.3 $ 18.5 December 31, 2023 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Property, Plant and Equipment Under Finance Leases: Generation $ 120.1 $ — $ — $ 41.0 $ 28.2 $ — $ 0.6 $ 25.3 Other Property, Plant and Equipment 305.9 53.9 — 22.1 42.3 33.7 25.5 32.0 Total Property, Plant and Equipment 426.0 53.9 — 63.1 70.5 33.7 26.1 57.3 Accumulated Amortization 221.5 26.3 — 37.1 39.0 15.5 12.3 28.3 Net Property, Plant and Equipment Under Finance Leases $ 204.5 $ 27.6 $ — $ 26.0 $ 31.5 $ 18.2 $ 13.8 $ 29.0 Obligations Under Finance Leases: Noncurrent Liability $ 139.9 $ 20.6 $ — $ 17.8 $ 20.8 $ 13.2 $ 10.7 $ 18.8 Liability Due Within One Year 65.7 7.0 — 8.2 10.7 5.0 3.1 11.3 Total Obligations Under Finance Leases $ 205.6 $ 27.6 $ — $ 26.0 $ 31.5 $ 18.2 $ 13.8 $ 30.1 December 31, 2024 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Assets $ 580.1 $ 54.4 $ 2.3 $ 67.0 $ 51.5 $ 60.4 $ 106.2 $ 141.0 Obligations Under Operating Leases: Noncurrent Liability $ 504.3 $ 43.4 $ 1.2 $ 54.0 $ 40.1 $ 48.4 $ 101.9 $ 137.5 Liability Due Within One Year 91.9 13.1 1.3 13.7 12.3 12.3 10.4 8.2 Total Obligations Under Operating Leases $ 596.2 $ 56.5 $ 2.5 $ 67.7 $ 52.4 $ 60.7 $ 112.3 $ 145.7 December 31, 2023 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Assets $ 620.2 $ 77.6 $ 2.6 $ 73.7 $ 53.8 $ 69.9 $ 112.8 $ 126.3 Obligations Under Operating Leases: Noncurrent Liability $ 519.4 $ 50.9 $ 1.4 $ 59.8 $ 37.7 $ 56.7 $ 106.8 $ 122.5 Liability Due Within One Year 115.7 28.7 1.3 14.6 16.8 13.5 10.1 9.0 Total Obligations Under Operating Leases $ 635.1 $ 79.6 $ 2.7 $ 74.4 $ 54.5 $ 70.2 $ 116.9 $ 131.5 Future minimum lease payments consisted of the following as of December 31, 2024: Finance Leases AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) 2025 $ 55.6 $ 7.8 $ — $ 8.9 $ 7.7 $ 4.8 $ 3.4 $ 4.7 2026 39.8 6.2 — 4.0 4.9 3.6 2.9 4.0 2027 30.5 4.5 — 2.5 4.1 2.6 2.3 3.3 2028 23.1 3.1 — 2.0 3.4 2.0 1.8 2.7 2029 15.5 2.4 — 1.6 2.8 1.4 1.3 2.4 After 2029 26.4 4.7 — 2.5 4.7 1.9 2.6 5.0 Total Future Minimum Lease Payments 190.9 28.7 — 21.5 27.6 16.3 14.3 22.1 Less: Imputed Interest 27.3 4.0 — 2.5 5.6 2.0 2.0 3.6 Estimated Present Value of Future Minimum Lease Payments $ 163.6 $ 24.7 $ — $ 19.0 $ 22.0 $ 14.3 $ 12.3 $ 18.5 Operating Leases AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) 2025 $ 123.0 $ 16.7 $ 1.3 $ 17.3 $ 15.9 $ 16.3 $ 11.6 $ 17.6 2026 107.8 14.5 0.7 15.3 15.0 15.1 10.8 15.5 2027 94.0 11.9 0.3 13.6 11.0 13.5 9.8 14.1 2028 78.5 8.9 0.3 11.4 9.0 11.3 8.4 12.1 2029 52.3 4.9 — 8.2 4.4 6.6 6.5 9.0 After 2029 340.0 6.5 — 10.2 2.4 4.9 123.7 178.1 Total Future Minimum Lease Payments 795.6 63.4 2.6 76.0 57.7 67.7 170.8 246.4 Less: Imputed Interest 199.4 6.9 0.1 8.3 5.3 7.0 58.5 100.7 Estimated Present Value of Future Minimum Lease Payments $ 596.2 $ 56.5 $ 2.5 $ 67.7 $ 52.4 $ 60.7 $ 112.3 $ 145.7 Master Lease Agreements (Applies to all Registrants except AEPTCo) The Registrants lease certain equipment under master lease agreements. Under the lease agreements, the lessor is guaranteed a residual value up to a stated percentage of the equipment cost at the end of the lease term. If the actual fair value of the leased equipment is below the guaranteed residual value at the end of the lease term, the Registrants are committed to pay the difference between the actual fair value and the residual value guarantee. Historically, at the end of the lease term the fair value has been in excess of the amount guaranteed. As of December 31, 2024, the maximum potential loss by the Registrants for these lease agreements assuming the fair value of the equipment is zero at the end of the lease term was as follows: Company Maximum (in millions) AEP $ 41.3 AEP Texas 9.4 APCo 5.4 I&M 3.9 OPCo 6.8 PSO 3.9 SWEPCo 4.7 Lessor Activity The Registrants’ lessor activity was immaterial as of and for the years ended December 31, 2024 and December 31, 2023, respectively.

VOLUNTARY SEVERANCE PROGRAM

VOLUNTARY SEVERANCE PROGRAM	12 Months Ended
	Dec. 31, 2024
Restructuring and Related Activities [Abstract]
VOLUNTARY SEVERANCE PROGRAM	VOLUNTARY SEVERANCE PROGRAM In April 2024, management announced a voluntary severance program designed to achieve a reduction in the size of AEP’s workforce. Approximately 7,400 of AEP’s 16,800 employees were eligible to participate in the program. Approximately 1,000 employees chose to take the voluntary severance package and substantially all terminated employment in July 2024. The severance program provides two weeks of base pay for every year of service with a minimum of four weeks and a maximum of 52 weeks of base pay. Certain positions impacted by the voluntary severance program have been and will continue to be refilled to maintain safe, effective and efficient operations. Net savings from the program will help offset increasing operating expenses and high interest costs in order to keep electricity costs affordable for customers. AEP recorded a charge to expense in the second quarter of 2024 related to this voluntary severance program. AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Severance Expense Incurred $ 122.0 $ 19.8 $ 10.7 $ 26.5 $ 14.8 $ 14.8 $ 10.1 $ 16.9 Settled 117.6 19.8 10.7 26.3 14.6 14.6 10.1 16.3 Remaining Balance as of December 31, 2024 $ 4.4 $ — $ — $ 0.2 $ 0.2 $ 0.2 $ — $ 0.6 These expenses were primarily included in Other Operation and Maintenance on the statements of income and Other Current Liabilities on the balance sheets. Settlement accounting was triggered for the qualified pension plan in November 2024 under the accounting guidance for “Compensation - Retirement Benefits”. A settlement charge of $90 million was recorded. AEP will seek recovery for the portion of the expense related to regulated operations. See Note 8 - Benefit Plans for additional information associated with the plan.

FINANCING ACTIVITIES

FINANCING ACTIVITIES	12 Months Ended
	Dec. 31, 2024
Debt Disclosure [Abstract]
FINANCING ACTIVITIES	FINANCING ACTIVITIES The disclosures in this note apply to all Registrants, unless indicated otherwise. Common Stock (Applies to AEP) The following table is a reconciliation of common stock share activity: Shares of AEP Common Stock Issued Held in Treasury Balance, December 31, 2021 524,416,175 20,204,160 Issued 683,146 — Treasury Stock Reissued — (8,970,920) (a) Balance, December 31, 2022 525,099,321 11,233,240 Issued 2,269,836 — Treasury Stock Reissued — (10,048,668) (a) Balance, December 31, 2023 527,369,157 1,184,572 Issued 6,725,373 — Treasury Stock Reacquired — 2,243 Balance, December 31, 2024 534,094,530 1,186,815 (a) Reissued Treasury Stock used to fulfill share commitments related to AEP’s Equity Units. ATM Program In 2023, AEP filed a prospectus supplement and executed an Equity Distribution Agreement, pursuant to which AEP may sell, from time to time, up to an aggregate of $1.7 billion of its common stock through an ATM offering program, including an equity forward sales component. The compensation paid to the selling agents by AEP may be up to 2% of the gross offering proceeds of the shares. For the year ended 2024, AEP issued 4,437,136 shares of common stock and received net cash proceeds of $397 million under the ATM program. As of December 31, 2024, approximately $1.3 billion of equity is available for issuance under the ATM program. Long-term Debt The following table details long-term debt outstanding: Weighted-Average Interest Rate Ranges as of Outstanding as of Interest Rate as of December 31, December 31, Company Maturity December 31, 2024 2024 2023 2024 2023 AEP (in millions) Senior Unsecured Notes 2025-2054 4.32% 1.00%-8.13% 1.00%-8.13% $ 36,410.9 $ 33,779.4 Pollution Control Bonds (a) 2025-2036 (b) 3.26% 0.63%-4.70% 0.63%-4.90% 1,771.3 1,771.6 Notes Payable – Nonaffiliated (c) 2025-2034 6.49% 0.93%-6.89% 0.93%-6.59% 609.9 193.3 Securitization Bonds 2025-2039 (d) 4.08% 2.06%-4.88% 2.06%-3.77% 578.0 368.9 Spent Nuclear Fuel Obligation (e) 316.3 300.4 Junior Subordinated Notes 2025-2054 5.67% 3.88%-7.05% 2.03%-5.70% 2,579.1 2,388.1 Other Long-term Debt 2025-2059 5.60% 3.00%-13.72% 3.00%-13.72% 377.3 1,341.5 Total Long-term Debt Outstanding $ 42,642.8 $ 40,143.2 AEP Texas Senior Unsecured Notes 2025-2052 4.39% 2.10%-6.76% 2.10%-6.76% $ 5,873.8 $ 5,027.2 Pollution Control Bonds (a) 2029-2030 (b) 3.88% 2.60%-4.55% 2.60%-4.55% 440.3 440.3 Securitization Bonds 2025-2029 (d) 2.27% 2.06%-2.29% 2.06%-2.84% 126.8 221.8 Other Long-term Debt 2059 4.50% 4.50% 4.50%-6.71% 0.7 200.5 Total Long-term Debt Outstanding $ 6,441.6 $ 5,889.8 AEPTCo Senior Unsecured Notes 2025-2053 4.12% 2.75%-5.52% 2.75%-5.52% $ 5,768.1 $ 5,414.4 Total Long-term Debt Outstanding $ 5,768.1 $ 5,414.4 APCo Senior Unsecured Notes 2025-2050 4.75% 2.70%-7.00% 2.70%-7.00% $ 4,984.1 $ 4,584.9 Pollution Control Bonds (a) 2025-2036 (b) 2.95% 0.63%-4.22% 0.63%-4.90% 429.9 430.0 Securitization Bonds 2028 (d) 3.77% 3.77% 3.77% 119.8 147.0 Other Long-term Debt 2025-2026 5.84% 5.75%-13.72% 6.46%-13.72% 126.5 426.4 Total Long-term Debt Outstanding $ 5,660.3 $ 5,588.3 I&M Senior Unsecured Notes 2028-2053 4.52% 3.25%-6.05% 3.25%-6.05% $ 2,845.2 $ 2,843.6 Pollution Control Bonds (a) 2025 (b) 2.49% 0.75%-3.05% 0.75%-3.05% 189.9 189.4 Notes Payable – Nonaffiliated (c) 2025-2028 5.78% 0.93%-6.41% 0.93%-6.59% 142.7 163.3 Spent Nuclear Fuel Obligation (e) 316.3 300.4 Other Long-term Debt 2025 6.00% 6.00% 6.00% 0.2 2.7 Total Long-term Debt Outstanding $ 3,494.3 $ 3,499.4 OPCo Senior Unsecured Notes 2030-2051 4.16% 1.63%-6.60% 1.63%-6.60% $ 3,715.7 $ 3,366.8 Total Long-term Debt Outstanding $ 3,715.7 $ 3,366.8 PSO Senior Unsecured Notes 2025-2051 4.29% 2.20%-6.63% 2.20%-6.63% $ 2,854.2 $ 2,257.8 Other Long-term Debt 2027 3.00% 3.00% 3.00%-6.71% 1.4 126.8 Total Long-term Debt Outstanding $ 2,855.6 $ 2,384.6 SWEPCo Senior Unsecured Notes 2026-2051 3.73% 1.65%-6.20% 1.65%-6.20% $ 3,649.4 $ 3,646.9 Securitization Bonds 2039 (d) 4.88% 4.88% —% 331.4 — Total Long-term Debt Outstanding $ 3,980.8 $ 3,646.9 (a) For certain series of Pollution Control Bonds, interest rates are subject to periodic adjustment. Certain series may be purchased on demand at periodic interest adjustment dates. Letters of credit from banks and insurance policies support certain series. Consequently, these bonds have been classified for maturity purposes as Long-term Debt Due Within One Year - Nonaffiliated on the balance sheets. (b) Certain Pollution Control Bonds are subject to redemption earlier than the maturity date. (c) Notes payable represent outstanding promissory notes issued under term loan agreements and credit agreements with a number of banks and other financial institutions. At expiration, all notes then issued and outstanding are due and payable. Interest rates are both fixed and variable. Variable rates generally relate to specified short-term interest rates. (d) Dates represent the scheduled final payment dates for the securitization bonds. The legal maturity date is one to two years later. These bonds have been classified for maturity and repayment purposes based on the scheduled final payment date. (e) Spent Nuclear Fuel Obligation consists of a liability along with accrued interest for disposal of SNF. See “Spent Nuclear Fuel Disposal” section of Note 6 for additional information. As of December 31, 2024, outstanding long-term debt was payable as follows: AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) 2025 $ 3,335.0 $ 324.5 $ 90.0 $ 798.6 $ 269.2 $ — $ 125.6 $ 22.7 2026 1,864.4 75.0 425.0 30.9 43.6 — 50.6 916.6 2027 2,283.6 25.6 — 355.6 13.7 — 0.3 17.4 2028 2,592.0 526.2 60.0 117.8 356.5 — — 593.3 2029 2,694.0 627.4 55.0 — — — 100.0 19.2 After 2029 30,212.8 4,912.8 5,201.0 4,400.0 2,841.3 3,750.0 2,600.0 2,442.4 Principal Amount 42,981.8 6,491.5 5,831.0 5,702.9 3,524.3 3,750.0 2,876.5 4,011.6 Unamortized Discount, Net and Debt Issuance Costs (339.0) (49.9) (62.9) (42.6) (30.0) (34.3) (20.9) (30.8) Total Long-term Debt Outstanding $ 42,642.8 $ 6,441.6 $ 5,768.1 $ 5,660.3 $ 3,494.3 $ 3,715.7 $ 2,855.6 $ 3,980.8 Long-term Debt Subsequent Events In January and February 2025, I&M retired $9 million and $4 million, respectively, of Notes Payable related to DCC Fuel. In January 2025, Transource Energy issued $2 million of variable rate Other Long-term Debt due in 2025. In January 2025, KPCo entered into a $150 million term loan due in February 2026. In February 2025, APCo retired $14 million of Securitization Bonds. In February 2025, AEP Texas retired $12 million of Securitization Bonds. Financing Plan (Applies to AEP and AEP Texas) As of December 31, 2024, the balance sheet of AEP Texas reflects negative working capital primarily driven by Long-term Debt Due within One Year - Nonaffiliated, Advances from Affiliates and Accounts Payable. In the near term, AEP Texas plans to issue long- term debt to provide additional liquidity and also intends to refinance the Long-term Debt due in 2025 on a long-term basis. While AEP Texas has historically been able to access the capital markets and refinance debt as it comes due, there is no guarantee this will occur. Accordingly, Parent, having available liquidity, has committed to provide sufficient liquidity to AEP Texas, as necessary, to continue operations and meet obligations as they become due until AEP Texas is able to execute its upcoming financing plan. Therefore, management does not believe there is a substantial doubt about AEP Texas’ ability to continue as a going-concern and the AEP Texas financial statements have been prepared on a going-concern basis, which contemplates the realization of assets and the satisfaction of obligations in the normal course of business. Debt Covenants (Applies to AEP and AEPTCo) Covenants in AEPTCo’s note purchase agreements and indenture limit the amount of contractually-defined priority debt (which includes a further sub-limit of $50 million of secured debt) to 10% of consolidated tangible net assets. AEPTCo’s contractually-defined priority debt was 0.6% of consolidated tangible net assets as of December 31, 2024. The method for calculating the consolidated tangible net assets is contractually-defined in the note purchase agreements. Dividend Restrictions Subsidiary Restrictions Parent depends on its subsidiaries to pay dividends to shareholders. AEP’s 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 most restrictive dividend limitation for certain AEP subsidiaries is through the Federal Power Act restriction, while for other AEP subsidiaries the most restrictive dividend limitation is through the credit agreements. As of December 31, 2024, the maximum amount of restricted net assets of AEP’s subsidiaries that may not be distributed to the Parent in the form of a loan, advance or dividend was $17.4 billion. The Federal Power Act restriction limits the ability of the AEP subsidiaries owning hydroelectric generation to pay dividends out of retained earnings. Additionally, the credit agreement covenant restrictions can limit the ability of the AEP subsidiaries to pay dividends out of retained earnings. As of December 31, 2024, the amount of any such restrictions were as follows: AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Restricted Retained Earnings $ 3,247.9 (a) $ 1,109.2 $ — $ 539.2 $ 707.0 $ — $ 267.7 $ 366.5 (a) Includes the restrictions of consolidated and non-consolidated subsidiaries. Parent Restrictions (Applies to AEP) The holders of AEP’s common stock are entitled to receive the dividends declared by the Board of Directors provided funds are legally available for such dividends. Parent’s income primarily derives from common stock equity in the earnings of its utility subsidiaries. Pursuant to the leverage restrictions in credit agreements, AEP must maintain a percentage of debt-to-total capitalization at a level that does not exceed 67.5%. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. AEP may not declare or pay any cash dividend or distribution on its common stock during any period when AEP defers interest on its junior subordinated notes. As of December 31, 2024, AEP had $8.6 billion of available retained earnings to pay dividends to common shareholders. AEP paid $1.9 billion, $1.8 billion and $1.6 billion of dividends to common shareholders for the years ended December 31, 2024, 2023 and 2022, respectively. Lines of Credit and Short-term Debt (Applies to AEP and SWEPCo) AEP uses its commercial paper program to meet the short-term borrowing needs of its subsidiaries. The program funds a Utility Money Pool, which funds AEP’s utility subsidiaries; a Nonutility Money Pool, which funds certain AEP nonutility subsidiaries; and the short-term debt requirements of subsidiaries that are not participating in either money pool for regulatory or operational reasons, as direct borrowers. As of December 31, 2024, AEP had $6 billion in revolving credit facilities to support its commercial paper program. Securitized Debt for Receivables, for the year ended 2024, had a weighted-average interest rate of 5.39% and a maximum amount outstanding of $900 million. The commercial paper program, for the year ended 2024, had a weighted-average yield of 5.39% and a maximum amount outstanding of $2.9 billion. AEP’s outstanding short-term debt was as follows: December 31, 2024 2023 Company Type of Debt Outstanding Interest Outstanding Interest (in millions) (in millions) AEP Securitized Debt for Receivables (b) $ 900.0 4.73 % $ 888.0 5.65 % AEP Commercial Paper 1,618.3 4.70 % 1,937.9 5.69 % SWEPCo Notes Payable 5.5 6.69 % 4.3 7.71 % Total Short-term Debt $ 2,523.8 $ 2,830.2 (a) Weighted-average rate of all borrowings outstanding as of December 31, 2024 and 2023, respectively. (b) Amount of securitized debt for receivables as accounted for under the “Transfers and Servicing” accounting guidance . Corporate Borrowing Program (Applies to Registrant Subsidiaries) AEP subsidiaries use a corporate borrowing program to meet their short-term borrowing needs. The corporate borrowing program includes a Utility Money Pool, which funds AEP’s utility subsidiaries; a Nonutility Money Pool, which funds certain AEP nonutility subsidiaries; and direct borrowing from AEP. The AEP Utility Money Pool operates in accordance with the terms and conditions of its agreement filed with the FERC. The amounts of outstanding loans to (borrowings from) the Utility Money Pool as of December 31, 2024 and 2023 are included in Advances to Affiliates and Advances from Affiliates, respectively, on the Registrant Subsidiaries’ balance sheets. The Utility Money Pool participants’ money pool activity and corresponding authorized borrowing limits are described in the following tables: Year Ended December 31, 2024: Maximum Average Net Loans to Borrowings Maximum Borrowings Average (Borrowings from) Authorized from the Loans to the from the Loans to the the Utility Money Short-term Utility Utility Utility Utility Pool as of Borrowing Company Money Pool Money Pool Money Pool Money Pool December 31, 2024 Limit (in millions) AEP Texas $ 374.6 $ 274.3 $ 233.8 $ 165.1 $ (284.9) $ 600.0 AEPTCo 313.3 332.0 71.8 138.4 (72.9) 820.0 (a) APCo 399.5 132.3 102.6 29.7 (77.3) 750.0 I&M 135.8 8.4 58.8 3.9 (126.8) 500.0 OPCo 310.0 183.4 180.5 94.2 114.9 600.0 PSO 308.9 314.5 171.4 287.7 232.0 750.0 SWEPCo 362.2 59.3 249.5 57.3 (275.0) 750.0 Year Ended December 31, 2023: Maximum Average Net Loans to Borrowings Maximum Borrowings Average (Borrowings from) Authorized from the Loans to the from the Loans to the the Utility Money Short-term Utility Utility Utility Utility Pool as of Borrowing Company Money Pool Money Pool Money Pool Money Pool December 31, 2023 Limit (in millions) AEP Texas $ 477.5 $ 42.0 $ 216.8 $ 12.9 $ (103.7) $ 600.0 AEPTCo 471.3 309.4 135.6 70.5 (62.8) 820.0 (a) APCo 388.6 19.8 283.5 19.0 (320.7) 750.0 I&M 475.3 112.2 84.0 44.2 (63.3) 500.0 OPCo 485.7 64.7 183.0 40.2 (110.5) 500.0 PSO 375.0 121.5 92.5 49.6 (54.4) 750.0 SWEPCo 401.6 25.8 150.7 16.5 (88.7) 750.0 (a) Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions. The activity in the above tables does not include short-term lending activity of certain AEP nonutility subsidiaries. AEP Texas’ wholly-owned subsidiary, AEP Texas North Generation Company, LLC and SWEPCo’s wholly-owned subsidiary, Mutual Energy SWEPCo, LLC participate in the Nonutility Money Pool. The amounts of outstanding loans to the Nonutility Money Pool as of December 31, 2024 and 2023 are included in Advances to Affiliates on each subsidiaries’ balance sheets. The Nonutility Money Pool participants’ money pool activity is described in the following tables: Year Ended December 31, 2024: Maximum Loans Average Loans Loans to the Nonutility to the Nonutility to the Nonutility Money Pool as of Company Money Pool Money Pool December 31, 2024 (in millions) AEP Texas $ 7.2 $ 7.1 $ 7.2 SWEPCo 2.9 2.6 2.3 Year Ended December 31, 2023: Maximum Loans Average Loans Loans to the Nonutility to the Nonutility to the Nonutility Money Pool as of Company Money Pool Money Pool December 31, 2023 (in millions) AEP Texas $ 7.1 $ 6.9 $ 7.1 SWEPCo 2.8 2.4 2.2 AEP has a direct financing relationship with AEPTCo to meet its short-term borrowing needs. The amounts of outstanding loans to and borrowings from AEP as of December 31, 2024 and 2023 are included in Advances to Affiliates and Advances from Affiliates, respectively, on AEPTCo’s balance sheets. AEPTCo’s direct financing activities with AEP and corresponding authorized borrowing limits are described in the following tables: Year Ended December 31, 2024: Borrowings Authorized Maximum Maximum Average Average from AEP Loans to Short-term Borrowings Loans Borrowings Loans as of AEP as of Borrowing Company from AEP to AEP from AEP to AEP December 31, 2024 December 31, 2024 Limit (a) (in millions) AEPTCo Parent $ 49.4 $ 148.5 $ 14.9 $ 57.0 $ — $ 20.4 $ — SWTCo 1.9 — 1.8 — 1.8 — 50.0 Year Ended December 31, 2023: Borrowings Authorized Maximum Maximum Average Average from AEP Loans to Short-term Borrowings Loans Borrowings Loans as of AEP as of Borrowing Company from AEP to AEP from AEP to AEP December 31, 2023 December 31, 2023 Limit (a) (in millions) AEPTCo Parent $ 42.7 $ 158.1 $ 18.0 $ 64.2 $ 42.7 $ — $ — SWTCo 1.6 — 1.6 — 1.7 — 50.0 (a) Amount represents the authorized short-term borrowing limit from FERC or state regulatory agencies not otherwise included in the utility money pool above. AEPTCo Parent has no short-term borrowing limit. The maximum and minimum interest rates for funds either borrowed from or loaned to the Utility Money Pool are summarized in the following table: Years Ended December 31, 2024 2023 2022 Maximum Interest Rate 5.79 % 5.81 % 5.28 % Minimum Interest Rate 4.74 % 4.66 % 0.10 % The average interest rates for funds borrowed from and loaned to the Utility Money Pool are summarized in the following table: Average Interest Rate for Funds Borrowed Average Interest Rate for Funds Loaned Company 2024 2023 2022 2024 2023 2022 AEP Texas 5.48 % 5.46 % 1.08 % 5.45 % 5.71 % 1.99 % AEPTCo 5.51 % 5.41 % 1.81 % 5.50 % 5.56 % 2.47 % APCo 5.51 % 5.54 % 2.34 % 5.41 % 5.54 % 2.39 % I&M 5.40 % 5.14 % 2.57 % 5.44 % 5.57 % 2.20 % OPCo 5.70 % 5.43 % 3.51 % 5.20 % 5.60 % 1.22 % PSO 5.50 % 5.51 % 2.65 % 4.79 % 5.35 % 0.75 % SWEPCo 5.41 % 5.34 % 2.80 % 4.78 % 5.72 % 0.55 % Maximum, minimum and average interest rates for funds loaned to the Nonutility Money Pool are summarized in the following table: Maximum Interest Rate Minimum Interest Rate Average Interest Rate Year Ended for Funds Loaned to for Funds Loaned to for Funds Loaned to December 31, Company the Nonutility Money Pool the Nonutility Money Pool the Nonutility Money Pool 2024 AEP Texas 5.79 % 4.74 % 5.46 % 2024 SWEPCo 5.79 % 4.74 % 5.45 % 2023 AEP Texas 5.81 % 4.66 % 5.54 % 2023 SWEPCo 5.81 % 4.66 % 5.56 % 2022 AEP Texas 5.28 % 0.46 % 2.23 % 2022 SWEPCo 5.28 % 0.46 % 2.23 % AEPTCo Parent’s and SWTCo’s maximum, minimum and average interest rates for funds either borrowed from or loaned to AEP are summarized in the following table: Maximum Minimum Maximum Minimum Average Average Interest Rate Interest Rate Interest Rate Interest Rate Interest Rate Interest Rate for Funds for Funds for Funds for Funds for Funds for Funds Year Ended Borrowed from Borrowed from Loaned to Loaned to Borrowed from Loaned to December 31, AEP AEP AEP AEP AEP AEP 2024 5.79 % 4.66 % 5.79 % 4.66 % 5.53 % 5.56 % 2023 5.81 % 4.53 % 5.81 % 4.53 % 5.56 % 5.51 % 2022 5.28 % 0.46 % 5.28 % 0.46 % 2.08 % 2.07 % Interest expense related to short-term borrowing activities with the Utility Money Pool, Nonutility Money Pool and direct borrowing financing relationship are included in Interest Expense on each of the Registrant Subsidiaries’ statements of income. The Registrant Subsidiaries incurred interest expense for all short-term borrowing activities as follows: Years Ended December 31, Company 2024 2023 2022 (in millions) AEP Texas $ 6.7 $ 10.8 $ 0.9 AEPTCo 4.3 7.6 3.5 APCo 6.1 16.8 5.6 I&M 4.3 3.2 2.9 OPCo 3.7 9.7 2.3 PSO 8.9 2.3 5.5 SWEPCo 13.6 7.9 4.9 Interest income related to short-term lending activities with the Utility Money Pool, Nonutility Money Pool and direct borrowing financing relationship are included in Interest Income, unless shown as Other Income due to materiality, on each of the Registrant Subsidiaries’ statements of income. The Registrant Subsidiaries earned interest income for all short-term lending activities as follows: Years Ended December 31, Company 2024 2023 2022 (in millions) AEP Texas $ 4.4 $ 0.1 $ 2.6 AEPTCo 10.5 7.0 1.6 APCo 1.6 1.1 2.8 I&M — 2.4 0.5 OPCo 3.2 0.1 0.4 PSO 1.0 1.5 0.3 SWEPCo 0.2 0.2 0.2 Credit Facilities See “Letters of Credit” section of Note 6 for additional information. Securitized Accounts Receivables – AEP Credit (Applies to AEP) AEP Credit has a receivables securitization agreement with bank conduits. Under the securitization agreement, AEP Credit receives financing from the bank conduits for the interest in the receivables AEP Credit acquires from affiliated utility subsidiaries. These securitized transactions allow AEP Credit to repay its outstanding debt obligations, continue to purchase the operating companies’ receivables and accelerate AEP Credit’s cash collections. AEP Credit’s receivables securitization agreement provides a commitment of $900 million from bank conduits to purchase receivables and expires in September 2026. As of December 31, 2024, the affiliated utility subsidiaries were in compliance with all requirements under the agreement. Accounts receivable information for AEP Credit was as follows: Years Ended December 31, 2024 2023 2022 (dollars in millions) Effective Interest Rates on Securitization of Accounts Receivable 5.39 % 5.33 % 1.84 % Net Uncollectible Accounts Receivable Written Off $ 29.4 $ 30.7 $ 29.5 December 31, 2024 2023 (in millions) Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts $ 1,117.0 $ 1,207.4 Short-term – Securitized Debt of Receivables 900.0 888.0 Delinquent Securitized Accounts Receivable 56.2 52.2 Bad Debt Reserves Related to Securitization 44.5 42.0 Unbilled Receivables Related to Securitization 335.5 409.8 AEP Credit’s delinquent customer accounts receivable represent accounts greater than 30 days past due. Securitized Accounts Receivables – AEP Credit (Applies to Registrant Subsidiaries, except AEP Texas and AEPTCo) Under this sale of receivables arrangement, the Registrant Subsidiaries sell, without recourse, certain of their customer accounts receivable and accrued unbilled revenue balances to AEP Credit and are charged a fee based on AEP Credit’s financing costs, administrative costs and uncollectible accounts experience for each Registrant Subsidiary’s receivables. APCo does not have regulatory authority to sell its West Virginia accounts receivable. The costs of customer accounts receivable sold are reported in Other Operation expense on the Registrant Subsidiaries’ statements of income. The Registrant Subsidiaries manage and service their customer accounts receivable, which are sold to AEP Credit. AEP Credit securitizes the eligible receivables for the operating companies and retains the remainder. The amount of accounts receivable and accrued unbilled revenues under the sale of receivables agreement were: December 31, Company 2024 2023 (in millions) APCo $ 192.7 $ 184.6 I&M 160.5 156.4 OPCo 470.7 541.7 PSO 111.4 134.6 SWEPCo 153.5 168.3 The fees paid to AEP Credit for customer accounts receivable sold were: Years Ended December 31, Company 2024 2023 2022 (in millions) APCo $ 15.5 $ 16.9 $ 9.4 I&M 15.4 16.3 9.7 OPCo 29.7 29.5 29.8 PSO 14.2 15.3 7.4 SWEPCo 17.6 18.5 9.4 The proceeds on the sale of receivables to AEP Credit were: Years Ended December 31, Company 2024 2023 2022 (in millions) APCo $ 1,953.7 $ 1,819.8 $ 1,552.9 I&M 2,105.3 2,054.8 2,045.6 OPCo 3,197.8 3,339.3 3,101.3 PSO 1,781.3 1,944.5 1,809.5 SWEPCo 1,838.1 1,866.4 1,858.4

STOCK-BASED COMPENSATION

STOCK-BASED COMPENSATION	12 Months Ended
	Dec. 31, 2024
Share-Based Payment Arrangement, Noncash Expense [Abstract]
STOCK-BASED COMPENSATION	STOCK-BASED COMPENSATION The disclosures in this note apply to AEP only. The impact of AEP’s share-based compensation plans is insignificant to the financial statements of the Registrant Subsidiaries. AEP’s long-term incentive plan available for eligible employees and directors, the American Electric Power System 2015 Long-Term Incentive Plan (2015 LTIP), was replaced prospectively for new grants by the American Electric Power System 2024 Long-Term Incentive Plan (2024 LTIP) effective in April 2024. The 2024 LTIP provides for a maximum of 10 million AEP common shares to be available for grant to eligible employees and directors. As of December 31, 2024, 9,806,016 shares remained available for issuance under the 2024 LTIP. No new awards may be granted under the 2015 LTIP. To the extent the issuance of a share is subject to an outstanding award under the 2015 LTIP, the issuance of that share will take place under the 2015 LTIP. Awards granted under the 2024 LTIP may be made in the form of stock options, stock appreciation rights, restricted stock, restricted stock units, performance shares, performance units, cash-based awards and other stock-based awards. All types of shares issued under the 2024 LTIP including stock options, stock appreciation rights, restricted stock units and performance shares reduce the shares remaining available for grants at a rate of 1 to 1. Cash settled awards do not reduce the number of shares remaining available under the 2024 LTIP. The following sections provide further information regarding each type of stock-based compensation award granted under these plans. Performance Shares Performance shares are settled in AEP common stock and reduce the aggregate share authorization. The number of performance shares held at the end of the three-year performance period is multiplied by the performance score for such period to determine the actual number of performance shares that participants realize. The performance score can range from 0% to 200% and is determined at the end of the performance period based on performance measures, which include both performance and market conditions, established for each grant at the beginning of the performance period by the Human Resources Committee of AEP’s Board of Directors (HR Committee). Certain employees must satisfy a minimum stock ownership requirement. If those employees have not met their stock ownership requirement, a portion or all of their performance shares are mandatorily deferred upon vesting into AEP career shares to the extent needed to meet their stock ownership requirement. AEP career shares are a form of non-qualified deferred compensation that has a value equivalent to a share of AEP common stock. AEP career shares are settled in AEP common stock after the participant’s termination of employment. AEP career shares are recorded in Paid-in Capital on the balance sheets. Amounts equivalent to cash dividends on both performance shares and AEP career shares accrue as additional shares. Management records compensation cost for performance shares over an approximately three-year vesting period. Performance shares are recorded as mezzanine equity on the balance sheets until the vesting date and compensation cost is calculated at fair value based on the performance metrics for each grant. Performance shares granted in 2024, 2023, and 2022 have three performance metrics: (a) three-year cumulative operating earnings per-share with a 50% weight, (b) relative total shareholder return with a 40% weight and (c) generation capacity additions, which focused on additions that maintain reliability for 2024 grants, renewable generation additions for 2023 grants, and non-emitting generation capacity as a percentage of total owned and purchased capacity for 2022 grants, each with a 10% weight. The three-year cumulative operating earnings per-share and renewable generation additions or non-emitting generating capacity metrics are adjusted quarterly for changes in performance relative to the metric approved by the HR Committee. The total shareholder return metric is measured relative to a peer group of similar companies and is based on a third-party Monte Carlo valuation. The value related to this metric does not change over the three-year vesting period. The HR Committee awarded performance shares and reinvested dividends on outstanding performance shares and AEP career shares as follows: Years Ended December 31, Performance Shares 2024 2023 2022 Awarded Shares (in thousands) 440.7 486.7 530.3 Weighted-Average Share Fair Value at Grant Date $ 99.76 $ 98.63 $ 97.61 Vesting Period (in years) 3 3 3 Performance Shares and AEP Career Shares Years Ended December 31, 2024 2023 2022 Awarded Shares (in thousands) 66.0 81.3 63.3 Weighted-Average Fair Value at Grant Date $ 91.75 $ 82.02 $ 98.73 Vesting Period (in years) (a) (a) (a) (a) The vesting period for the reinvested dividends on performance shares is equal to the remaining life of the related performance shares. Dividends on AEP career shares vest immediately when the dividend is awarded but are not settled in AEP common stock until after the participant’s AEP employment ends. Performance scores and final awards are determined and approved by the HR Committee in accordance with the pre-established performance measures within approximately two months after the end of the performance period. The performance scores and shares earned for the three-year periods were as follows: Years Ended December 31, Performance Shares 2024 (b) 2023 2022 Performance Score 109.8 % 106.1 % 131.1 % Performance Shares Earned 477,487 540,863 512,660 Performance Shares Mandatorily Deferred as AEP Career Shares 39,172 70,377 28,282 Performance Shares Voluntarily Deferred into the Incentive Compensation Deferral Program 21,245 22,716 23,609 Performance Shares to be Settled (a) 417,070 447,770 460,769 (a) Performance shares settled in AEP common stock in the quarter following the end of the year shown. (b) Performance shares earned, deferred and settled were calculated based on the estimated performance score. The settlements were as follows: Years Ended December 31, Performance Shares and AEP Career Shares 2024 2023 2022 (in millions) AEP Common Stock Settlements for Performance Shares $ 38.1 $ 41.8 $ 43.2 AEP Common Stock Settlements for Career Share Distributions 8.4 8.3 5.1 A summary of the status of AEP’s nonvested Performance Shares as of December 31, 2024 and changes during the year ended December 31, 2024 were as follows: Nonvested Performance Shares Shares Weighted Average (in thousands) Nonvested as of January 1, 2024 889.9 $ 99.49 Awarded 440.7 99.76 Dividends 49.4 91.82 Vested (a) (440.6) 100.52 Forfeited (161.8) 87.94 Nonvested as of December 31, 2024 777.6 100.97 (a) The vested Performance Shares will be converted to an estimated 417 thousand shares based on the closing share price on the day before settlement. Monte Carlo Valuation AEP engages a third-party for a Monte Carlo valuation to calculate the fair value of the total shareholder return metric for the performance shares awarded during and after 2017. The valuations use a lattice model and the expected volatility assumptions used were the historical volatilities for AEP and the members of their peer group. The assumptions used in the Monte Carlo valuations were as follows: Years Ended December 31, Assumptions 2024 2023 2022 Valuation Period (in years) (a) 2.85 2.87 2.86 Expected Volatility Minimum 18.79 % 21.23 % 25.92 % Expected Volatility Maximum 33.29 % 39.00 % 40.82 % Expected Volatility Average 22.34 % 25.35 % 31.09 % Dividend Rate (b) — % — % — % Risk Free Rate 4.43 % 4.32 % 1.64 % (a) Period from award date to vesting date. (b) Equivalent to reinvesting dividends. Restricted Stock Units The HR Committee grants restricted stock units (RSUs), which generally vest, subject to the participant’s continued AEP employment, over at least three years in approximately equal annual increments. The RSUs accrue dividends as additional RSUs. The additional RSUs granted as dividends vest on the same date, subject to the participant’s continued AEP employment, as the underlying RSUs. RSUs are converted into shares of AEP common stock upon vesting. The RSU compensation cost is measured at fair value on the grant date and recorded over the vesting period. Fair value is determined by multiplying the number of RSUs granted by the grant date market closing price. The maximum contractual term of outstanding RSUs is approximately 40 months from the grant date. The HR Committee awarded RSUs, including additional units awarded as dividends, as follows: Years Ended December 31, Restricted Stock Units 2024 2023 2022 Awarded Units (in thousands) 417.0 268.4 290.4 Weighted-Average Grant Date Fair Value $ 87.85 $ 88.52 $ 90.48 The total fair value and total intrinsic value of restricted stock units vested were as follows: Years Ended December 31, Restricted Stock Units 2024 2023 2022 (in millions) Fair Value of Restricted Stock Units Vested $ 25.9 $ 18.8 $ 17.8 Intrinsic Value of Restricted Stock Units Vested (a) 27.3 19.0 20.3 (a) Intrinsic value is calculated as market price at the vesting date. A summary of the status of AEP’s nonvested RSUs as of December 31, 2024 and changes during the year ended December 31, 2024 were as follows: Nonvested Restricted Stock Units Shares/Units Weighted Average (in thousands) Nonvested as of January 1, 2024 431.1 $ 88.57 Awarded 417.0 87.85 Vested (296.8) 87.26 Forfeited (74.0) 89.97 Nonvested as of December 31, 2024 477.3 88.37 The total aggregate intrinsic value of nonvested RSUs as of December 31, 2024 was $44 million and the weighted-average remaining contractual life was 1.5 years. Other Stock-Based Plans AEP also has a Stock Unit Accumulation Plan (SUAP) for Non-Employee Directors providing each non-employee director with AEP stock units as a substantial portion of the compensation for their services as a director. The number of stock units provided is based on the closing price of AEP common stock on the last trading day of the quarter for which the stock units were earned. Amounts equivalent to cash dividends on the stock units accrue as additional AEP stock units. The stock units granted to non-employee directors are fully vested on their grant date. Stock units are paid to directors upon termination of their board service or up to 10 years later if the participant so elects. Cash settlements for stock units were calculated based on the average closing price of AEP common stock for the last 20 trading days prior to the distribution date. Effective June 30, 2022, the SUAP was amended to pay stock units in AEP common stock rather than cash. Management records compensation costs for stock units when the units are awarded and prior to June 2022 adjusted the liability for changes in value based on the current 20-day average closing price of AEP common stock on the valuation date. After five years of service on the Board of Directors, non-employee directors receive subsequent AEP stock units as contributions to an AEP stock fund under the Stock Unit Accumulation Plan. Such amounts may be exchanged into other market-based investment options available to employees that participate in AEP’s Incentive Compensation Deferral Plan. These balances are paid in cash upon termination of board service or up to 10 years later if the participant so elects. AEP common stock and cash settlements for stock unit distributions were immaterial for the years ended December 31, 2024, 2023 and 2022. The Board of Directors awarded stock units, including units awarded for dividends, as follows: Years Ended December 31, Stock Unit Accumulation Plan for Non-Employee Directors 2024 2023 2022 Awarded Units (in thousands) 18.9 19.8 14.5 Weighted-Average Grant Date Fair Value $ 91.42 $ 82.14 $ 95.16 Share-based Compensation Plans The compensation cost for share-based payment arrangements, the actual tax benefit from the tax deductions for compensation cost recognized in income and the total compensation cost capitalized were as follows: Years Ended December 31, Share-based Compensation Plans 2024 2023 2022 (in millions) Compensation Cost for Share-based Payment Arrangements (a) $ 52.9 $ 50.9 $ 63.3 Actual Tax Benefit 7.4 6.4 8.0 Total Compensation Cost Capitalized 13.9 15.3 16.0 (a) Compensation cost for share-based payment arrangements is included in Other Operation and Maintenance expenses on the statements of income. As of December 31, 2024, there was $59 million of total unrecognized compensation cost related to unvested share-based compensation arrangements granted under the 2015 LTIP and the 2024 LTIP. Unrecognized compensation cost related to unvested share-based arrangements will change as the fair value of performance shares is adjusted each period and as forfeitures for all award types are realized. AEP’s unrecognized compensation cost will be recognized over a weighted-average period of 1.5 years. Under the 2015 LTIP and 2024 LTIP, AEP is permitted to use authorized but unissued shares, treasury shares, shares acquired in the open market specifically for distribution under these plans, or any combination thereof to fulfill share commitments. AEP’s current practice is to use authorized but unissued shares to fulfill share commitments. The number of shares used to fulfill share commitments is generally reduced to offset tax withholding obligations.

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	12 Months Ended
	Dec. 31, 2024
Related Party Transactions [Abstract]
RELATED PARTY TRANSACTIONS	RELATED PARTY TRANSACTIONS The disclosures in this note apply to all Registrant Subsidiaries unless indicated otherwise. For other related party transactions, also see “Income Taxes and Investment and Production Tax Credits” section of Note 1 in addition to “Corporate Borrowing Program” and “Securitized Accounts Receivables – AEP Credit” sections of Note 15. Intercompany Billings The Registrant Subsidiaries and other AEP subsidiaries perform certain utility services for each other when necessary or practical. The costs of these services are billed on a direct-charge basis, whenever possible, or on reasonable basis of proration for services that benefit multiple companies. The billings for services are made at cost and include no compensation for the use of equity capital. Power Coordination Agreement (Applies to all Registrant Subsidiaries except AEP Texas and AEPTCo) Effective January 1, 2014, the FERC approved the PCA. Under the PCA, APCo, I&M, KPCo and WPCo are individually responsible for planning their respective capacity obligations. The PCA allows, but does not obligate, APCo, I&M, KPCo and WPCo to participate collectively under a common fixed resource requirement capacity plan in PJM and to participate in specified collective Off-system Sales and purchase activities. AEPSC conducts power, capacity, coal, natural gas, interest rate and, to a lesser extent, heating oil, gasoline and other risk management activities on behalf of APCo, I&M, KPCo, PSO, SWEPCo and WPCo. Certain power and natural gas risk management activities for APCo, I&M, KPCo and WPCo are allocated based on the four member companies’ respective equity positions, while power and natural gas risk management activities for PSO and SWEPCo are allocated based on the Operating Agreement. AEPSC conducts only gasoline, diesel fuel, energy procurement and risk management activities on OPCo’s behalf. Joint License Agreement (Applies to all Registrant Subsidiaries except AEP Texas and SWEPCo) AEPTCo entered into a 50-year joint license agreement with APCo, I&M, KPCo, OPCo and PSO, respectively, allowing either party to occupy the granting party’s facilities or real property. In addition, AEPTCo entered into a 5-year joint license agreement with APCo and WPCo. After the expiration of these agreements, the term shall automatically renew for successive one-year terms unless either party provides notice. The joint license billing provides compensation to the granting party for the cost of carrying assets, including depreciation expense, property taxes, interest expense, return on equity and income taxes. AEPTCo recorded the costs related to these agreements in Other Operation expense on the statements of income. APCo, I&M, KPCo, OPCo, PSO and WPCo recorded income related to these agreements in Sales to AEP Affiliates on the statements of income. The impact of the joint license agreement for the years ended December 31, 2024, 2023 and 2022 was not material. Unit Power Agreements (Applies to I&M) A UPA between AEGCo and I&M (the I&M Power Agreement) provides for the sale by AEGCo to I&M of all the energy and capacity available to AEGCo at the Rockport Plant unless it is sold to another utility. I&M is obligated, whether or not power is available from AEGCo, to pay as a demand charge for the right to receive such power (and as an energy charge for any associated energy taken by I&M) net of amounts received by AEGCo from any other sources, sufficient to enable AEGCo to pay all of its operating and other expenses, including a rate of return on the common equity of AEGCo as approved by the FERC. The UPA will continue in effect until the debt obligations of AEGCo secured by the Rockport Plant have been satisfied and discharged (currently expected to be December 2028). I&M’s direct purchases from AEGCo were $209 million, $181 million and $242 million for the years ended December 31, 2024, 2023 and 2022, respectively. These direct purchases are presented as Purchased Electricity from AEP Affiliates on I&M’s statements of income. Ohio Auctions (Applies to OPCo) In connection with OPCo’s June 2012 - May 2015 ESP, the PUCO ordered OPCo to conduct energy and capacity auctions for its entire SSO load for delivery beginning in June 2015. AEP Energy and AEPEP participate in the auction process and have been awarded tranches of OPCo’s SSO load. OPCo’s auction purchases were $98 million, $87 million and $10 million for the years ended December 31, 2024, 2023 and 2022, respectively. These direct purchases are presented as Purchased Electricity from AEP Affiliates on OPCo’s statements of income. Sales and Purchases of Property Certain AEP subsidiaries had affiliated sales and purchases of electric property individually amounting to $100 thousand or more, sales and purchases of meters and transformers, and sales and purchases of transmission property. There were no gains or losses recorded on the transactions and the net book value of all sales and purchases for the years ended December 31, 2024, 2023 and 2022 were not material. These sales and purchases are recorded in Property, Plant and Equipment on the balance sheets. Charitable Contributions to AEP Foundation The American Electric Power Foundation is funded by American Electric Power and its utility operating units. The Foundation provides a permanent, ongoing resource for charitable initiatives and multi-year commitments in the communities served by AEP and initiatives outside of AEP’s 11-state service area. Charitable contributions to the AEP Foundation were not made in 2024 or 2023. Charitable contributions were recorded in Other Operation expenses on the statements of income as follows for the year ended December 31, 2022: AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Contributions to AEP Foundation $ 75.0 $ 9.9 $ 11.1 $ 12.5 $ 11.0 $ 8.1 $ 5.8 $ 8.8 Other Related Party Contributions For the years ended December 31, 2023 and 2022, AEP made contributions of $0.1 million and $0.2 million, respectively, to Clean Affordable Reliable Coalition (CARE), a 501(c)(6) organization established to encourage communication, discussion and concerted action related to tax policy associated with clean, affordable and reliable power initiatives. These contributions were made in the ordinary course of business. AEP was a member of CARE and provided the organization its primary financial support. In addition, an employee of AEP served as a board member of the organization during 2023 and 2022. AEP management has determined these contributions are Related Party transactions under ASC 850 based on AEP’s ability to significantly influence the management and operating policies of CARE. AEP made no contributions to CARE in 2024. Beginning in August 2024, an officer of AEP also served as a member of the board of directors of a company that is a vendor of certain AEP subsidiaries. From August 2024 through December 2024, AEP purchased $44 million of distribution and transmission infrastructure services from the related party vendor in the ordinary course of business. Of this amount, $25 million was incurred by AEP Texas and $13 million was incurred by PSO. The amounts incurred by the remaining Registrant Subsidiaries were not significant. I&M Barging, Urea Transloading and Other Services (Applies to APCo and I&M) I&M provides barging, urea transloading and other transportation services to affiliates. Urea is a chemical used to control NO x emissions at certain generation plants in the AEP System. I&M recorded revenues from barging, transloading and other services in Other Revenues – Affiliated on the statements of income. The affiliated companies recorded these costs paid to I&M as fuel expenses or other operation expenses. The amounts of affiliated expenses were: Years Ended December 31, Company 2024 2023 2022 (in millions) AEGCo $ 10.0 $ 9.3 $ 11.3 APCo 47.0 39.2 36.1 KPCo — — 2.0 WPCo 7.5 10.6 4.7 AEP Wind Holdings LLC PPAs (Applies to I&M, OPCo and SWEPCo) Prior to acquisition, Fowler Ridge 2 had PPAs with I&M and OPCo and Flat Ridge 2 had a PPA with SWEPCo for a portion of their energy production. The following table shows the amounts of purchased electricity by I&M, PSO and SWEPCo: Years Ended December 31, Company 2023 2022 (in millions) I&M $ 8.0 $ 11.8 OPCo 16.1 23.6 SWEPCo — 13.7 See Note 7 - Acquisitions, Dispositions and Impairments for additional information related to the disposal of the 50% interests in Fowler Ridge 2 which was included in the August 2023 sale of the Competitive Contracted Renewables Portfolio and Flat Ridge 2 which was sold in November 2022. Transmission Service Charges The AEP East Companies are parties to the TA, which defines how transmission costs through the PJM OATT are allocated among the AEP East Companies on a 12-month average coincident peak basis. Additional costs for transmission services provided by AEPTCo and other transmission affiliates are billed to AEP East Companies through the PJM OATT. PSO, SWEPCo and AEPSC are parties to the TCA in connection with the operation of the transmission assets of PSO and SWEPCo. Under the TCA, AEPSC is responsible for monitoring the reliability of their transmission systems and administering the OATT. Additional costs for transmission services provided by AEPTCo and other transmission affiliates are billed to PSO and SWEPCo through the SPP OATT. Pursuant to an order from the PUCT, ETT bills AEP Texas for its ERCOT wholesale transmission services. The charges discussed above are recorded in Other Operation expenses on the statements of income. AEPTCo recorded affiliated transmission revenues in Sales to AEP Affiliates on the statements of income. Refer to the Affiliated Revenues section below for amounts related to these transactions. The following table shows the net transmission service charges recorded by the Registrant Subsidiaries: Years Ended December 31, Company 2024 2023 2022 (in millions) AEP Texas $ 30.6 $ 28.7 $ 28.5 APCo 380.7 365.1 345.1 I&M 252.7 226.2 220.8 OPCo 696.1 665.3 608.2 PSO 127.1 100.1 110.8 SWEPCo 64.5 49.2 62.1 Affiliated Revenues The tables below represent revenues from affiliates, net of respective provisions for refund, by type of revenue for the Registrant Subsidiaries. Related party revenues are shown in Sales to AEP Affiliates, Provision for Refund - Affiliated and Other Revenues - Affiliated, respectively, on the Registrant Subsidiaries’ statements of income. Related Party Revenues AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Year Ended December 31, 2024 Direct Sales to East Affiliates $ — $ — $ 159.0 $ — $ — $ — $ — Transmission Revenues — 1,491.1 78.8 (8.8) (6.9) 0.1 60.6 Other Revenues 5.4 21.2 9.6 75.0 29.6 6.8 1.5 Total Affiliated Revenues $ 5.4 $ 1,512.3 $ 247.4 $ 66.2 $ 22.7 $ 6.9 $ 62.1 Related Party Revenues AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Year Ended December 31, 2023 Direct Sales to East Affiliates $ — $ — $ 158.7 $ — $ — $ — $ — Transmission Revenues — 1,304.0 70.9 (11.1) 3.2 — 45.3 Barging, Urea Transloading and Other Transportation Services — — — 59.0 — — — Other Revenues 4.9 13.8 9.7 9.9 27.9 1.2 1.5 Total Affiliated Revenues $ 4.9 $ 1,317.8 $ 239.3 $ 57.8 $ 31.1 $ 1.2 $ 46.8 Related Party Revenues AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Year Ended December 31, 2022 Direct Sales to East Affiliates $ — $ — $ 169.7 $ — $ — $ — $ — Direct Sales to West Affiliates — — — — — — 1.3 Transmission Revenues — 1,276.4 77.5 7.7 (3.6) — 51.5 Barging, Urea Transloading and Other Transportation Services — — — 54.1 — — — Other Revenues 3.5 7.4 8.9 7.8 22.4 2.9 1.1 Total Affiliated Revenues $ 3.5 $ 1,283.8 $ 256.1 $ 69.6 $ 18.8 $ 2.9 $ 53.9

VARIABLE INTEREST ENTITIES AND

VARIABLE INTEREST ENTITIES AND EQUITY METHOD INVESTMENTS	12 Months Ended
	Dec. 31, 2024
Variable Interest Entities [Abstract]
VARIABLE INTEREST ENTITIES AND EQUITY METHOD INVESTMENTS	VARIABLE INTEREST ENTITIES AND EQUITY METHOD INVESTMENTS The disclosures in this note apply to all Registrants unless indicated otherwise. The accounting guidance for “Variable Interest Entities” is a consolidation model that considers if a company has a variable interest in a VIE. A VIE is a legal entity that possesses any of the following conditions: the entity’s equity at risk is not sufficient to permit the legal entity to finance its activities without additional subordinated financial support, equity owners are unable to direct the activities that most significantly impact the legal entity’s economic performance (or they possess disproportionate voting rights in relation to the economic interest in the legal entity), or the equity owners lack the obligation to absorb the legal entity’s expected losses or the right to receive the legal entity’s expected residual returns. Entities are required to consolidate a VIE when it is determined that they have a controlling financial interest in a VIE and therefore, are the primary beneficiary of that VIE, as defined by the accounting guidance for “Variable Interest Entities.” In determining whether AEP is the primary beneficiary of a VIE, management considers whether AEP has the power to direct the most significant activities of the VIE and is obligated to absorb losses or receive the expected residual returns that are significant to the VIE. Management believes that significant assumptions and judgments were applied consistently. AEP holds ownership interests in businesses with varying ownership structures. Partnership interests and other variable interests are evaluated to determine if each entity is a VIE, and if so, whether or not the VIE should be consolidated into AEP’s financial statements. AEP has not provided material financial or other support that was not previously contractually required to any of its consolidated VIEs. AEP’s interests in nonconsolidated VIEs are accounted for under the equity method of accounting. Consolidated Variable Interests Entities Sabine (Applies to AEP and SWEPCo) Sabine is a mining operator whose purpose was to provide mining services to SWEPCo’s Pirkey Plant until its retirement in March 2023. See "Pirkey Plant and Related Fuel Operations" section of Note 5 for additional information. Sabine’s post-production operations primarily consist of reclamation and other land-related activities. The terms of these services are governed by a lignite mining agreement between SWEPCo and Sabine. SWEPCo has no equity investment in Sabine but is Sabine’s only customer. SWEPCo guarantees the debt obligations and lease obligations of Sabine. Under the terms of the note agreements with Sabine’s creditors, substantially all assets are pledged and all rights under the lignite mining agreement are assigned to SWEPCo. The creditors of Sabine have no recourse to any AEP entity other than SWEPCo. Under the provisions of the lignite mining agreement, SWEPCo is required to pay an amount equal to Sabine’s operating costs plus a management fee and SWEPCo holds an option agreement to purchase Sabine, which SWEPCo exercised in 2023. As a result, SWEPCo will take direct control over reclamation activities in October 2026. Based on these facts, management concluded that SWEPCo is the primary beneficiary and is required to consolidate Sabine. See the tables below for the classification of Sabine’s assets and liabilities on SWEPCo’s balance sheets. As part of the process to receive a renewal of a Texas Railroad Commission permit for lignite mining, SWEPCo provides guarantees of mine reclamation o f $155 million . Since SWEPCo uses self-bonding, the guarantee commits SWEPCo to complete the reclamation, in the event, Sabine does not complete the work. This guarantee ends upon completion of reclamation activities expected by 2037 with an estimated cost of $100 million. Actual costs may vary due to inflation and changes in reclamation scope. SWEPCo recovers these costs through its fuel clauses. As of December 31, 2024, SWEPCo has recorded an ARO of $96 million and has paid or accrued $77 million for reclamation costs billed by Sabine. To date, SWEPCo has collected $97 million from customers for reclamation costs and expects to collect an additional $76 million recorded in Deferred Charges and Other Noncurrent Assets on SWEPCo’s balance sheets. DCC Fuel (Applies to AEP and I&M) I&M has nuclear fuel lease agreements with DCC Fuel, which was formed for the purpose of acquiring, owning and leasing nuclear fuel to I&M. DCC Fuel purchased the nuclear fuel from I&M with funds received from the issuance of notes to financial institutions. Each DCC Fuel entity is a single-lessee leasing arrangement with only one asset and is capitalized with all debt. Each is a separate legal entity from I&M, the assets of which are not available to satisfy the debts of I&M. Payments on the leases for the years ended December 31, 2024, 2023 and 2022 were $111 million, $97 million and $84 million, respectively. The leases qualify as finance leases because title to the nuclear fuel transfers to I&M at the end of the respective lease terms, which do not exceed 54 months . Based on I&M’s control of DCC Fuel, management concluded that I&M is the primary beneficiary and is required to consolidate DCC Fuel. The finance leases are eliminated upon consolidation. See the tables below for the classification of DCC Fuel’s assets and liabilities on I&M’s balance sheets. Transition Funding (Applies to AEP and AEP Texas) Transition Funding was formed for the sole purpose of issuing and servicing securitization bonds related to restructuring legislation in Texas. Management concluded that AEP Texas is the primary beneficiary of Transition Funding because AEP Texas has the power to direct the most significant activities of the VIE and AEP Texas’ equity interest could potentially be significant. Therefore, AEP Texas is required to consolidate Transition Funding. In December 2024, the final AEP Texas Central Transition Funding III LLC securitization bond matured. As of December 31, 2023, the securitized bond included in Long-term Debt Due Within One Year - Nonaffiliated was $72 million and the securitized bond included in Long-term Debt - Nonaffiliated was immaterial on the balance sheet. Transition Funding’s securitized transition assets were $64 million as of December 31, 2023, which was presented separately on the face of the balance sheet. The securitized transition assets represent the right to impose and collect Texas true-up costs from customers receiving electric transmission or distribution service from AEP Texas under-recovery mechanisms approved by the PUCT. The securitization bonds are payable only from and secured by the securitized transition assets. The bondholders have no recourse to AEP Texas or any other AEP entity. AEP Texas acts as the servicer for Transition Funding’s securitized transition assets and remits all related amounts collected from customers to Transition Funding for interest and principal payments on the securitization bonds and related costs. See the tables below for the classification of Transition Funding’s assets and liabilities on the balance sheets. Restoration Funding (Applies to AEP and AEP Texas) Restoration Funding was formed for the sole purpose of issuing and servicing securitization bonds related to storm restoration of AEP Texas’ distribution system primarily due to damage caused by Hurricane Harvey. Management concluded that AEP Texas is the primary beneficiary of Restoration Funding because AEP Texas has the power to direct the most significant activities of the VIE and AEP Texas’ equity interest could potentially be significant. Therefore, AEP Texas is required to consolidate Restoration Funding. As of December 31, 2024 and 2023, $24 million and $24 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, and $102 million and $126 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Restoration Funding’s securitized assets were $117 million and $139 million as of December 31, 2024 and 2023, respectively, which are presented separately on the face of the balance sheets. The securitized restoration assets represent the right to impose and collect Texas storm restoration costs from customers receiving electric transmission or distribution service from AEP Texas under-recovery mechanisms approved by the PUCT. The securitization bonds are payable only from and secured by the securitized assets. The bondholders have no recourse to AEP Texas or any other AEP entity. AEP Texas acts as the servicer for Restoration Funding’s securitized assets and remits all related amounts collected from customers to Restoration Funding for interest and principal payments on the securitization bonds and related costs. See the tables below for the classification of Restoration Funding’s assets and liabilities on the balance sheets. Appalachian Consumer Rate Relief Funding (Applies to AEP and APCo) Appalachian Consumer Rate Relief Funding was formed for the sole purpose of issuing and servicing securitization bonds related to APCo’s under-recovered ENEC deferral balance. Management concluded that APCo is the primary beneficiary of Appalachian Consumer Rate Relief Funding because APCo has the power to direct the most significant activities of the VIE and APCo’s equity interest could potentially be significant. Therefore, APCo is required to consolidate Appalachian Consumer Rate Relief Funding. As of December 31, 2024 and 2023, $28 million and $27 million of the securitized bonds were included in Long-term Debt Due Within One Year - Nonaffiliated, respectively, and $91 million and $120 million were included in Long-term Debt - Nonaffiliated, respectively, on the balance sheets. Appalachian Consumer Rate Relief Funding’s securitized assets were $106 million and $133 million as of December 31, 2024 and 2023, respectively, which are presented separately on the face of the balance sheets. The phase-in recovery property represents the right to impose and collect West Virginia deferred generation charges from customers receiving electric transmission, distribution and generation service from APCo under a recovery mechanism approved by the WVPSC. In November 2013, securitization bonds were issued. The securitization bonds are payable only from and secured by the securitized assets. The bondholders have no recourse to APCo or any other AEP entity. APCo acts as the servicer for Appalachian Consumer Rate Relief Funding’s securitized assets and remits all related amounts collected from customers to Appalachian Consumer Rate Relief Funding for interest and principal payments on the securitization bonds and related costs. See the tables below for the classification of Appalachian Consumer Rate Relief Funding’s assets and liabilities on APCo’s balance sheets. Storm Recovery Funding (Applies to AEP and SWEPCo) In August 2024, Storm Recovery Funding was formed for the sole purpose of issuing and servicing securitization bonds related to storm recovery primarily related to SWEPCo’s distribution system. Management concluded that SWEPCo is the primary beneficiary of Storm Recovery Funding because SWEPCo has the power to direct the most significant activities of the VIE and SWEPCo’s equity interest could potentially be significant. Therefore, SWEPCo is required to consolidate Storm Recovery Funding. As of December 31, 2024, $23 million of the securitized bonds was included in Long-term Debt Due Within One Year - Nonaffiliated and $309 million was included in Long-term Debt - Nonaffiliated on the balance sheet. Storm Recovery Funding’s securitized assets are $331 million as of December 31, 2024, which is presented separately on the face of the balance sheet. The securitized assets represent the right to impose and collect SWEPCo storm recovery charges from SWEPCo’s Louisiana jurisdictional customers. The securitization bonds are payable only from and secured by the securitized assets. The bondholders have no recourse to SWEPCo or any other AEP entity. SWEPCo acts as the servicer for Storm Recovery Funding’s securitized assets and remits all related amounts collected from customers to Storm Recovery Funding for interest and principal payments on the securitization bonds and related costs. See the tables below for the classification of Storm Recovery Funding’s assets and liabilities on the balance sheet. AEP Credit (Applies to AEP) AEP Credit is a wholly-owned subsidiary of Parent. AEP Credit purchases, without recourse, accounts receivable from certain utility subsidiaries of AEP to reduce working capital requirements. AEP provides a minimum of 5% equity and up to 35% of AEP Credit’s short-term borrowing needs in excess of third-party financings. Any third-party financing of AEP Credit only has recourse to the receivables securitized for such financing. Based on AEP’s control of AEP Credit, management concluded that AEP is the primary beneficiary and is required to consolidate AEP Credit. See the tables below for the classification of AEP Credit’s assets and liabilities on the balance sheets. See “Securitized Accounts Receivables - AEP Credit” section of Note 15. EIS (Applies to AEP) AEP’s subsidiaries participate in one protected cell of EIS for seven lines of insurance. EIS has multiple protected cells. Neither AEP nor its subsidiaries have an equity investment in EIS. The AEP System is essentially this EIS cell’s only participant, but allows certain third-parties access to this insurance. AEP’s subsidiaries and any allowed third-parties share in the insurance coverage, premiums and risk of loss from claims. Based on AEP’s control and the structure of the protected cell of EIS, management concluded that AEP is the primary beneficiary of the protected cell and is required to consolidate the protected cell of EIS. The insurance premium expense to the protected cell for the years ended December 31, 2024, 2023 and 2022 was $37 million, $34 million and $31 million, respectively. See the tables below for the classification of the protected cell’s assets and liabilities on the balance sheets. The amount reported as equity is the protected cell’s policy holders’ surplus. Transource Energy (Applies to AEP) Transource Energy was formed for the purpose of investing in utilities which develop, acquire, construct, own and operate transmission facilities in accordance with FERC-approved rates. AEP has an 86.5% equity and voting ownership interest and the remaining 13.5% interest is held by a single third-party owner. Management concluded that Transource Energy is a VIE and that AEP is the primary beneficiary because AEP has the power to direct the most significant activities of the entity and AEP’s equity interest could potentially be significant. Therefore, AEP is required to consolidate Transource Energy. Transource Energy’s activities consist of the development, construction and operation of FERC-regulated transmission assets in Missouri, West Virginia, Pennsylvania, Maryland and Oklahoma. Transource Energy has a credit facility agreement where borrowings are loaned through intercompany lending agreements to its subsidiaries. The creditor to the agreement has no recourse to the general credit of AEP. Transource Energy’s credit facility agreement contains certain covenants and require it to maintain a percentage of debt-to-total capitalization at a level that does not exceed 67.5% . See the tables below for the classification of Transource Energy’s assets and liabilities on the balance sheets. The balances below represent the assets and liabilities of AEP’s consolidated VIEs. These balances include intercompany transactions that are eliminated upon consolidation. December 31, 2024 Consolidated VIEs SWEPCo I&M AEP Texas Restoration Funding APCo SWEPCo Storm Recovery Funding AEP Credit Protected Transource Energy (in millions) ASSETS Current Assets $ 6.0 $ 79.3 $ 21.3 $ 14.2 $ 3.4 $ 1,118.3 $ 218.5 $ 40.2 Net Property, Plant and Equipment — 132.3 — — — — — 598.3 Other Noncurrent Assets 110.8 63.6 121.9 (a) 109.6 (b) 331.4 10.5 — 3.5 Total Assets $ 116.8 $ 275.2 $ 143.2 $ 123.8 $ 334.8 $ 1,128.8 $ 218.5 $ 642.0 LIABILITIES AND EQUITY Current Liabilities $ 20.1 $ 79.2 $ 30.7 $ 30.5 $ 24.4 $ 1,068.8 $ 54.7 $ 57.2 Noncurrent Liabilities 96.3 196.0 111.2 91.4 308.7 1.0 96.0 274.3 Equity 0.4 — 1.3 1.9 1.7 59.0 67.8 310.5 Total Liabilities and Equity $ 116.8 $ 275.2 $ 143.2 $ 123.8 $ 334.8 $ 1,128.8 $ 218.5 $ 642.0 (a) Includes an intercompany item eliminated in consolidation of $5 million . (b) Includes an intercompany item eliminated in consolidation of $1 million . December 31, 2023 Consolidated VIEs SWEPCo I&M AEP Texas Transition Funding AEP Texas Restoration Funding APCo AEP Credit Protected Cell of EIS Transource Energy (in millions) ASSETS Current Assets $ 4.2 $ 81.9 $ 25.5 $ 27.5 $ 13.3 $ 1,208.8 $ 205.3 $ 36.9 Net Property, Plant and Equipment — 153.8 — — — — — 533.4 Other Noncurrent Assets 150.7 81.7 71.4 (a) 145.6 (b) 138.2 (c) 9.6 — 5.1 Total Assets $ 154.9 $ 317.4 $ 96.9 $ 173.1 $ 151.5 $ 1,218.4 $ 205.3 $ 575.4 LIABILITIES AND EQUITY Current Liabilities $ 19.9 $ 81.7 $ 75.5 $ 36.8 $ 29.9 $ 1,155.0 $ 49.2 $ 45.3 Noncurrent Liabilities 134.8 235.7 17.0 135.1 119.7 0.9 91.7 241.5 Equity 0.2 — 4.4 1.2 1.9 62.5 64.4 288.6 Total Liabilities and Equity $ 154.9 $ 317.4 $ 96.9 $ 173.1 $ 151.5 $ 1,218.4 $ 205.3 $ 575.4 (a) Includes an intercompany item eliminated in consolidation of $8 million. (b) Includes an intercompany item eliminated in consolidation of $6 million. (c) Includes an intercompany item eliminated in consolidation of $2 million. Non-Consolidated Significant Variable Interests - AEP AEPSC (Applies to Registrant Subsidiaries) AEPSC, a wholly-owned subsidiary of Parent, is consolidated by AEP. Parent is the sole equity owner of AEPSC and controls the activities of AEPSC. AEPSC provides certain managerial and professional services to AEP’s subsidiaries. The costs of the services are based on a direct-charge or on a prorated basis and billed to the AEP subsidiary companies at AEPSC’s cost. AEP subsidiaries have not provided financial or other support outside of the reimbursement of costs for services rendered. AEPSC finances its operations through cost reimbursement from other AEP subsidiaries. There are no other terms or arrangements between AEPSC and any of the AEP subsidiaries that could require additional financial support from an AEP subsidiary or expose them to losses outside of the normal course of business. AEPSC and its billings are subject to regulation by the FERC. AEP subsidiaries are exposed to losses to the extent they cannot recover the costs of AEPSC through their normal business operations. AEP subsidiaries are considered to have a significant variable interest in AEPSC due to their activity in AEPSC’s cost reimbursement structure. However, AEP subsidiaries do not have control over AEPSC. In the event AEPSC would require financing or other support outside the cost reimbursement billings, this financing would be provided by AEP. Total AEPSC billings to the Registrant Subsidiaries were as follows: Years Ended December 31, Company 2024 2023 2022 (in millions) AEP Texas $ 242.6 $ 228.5 $ 236.8 AEPTCo 289.7 269.9 286.6 APCo 335.3 324.9 347.5 I&M 187.6 178.4 192.4 OPCo 283.4 269.5 272.5 PSO 157.4 138.6 142.3 SWEPCo 194.4 185.1 192.5 The carrying amount and classification of variable interest in AEPSC’s accounts payable were as follows: December 31, 2024 2023 Company As Reported on Maximum As Reported on Maximum (in millions) AEP Texas $ 26.1 $ 26.1 $ 15.1 $ 15.1 AEPTCo 29.3 29.3 17.9 17.9 APCo 36.4 36.4 21.1 21.1 I&M 25.1 25.1 14.3 14.3 OPCo 34.5 34.5 19.0 19.0 PSO 19.2 19.2 10.6 10.6 SWEPCo 22.0 22.0 12.7 12.7 AEGCo (Applies to I&M) AEGCo, a wholly-owned subsidiary of Parent, is consolidated by AEP. AEGCo owns a 50% ownership interest in Rockport Plant, Units 1 and 2. AEGCo sells its portion of the output from the Rockport Plant to I&M. AEP has agreed to provide AEGCo with the funds necessary to satisfy all the debt obligations of AEGCo. I&M is considered to have a significant variable interest in AEGCo due to these transactions. I&M is exposed to losses to the extent it cannot recover the costs of AEGCo through its normal business operations. In the event AEGCo requires financing or other support outside the billings to I&M, it would be provided by AEP. AEGCo’s billings to I&M for the years ended December 31, 2024, 2023 and 2022 were $209 million, $181 million and $242 million, respectively. The carrying amounts of I&M’s liabilities associated with AEGCo as of December 31, 2024 and 2023 were $14 million and $15 million, respectively. Management estimates the maximum exposure of loss to be equal to the amount of such liabilities. AEP Development Services (Applies to OPCo) AEP Development Services LLC (Devco), a wholly-owned subsidiary of Parent, is consolidated by AEP. Devco was formed for the purpose of developing, constructing, and installing energy projects for the regulated operating companies across the AEP system. In the fourth quarter of 2024, Devco executed a purchase agreement with Bloom Energy, acquiring 100 MWs of solid oxide fuel cells with an option to acquire up to one gigawatt in total by the end of 2025. Devco contemporaneously executed an affiliated services agreement with OPCo to establish the terms and conditions for Devco to design, procure, construct, and ultimately sell customer-sited, behind-the-meter fuel cell generation facilities to OPCo. Sales of fuel cell generation facilities will be made for OPCo to meet its obligations arising from bilateral customer-sited renewable energy resource agreements (CSRERAs) entered with its commercial customers. Sales are generally expected to close when a fuel cell generation facility is mechanically complete and will be sold at net book value plus reimbursement for the costs of Devco’s services. OPCo will own and operate the fuel cell generation facilities, and sell power produced by them to its customers under the terms of the applicable CSRERAs. Devco is a VIE because its operations and activities, including the initial 100 MWs purchase of fuel cells from Bloom Energy, are entirely financed by Parent through borrowings from the Nonutility Money Pool. Parent controls the significant activities of Devco and is exposed to its potential losses to the extent sales of completed fuel cell generation facilities to OPCo are insufficient to cover its costs of operations. AEP intends to recover its investment through the fulfillment of contractual commitments to deploy and install fuel cells to provide electricity service to customers. Based on AEP’s control of Devco, management concluded that AEP is the primary beneficiary and is required to consolidate Devco. In addition, OPCo has a noncontrolling variable interest in Devco because of the pricing structure for the sales of fuel cell generation facilities. As of December 31, 2024, the amounts of CWIP and borrowings from the Nonutility Money Pool were $457 million and $456 million, respectively. Non-Consolidated Significant Variable Interests - Registrant Subsidiaries DHLC (Applies to AEP and SWEPCo) DHLC is a mining operator which previously sold 50% of the lignite produced to SWEPCo and 50% to CLECO. The operations of DHLC are governed by the lignite mining agreement among SWEPCo, CLECO and DHLC. SWEPCo and CLECO share the executive board seats and voting rights equally. In accordance with the lignite mining agreement, each entity is responsible for 50% of DHLC’s obligations, including debt. SWEPCo and CLECO equally approve DHLC’s annual budget. The creditors of DHLC have no recourse to any AEP entity other than SWEPCo. As SWEPCo is the sole equity owner of DHLC, it receives 100% of the management fee earned by DHLC. In April 2020, SWEPCo and CLECO jointly filed a notification letter to the LPSC providing notice of the cessation of lignite mining. SWEPCo’s total billings from DHLC for the years ended December 31, 2024, 2023, and 2022 were not material. DHLC paid dividends of $1 million, $1 million, and $25 million to SWEPCo for the years ended December 31, 2024, 2023 and 2022, respectively. SWEPCo does not have the power to control decision making that significantly impacts the economic performance of DHLC because such power is shared with CLECO. As a result, SWEPCo is not required to consolidate DHLC as it is not the primary beneficiary, although it holds a significant variable interest in DHLC. SWEPCo’s equity investment in DHLC is included in Deferred Charges and Other Noncurrent Assets on SWEPCo’s balance sheets. SWEPCo’s investment in DHLC was: December 31, 2024 2023 As Reported on Maximum As Reported on Maximum (in millions) Capital Contribution from SWEPCo $ 7.6 $ 7.6 $ 7.6 $ 7.6 Retained Earnings 0.3 0.3 0.4 0.4 SWEPCo’s Share of Obligations — 15.6 — 19.2 Total Investment in DHLC $ 7.9 $ 23.5 $ 8.0 $ 27.2 OVEC (Applies to AEP and OPCo) AEP and several nonaffiliated utility companies jointly own OVEC. As of December 31, 2024, AEP’s ownership in OVEC was 43.47%. Parent owns 39.17% and OPCo owns 4.3%. APCo, I&M and OPCo are members to an intercompany power agreement. The Registrants’ power participation ratios are 15.69% for APCo, 7.85% for I&M and 19.93% for OPCo. Participants of this agreement are entitled to receive and are obligated to pay for all OVEC generating capacity, approximately 2,400 MWs, in proportion to their respective power participation ratios. The proceeds from the sale of power by OVEC are designed to be sufficient for OVEC to meet its operating expenses and fixed costs, including outstanding indebtedness, and provide a return on capital. The intercompany power agreement ends in June 2040. AEP and other nonaffiliated owners authorized environmental investments related to their ownership interests. OVEC financed capital expenditures in connection with the engineering and construction of FGD projects and the associated waste disposal landfills at its two generation plants. These environmental projects were funded through debt issuances. As of December 31, 2024 and 2023, OVEC’s outstanding indebtedness was approximately $997 million and $1.1 billion, respectively. Although they are not an obligor or guarantor, the Registrants’ are responsible for their respective ratio of OVEC’s outstanding debt through the intercompany power agreement. Principal and interest payments related to OVEC’s outstanding indebtedness are disclosed in accordance with the accounting guidance for “Commitments.” See the “Commitments” section of Note 6 for additional information. AEP is not required to consolidate OVEC as it is not the primary beneficiary, although AEP and OPCo each hold a significant variable interest in OVEC. Power to control decision making that significantly impacts the economic performance of OVEC is shared amongst the owners through their representation on the Board of Directors of OVEC and the representation of the sponsoring companies on the Operating Committee under the intercompany power agreement. AEP’s investment in OVEC was: December 31, 2024 2023 As Reported on Maximum As Reported on Maximum Exposure (in millions) Capital Contribution from AEP $ 4.4 $ 4.4 $ 4.4 $ 4.4 AEP’s Share of OVEC Debt (a) — 433.2 — 465.3 Total Investment in OVEC $ 4.4 $ 437.6 $ 4.4 $ 469.7 (a) Based on the Registrants’ power participation ratios, APCo, I&M and OPCo’s share of OVEC debt was $156 million, $78 million and $199 million as of December 31, 2024, respectively, and $168 million, $84 million and $213 million as of December 31, 2023, respectively. Power purchased by the Registrant Subsidiaries from OVEC is included in Purchased Electricity, Fuel and Other Consumables Used for Electric Generation and Purchased Electricity for Resale on the statements of income and is shown in the table below: Years Ended December 31, Company 2024 2023 2022 (in millions) APCo $ 133.6 $ 121.8 $ 119.3 I&M 66.8 60.9 59.7 OPCo 169.7 154.7 151.8 Significant Equity Method Investment in Unconsolidated Entities (Applies to AEP) For a discussion of the equity method of accounting, see the “Equity Method Investments in Unconsolidated Entities” section of Note 1. ETT ETT designs, acquires, constructs, owns and operates certain transmission facilities in ERCOT. BHE, a nonaffiliated entity, holds a 50% membership interest in ETT and AEP Transmission Holdco holds a 50% membership interest in ETT. As a result, AEP, through its wholly-owned subsidiary, holds a 50% membership interest in ETT. As of December 31, 2024 and 2023, AEP’s investment in ETT was $897 million and $811 million, respectively. AEP’s equity earnings associated with ET T were $86 million, $74 million and $74 million for the years ended December 31, 2024, 2023 and 2022, respectively.

PROPERTY, PLANT, AND EQUIPMENT

PROPERTY, PLANT, AND EQUIPMENT	12 Months Ended
	Dec. 31, 2024
Property, Plant and Equipment [Abstract]
PROPERTY, PLANT, AND EQUIPMENT	PROPERTY, PLANT AND EQUIPMENT The disclosures in this note apply to all Registrants unless indicated otherwise. Property, Plant and Equipment is shown functionally on the face of the balance sheets. The following tables include the total plant balances as of December 31, 2024 and 2023: December 31, 2024 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Regulated Property, Plant and Equipment Generation $ 24,694.5 (a) $ — $ — $ 7,272.6 $ 5,438.5 $ — $ 2,772.4 $ 5,287.5 (a) Transmission 38,871.9 7,546.2 14,913.4 5,001.5 1,957.8 3,663.9 1,345.3 2,863.8 Distribution 31,061.9 6,250.5 — 5,568.5 3,535.0 7,244.0 3,698.8 3,007.1 Other 6,544.9 1,172.9 515.9 1,023.9 948.3 1,245.3 546.8 682.7 CWIP 6,321.5 (a) 1,118.0 1,965.4 742.6 330.1 691.1 378.8 627.3 (a) Less: Accumulated Depreciation 25,794.0 2,045.7 1,578.5 6,030.9 4,607.0 2,883.0 2,214.7 3,048.5 Total Regulated Property, Plant and Equipment - Net 81,700.7 14,041.9 15,816.2 13,578.2 7,602.7 9,961.3 6,527.4 9,419.9 Nonregulated Property, Plant and Equipment - Net 714.9 1.6 0.3 34.3 76.6 9.8 4.9 26.2 Total Property, Plant and Equipment - Net $ 82,415.6 $ 14,043.5 $ 15,816.5 $ 13,612.5 $ 7,679.3 $ 9,971.1 $ 6,532.3 $ 9,446.1 December 31, 2023 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Regulated Property, Plant and Equipment Generation $ 23,862.7 (a) $ — $ — $ 7,041.3 $ 5,588.7 $ — $ 2,695.5 $ 4,790.7 (a) Transmission 35,903.6 6,812.6 13,723.9 4,711.8 1,906.4 3,395.1 1,228.3 2,660.6 Distribution 28,989.9 5,798.8 — 5,176.6 3,254.0 6,839.4 3,450.8 2,824.1 Other 5,986.1 1,142.9 501.2 943.7 856.8 1,114.4 502.7 544.1 CWIP 5,480.6 (a) 904.6 1,563.7 709.2 294.1 654.0 313.7 555.8 (a) Less: Accumulated Depreciation 24,093.8 1,886.7 1,291.4 5,684.0 4,353.7 2,712.7 2,083.6 2,840.8 Total Regulated Property, Plant and Equipment - Net 76,129.1 12,772.2 14,497.4 12,898.6 7,546.3 9,290.2 6,107.4 8,534.5 Nonregulated Property, Plant and Equipment - Net 564.3 1.8 0.3 32.9 82.7 9.7 4.9 23.9 Total Property, Plant and Equipment - Net $ 76,693.4 $ 12,774.0 $ 14,497.7 $ 12,931.5 $ 7,629.0 $ 9,299.9 $ 6,112.3 $ 8,558.4 (a) AEP and SWEPCo’s regulated generation and regulated CWIP include amounts related to SWEPCo’s Arkansas jurisdictional share of the Turk Plant. Depreciation, Depletion and Amortization The Registrants provide for depreciation of Property, Plant and Equipment, excluding coal-mining properties, on a straight-line basis over the estimated useful lives of property, generally using composite rates by functional class. The following tables provide total regulated annual composite depreciation rates and depreciable lives for the Registrants: AEP 2024 2023 2022 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 2.7% - 4.9% 20 - 162 2.7% - 4.7% 20 - 162 2.7% - 7.6% 20 - 132 Transmission 2.1% - 2.7% 15 - 79 2.0% - 2.7% 15 - 78 2.0% - 2.7% 24 - 75 Distribution 2.8% - 3.5% 7 - 85 2.9% - 3.6% 7 - 85 2.7% - 3.6% 7 - 78 Other 3.0% - 8.9% 5 - 75 3.8% - 9.1% 5 - 75 3.1% - 14.4% 5 - 75 AEP Texas 2024 2023 2022 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Transmission 2.2% 50 - 79 2.2% 50 - 75 2.2% 50 - 75 Distribution 2.8% 15 - 74 2.9% 7 - 70 2.9% 7 - 70 Other 5.9% 5 - 54 6.0% 5 - 50 6.2% 5 - 50 AEPTCo 2024 2023 2022 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Transmission 2.7% 24 - 78 2.6% 24 - 78 2.6% 24 - 75 Other 7.1% 5 - 58 7.0% 5 - 58 6.6% 5 - 56 APCo 2024 2023 2022 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 3.2% 35 - 162 3.3% 35 - 162 3.6% 35 - 118 Transmission 2.3% 15 - 78 2.3% 15 - 78 2.2% 24 - 75 Distribution 3.5% 12 - 60 3.6% 12 - 60 3.6% 12 - 57 Other 6.8% 5 - 55 7.4% 5 - 55 7.3% 5 - 55 I&M 2024 2023 2022 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 4.9% 20 - 132 4.7% 20 - 132 4.9% 20 - 132 Transmission 2.6% 44 - 67 2.5% 44 - 67 2.5% 44 - 67 Distribution 2.8% 15 - 76 2.9% 14 - 71 3.1% 14 - 71 Other 8.9% 5 - 45 9.1% 5 - 45 10.1% 5 - 45 OPCo 2024 2023 2022 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Transmission 2.3% 39 - 60 2.3% 39 - 60 2.3% 39 - 60 Distribution 3.1% 11 - 70 3.1% 11 - 70 2.7% 11 - 70 Other 5.9% 5 - 50 6.4% 5 - 50 6.1% 5 - 50 PSO 2024 2023 2022 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 3.3% 30 - 78 3.0% 25 - 75 3.1% 30 - 75 Transmission 2.6% 41 - 75 2.6% 41 - 75 2.5% 42 - 75 Distribution 2.8% 15 - 85 2.9% 15 - 85 2.9% 15 - 78 Other 6.6% 5 - 58 6.8% 5 - 58 6.8% 5 - 56 SWEPCo 2024 2023 2022 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 3.7% 30 - 65 2.9% 30 - 65 2.7% 30 - 65 Transmission 2.2% 46 - 70 2.2% 46 - 70 2.3% 44 - 70 Distribution 2.9% 7 - 75 2.9% 7 - 75 2.9% 15 - 75 Other 6.7% 5 - 58 8.5% 5 - 58 9.0% 5 - 57 The following table includes the nonregulated annual composite depreciation rate ranges and nonregulated depreciable life ranges for AEP. With the exception of I&M, the Registrants' depreciation rate ranges and depreciable life ranges are not meaningful for nonregulated property for 2024, 2023 and 2022. 2024 2023 2022 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 1.8% - 6.0% 39 - 61 4.8% - 6.7% 10 - 61 3.8% - 8.7% 3 - 61 Transmission NA NA 2.5% 62 2.8% 10 - 62 Distribution NA NA NA NA NA NA Other 9.7% 5 - 35 10.6% 5 - 35 25.2% 5 - 35 (a) I&M's annual composite depreciation rate for Generation property is 1.8% and the depreciable life is 39 years. NA Not applicable. For regulated operations, the composite depreciation rate generally includes a component for non-ARO removal costs, which is credited to Accumulated Depreciation and Amortization on the balance sheets. Actual removal costs incurred are charged to Accumulated Depreciation and Amortization. Any excess of accrued non-ARO removal costs over actual removal costs incurred is reclassified from Accumulated Depreciation and Amortization and reflected as a regulatory liability. For nonregulated operations, non-ARO removal costs are expensed as incurred. Asset Retirement Obligations (Applies to all Registrants except AEPTCo) Listed below are significant changes to the Registrants ARO balances as of December 31, 2024 and 2023: • In April 2024, the Federal EPA finalized revisions to the CCR Rule to expand the scope of the rule to include inactive impoundments at inactive facilities as well as to establish requirements for currently exempt solid waste management units that involve the direct placement of CCR on the land. In the second quarter of 2024, AEP evaluated the applicability of the rule to current and former plant sites and incurred ARO liabilities of $602 million and revised cash flow estimates by an additional $72 million based on initial cost estimates. See the “Federal EPA’s Revised CCR Rule” section of Note 6 for additional information. • In December 2024, I&M recorded a $176 million revision as a result of the completion of the latest Cook Plant nuclear decommissioning study. I&M's ARO related to nuclear decommissioning costs for the Cook Plant was $1.97 billion and $2.11 billion as of December 31, 2024 and 2023. As of December 31, 2024 and 2023, the fair value of I&M’s assets that are legally restricted for purposes of settling decommissioning liabilities totaled $4.03 billion and $3.51 billion, respectively. These assets are included in Spent Nuclear Fuel and Decommissioning Trusts on I&M’s balance sheets. The following is a reconciliation of the 2024 and 2023 aggregate carrying amounts of ARO by Registrant: Company ARO as of December 31, 2023 Accretion Liabilities Liabilities Revisions in ARO as of December 31, 2024 (in millions) AEP(b)(c)(d)(e)(f) $ 3,031.2 $ 140.1 $ 612.4 $ (102.4) $ (69.6) $ 3,611.7 AEP Texas (e) 4.5 0.2 — (0.8) — 3.9 APCo (b)(e)(f) 464.0 27.7 247.1 (18.1) 81.0 801.7 I&M (b)(c)(e) 2,106.0 80.2 85.7 (2.2) (175.9) 2,093.8 OPCo (b)(e) 2.1 1.4 52.9 (0.1) — 56.3 PSO (b)(e)(f) 84.2 5.8 33.7 (1.9) — 121.8 SWEPCo (b)(d)(e)(f) 281.6 16.2 30.2 (69.2) 19.9 278.7 Company ARO as of December 31, 2022 Accretion Liabilities Liabilities Revisions in ARO as of December 31, 2023 (in millions) AEP (b)(c)(d)(e)(f) $ 2,943.6 $ 116.3 $ 38.9 $ (130.6) $ 63.0 $ 3,031.2 AEP Texas (e) 4.5 0.2 — (0.3) 0.1 4.5 APCo (b)(e)(f) 427.7 16.8 16.1 (23.1) 26.5 464.0 I&M (b)(c)(e) 2,028.1 74.8 4.8 (3.7) 2.0 2,106.0 OPCo (e) 5.0 0.2 — (3.1) — 2.1 PSO (b)(e)(f) 75.7 4.7 5.8 (1.2) (0.8) 84.2 SWEPCo (b)(d)(e)(f) 280.9 13.7 7.5 (55.0) 34.5 281.6 (a) Unless discussed above, primarily related to ash ponds, landfills and mine reclamation, generally due to changes in estimated closure area, volumes and/or unit costs. (b) Includes ARO related to ash disposal facilities. (c) Includes ARO related to nuclear decommissioning costs for the Cook Plant. (d) Includes ARO related to Sabine and DHLC. (e) Includes ARO related to asbestos removal. (f) Includes ARO related to renewables. Allowance for Funds Used During Construction and Interest Capitalization The Registrants’ amounts of Allowance for Equity Funds Used During Construction are summarized in the following table: Years Ended December 31, Company 2024 2023 2022 (in millions) AEP $ 211.0 $ 174.9 $ 133.7 AEP Texas 45.9 28.4 19.7 AEPTCo 89.4 83.2 70.7 APCo 16.1 11.9 11.7 I&M 13.3 10.9 9.8 OPCo 23.4 17.1 13.9 PSO 7.4 8.4 1.5 SWEPCo 13.5 11.5 4.9 The Registrants’ amounts of allowance for borrowed funds used during construction, including capitalized interest, are summarized in the following table: Years Ended December 31, Company 2024 2023 2022 (in millions) AEP $ 129.8 $ 117.3 $ 63.0 AEP Texas 30.7 23.4 11.5 AEPTCo 33.7 31.4 22.4 APCo 10.5 14.1 6.5 I&M 9.2 7.7 5.7 OPCo 12.8 14.0 6.7 PSO 9.7 5.2 2.7 SWEPCo 15.1 9.8 4.3 Jointly-owned Electric Facilities (Applies to AEP, I&M, PSO and SWEPCo) The Registrants have electric facilities that are jointly-owned with affiliated and nonaffiliated companies. Using its own financing, each participating company is obligated to pay its share of the costs of these jointly-owned facilities in the same proportion as its ownership interest. Each Registrant’s proportionate share of the operating costs associated with these facilities is included in its statements of income and the investments and accumulated depreciation are reflected in its balance sheets under Property, Plant and Equipment as follows: Registrant’s Share as of December 31, 2024 Fuel Percent of Utility Plant Construction Accumulated (in millions) AEP Flint Creek Generating Station, Unit 1 (a) Coal 50.0 % $ 404.1 $ 3.4 $ 188.8 Turk Generating Plant (a) Coal 73.3 % 1,517.0 1.2 350.2 Total $ 1,921.1 $ 4.6 $ 539.0 I&M Rockport Generating Plant (b)(c) Coal 50.0 % $ 1,345.0 $ 10.9 $ 1,181.8 PSO North Central Wind Energy Facilities (d)(e) Wind 45.5 % $ 912.3 $ 1.0 $ 77.6 SWEPCo Flint Creek Generating Station, Unit 1 (a) Coal 50.0 % $ 404.1 $ 3.4 $ 188.8 Turk Generating Plant (a) Coal 73.3 % 1,517.0 1.2 350.2 North Central Wind Energy Facilities (d)(e) Wind 54.5 % 1,093.5 1.2 98.1 Total $ 3,014.6 $ 5.8 $ 637.1 Registrant’s Share as of December 31, 2023 Fuel Percent of Utility Plant Construction Accumulated (in millions) AEP Flint Creek Generating Station, Unit 1 (a) Coal 50.0 % $ 402.8 $ 1.6 $ 167.5 Turk Generating Plant (a) Coal 73.3 % 1,504.0 10.1 323.3 Total $ 1,906.8 $ 11.7 $ 490.8 I&M Rockport Generating Plant (b)(c) Coal 50.0 % $ 1,341.4 $ 7.9 $ 1,018.9 PSO North Central Wind Energy Facilities (d)(e) Wind 45.5 % $ 906.3 $ 2.4 $ 54.1 SWEPCo Flint Creek Generating Station, Unit 1 (a) Coal 50.0 % $ 402.8 $ 1.6 $ 167.5 Turk Generating Plant (a) Coal 73.3 % 1,504.0 10.1 323.3 North Central Wind Energy Facilities (d)(e) Wind 54.5 % 1,086.3 2.9 67.9 Total $ 2,993.1 $ 14.6 $ 558.7 (a) Operated by SWEPCo. (b) Operated by I&M. (c) AEGCo owns 50%. (d) Operated by PSO. (e)

REVENUE FROM CONTRACTS WITH CUS

REVENUE FROM CONTRACTS WITH CUSTOMERS	12 Months Ended
	Dec. 31, 2024
Revenue from Contract with Customer [Abstract]
REVENUE FROM CONTRACTS WITH CUSTOMERS	REVENUE FROM CONTRACTS WITH CUSTOMERS The disclosures in this note apply to all Registrants, unless indicated otherwise. Disaggregated Revenues from Contracts with Customers The table below represents AEP’s reportable segment revenues from contracts with customers, net of respective provisions for refund, by type of revenue: Year Ended December 31, 2024 VIU T&D AEPTHCo G&M Corporate and Other Reconciling Adjustments AEP Consolidated (in millions) Retail Revenues: Residential Revenues $ 4,561.9 $ 2,755.7 $ — $ — $ — $ — $ 7,317.6 Commercial Revenues 2,731.4 1,567.4 — — — — 4,298.8 Industrial Revenues (a) 2,659.0 515.2 — — — (0.9) 3,173.3 Other Retail Revenues 231.5 56.4 — — — — 287.9 Total Retail Revenues 10,183.8 4,894.7 — — — (0.9) 15,077.6 Wholesale and Competitive Retail Revenues: Generation Revenues 747.8 — — 103.2 — — 851.0 Transmission Revenues (b) 483.3 769.5 1,978.3 — — (1,620.1) 1,611.0 Renewable Generation Revenues (a) — — — 23.2 — (4.4) 18.8 Retail, Trading and Marketing Revenues (c) — — — 2,080.5 1.3 (96.4) 1,985.4 Total Wholesale and Competitive Retail Revenues 1,231.1 769.5 1,978.3 2,206.9 1.3 (1,720.9) 4,466.2 Other Revenues from Contracts with Customers (d) 227.3 197.5 25.8 4.1 184.7 (213.5) 425.9 Total Revenues from Contracts with Customers 11,642.2 5,861.7 2,004.1 2,211.0 186.0 (1,935.3) 19,969.7 Other Revenues: Alternative Revenue Programs (e) (22.0) 26.0 (53.3) — — (29.8) (79.1) Other Revenues (a) (f) (23.6) 20.0 — (165.6) (2.9) 2.8 (169.3) Total Other Revenues (45.6) 46.0 (53.3) (165.6) (2.9) (27.0) (248.4) Total Revenues $ 11,596.6 $ 5,907.7 $ 1,950.8 $ 2,045.4 $ 183.1 $ (1,962.3) $ 19,721.3 (a) Amounts include affiliated and nonaffiliated revenues. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $1.6 billion and Vertically Integrated Utilities was $177 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $96 million. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $137 million. The remaining affiliated amounts were immaterial. (e) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. (f) Generation & Marketing includes economic hedge activity. Year Ended December 31, 2023 VIU T&D AEPTHCo G&M Corporate and Other Reconciling Adjustments AEP Consolidated (in millions) Retail Revenues: Residential Revenues $ 4,479.3 $ 2,609.1 $ — $ — $ — $ — $ 7,088.4 Commercial Revenues 2,678.8 1,497.2 — — — — 4,176.0 Industrial Revenues (a) 2,748.2 642.1 — — — (0.9) 3,389.4 Other Retail Revenues 242.7 50.7 — — — — 293.4 Total Retail Revenues 10,149.0 4,799.1 — — — (0.9) 14,947.2 Wholesale and Competitive Retail Revenues: Generation Revenues 662.5 — — 111.3 — — 773.8 Transmission Revenues (b) 444.0 701.6 1,748.9 — — (1,418.3) 1,476.2 Renewable Generation Revenues (a) — — — 80.6 — (6.7) 73.9 Retail, Trading and Marketing Revenues (c) — — — 1,836.2 0.6 (82.2) 1,754.6 Total Wholesale and Competitive Retail Revenues 1,106.5 701.6 1,748.9 2,028.1 0.6 (1,507.2) 4,078.5 Other Revenues from Contracts with Customers (d) 204.4 208.1 16.8 8.6 151.5 (160.3) 429.1 Total Revenues from Contracts with Customers 11,459.9 5,708.8 1,765.7 2,036.7 152.1 (1,668.4) 19,454.8 Other Revenues: Alternative Revenue Programs (e) (35.0) (19.5) (37.1) — — (25.5) (117.1) Other Revenues (a) (f) 24.6 24.0 (0.1) (404.5) 15.9 (15.3) (355.4) Total Other Revenues (10.4) 4.5 (37.2) (404.5) 15.9 (40.8) (472.5) Total Revenues $ 11,449.5 $ 5,713.3 $ 1,728.5 $ 1,632.2 $ 168.0 $ (1,709.2) $ 18,982.3 (a) Amounts include affiliated and nonaffiliated revenues. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $1.5 billion and Vertically Integrated Utilities was $205 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $82 million. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $100 million. The remaining affiliated amounts were immaterial. (e) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. (f) Generation & Marketing includes economic hedge activity. Year Ended December 31, 2022 VIU T&D AEPTHCo G&M Corporate and Other Reconciling Adjustments AEP Consolidated (in millions) Retail Revenues: Residential Revenues $ 4,498.6 $ 2,497.3 $ — $ — $ — $ — $ 6,995.9 Commercial Revenues 2,576.5 1,365.2 — — — — 3,941.7 Industrial Revenues (a) 2,543.8 711.3 — — — (0.9) 3,254.2 Other Retail Revenues 212.2 49.1 — — — — 261.3 Total Retail Revenues 9,831.1 4,622.9 — — — (0.9) 14,453.1 Wholesale and Competitive Retail Revenues: Generation Revenues 958.3 — — 271.2 — — 1,229.5 Transmission Revenues (b) 442.8 650.0 1,700.6 — — (1,413.2) 1,380.2 Renewable Generation Revenues (a) — — — 129.1 — (8.0) 121.1 Retail, Trading and Marketing Revenues (a) — — — 1,713.2 6.9 (10.1) 1,710.0 Total Wholesale and Competitive Retail Revenues 1,401.1 650.0 1,700.6 2,113.5 6.9 (1,431.3) 4,440.8 Other Revenues from Contracts with Customers (c) 241.1 247.3 8.2 12.1 93.9 (104.8) 497.8 Total Revenues from Contracts with Customers 11,473.3 5,520.2 1,708.8 2,125.6 100.8 (1,537.0) 19,391.7 Other Revenues: Alternative Revenue Programs (d) 3.8 (26.8) (31.8) — — (57.7) (112.5) Other Revenues (a) (e) 0.4 18.6 — 341.3 9.1 (9.1) 360.3 Total Other Revenues 4.2 (8.2) (31.8) 341.3 9.1 (66.8) 247.8 Total Revenues $ 11,477.5 $ 5,512.0 $ 1,677.0 $ 2,466.9 $ 109.9 $ (1,603.8) $ 19,639.5 (a) Amounts include affiliated and nonaffiliated revenues. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $1.3 billion. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $59 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. The table below represents revenues from contracts with customers, net of respective provisions for refund, by type of revenue for the Registrant Subsidiaries: Year Ended December 31, 2024 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 724.8 $ — $ 1,772.0 $ 847.2 $ 2,030.8 $ 799.6 $ 726.4 Commercial Revenues 466.6 — 764.4 605.1 1,100.7 509.5 558.1 Industrial Revenues (a) 141.5 — 813.1 595.6 373.7 349.1 367.9 Other Retail Revenues 38.9 — 113.0 5.1 17.4 100.5 9.2 Total Retail Revenues 1,371.8 — 3,462.5 2,053.0 3,522.6 1,758.7 1,661.6 Wholesale Revenues: Generation Revenues (b) — — 304.5 393.9 — 9.4 176.9 Transmission Revenues (c) 673.2 1,924.6 184.6 40.6 96.3 42.1 172.1 Total Wholesale Revenues 673.2 1,924.6 489.1 434.5 96.3 51.5 349.0 Other Revenues from Contracts with Customers (d) 35.8 25.9 87.2 116.0 162.0 39.3 32.7 Total Revenues from Contracts with Customers 2,080.8 1,950.5 4,038.8 2,603.5 3,780.9 1,849.5 2,043.3 Other Revenues: Alternative Revenue Programs (e) (0.9) (59.6) (6.4) (7.6) 26.9 (3.1) (7.0) Other Revenues (a) — — 0.2 (23.9) 20.0 — — Total Other Revenues (0.9) (59.6) (6.2) (31.5) 46.9 (3.1) (7.0) Total Revenues $ 2,079.9 $ 1,890.9 $ 4,032.6 $ 2,572.0 $ 3,827.8 $ 1,846.4 $ 2,036.3 (a) Amounts include affiliated and nonaffiliated revenues. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $159 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $1.6 billion, APCo was $87 million and SWEPCo was $65 million. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $75 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (e) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. Year Ended December 31, 2023 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 655.5 $ — $ 1,612.9 $ 841.9 $ 1,953.7 $ 831.2 $ 799.5 Commercial Revenues 415.2 — 699.6 575.2 1,082.0 538.8 609.4 Industrial Revenues (a) 145.0 — 778.4 614.2 497.1 423.1 415.9 Other Retail Revenues 35.5 — 106.3 5.0 15.1 112.8 10.1 Total Retail Revenues 1,251.2 — 3,197.2 2,036.3 3,547.9 1,905.9 1,834.9 Wholesale Revenues: Generation Revenues (b) — — 288.2 327.1 — 11.7 176.9 Transmission Revenues (c) 619.0 1,703.9 181.0 38.6 82.6 37.5 150.8 Total Wholesale Revenues 619.0 1,703.9 469.2 365.7 82.6 49.2 327.7 Other Revenues from Contracts with Customers (d) 35.9 16.7 74.2 120.3 172.3 21.5 29.5 Total Revenues from Contracts with Customers 1,906.1 1,720.6 3,740.6 2,522.3 3,802.8 1,976.6 2,192.1 Other Revenues: Alternative Revenue Programs (e) (4.2) (48.6) (20.1) (10.9) (15.3) 0.5 (9.4) Other Revenues (a) — — 0.2 24.5 23.9 (0.1) 0.1 Total Other Revenues (4.2) (48.6) (19.9) 13.6 8.6 0.4 (9.3) Total Revenues $ 1,901.9 $ 1,672.0 $ 3,720.7 $ 2,535.9 $ 3,811.4 $ 1,977.0 $ 2,182.8 (a) Amounts include affiliated and nonaffiliated revenues. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $159 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $1.4 billion, APCo was $93 million and SWEPCo was $73 million. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $68 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (e) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. Year Ended December 31, 2022 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 667.2 $ — $ 1,558.7 $ 852.4 $ 1,830.2 $ 816.3 $ 820.7 Commercial Revenues 417.5 — 643.4 550.2 947.7 489.2 612.3 Industrial Revenues (a) 139.6 — 664.0 602.9 571.7 372.5 393.5 Other Retail Revenues 35.3 — 87.1 5.0 13.9 102.9 10.1 Total Retail Revenues 1,259.6 — 2,953.2 2,010.5 3,363.5 1,780.9 1,836.6 Wholesale Revenues: Generation Revenues (b) — — 299.9 490.0 — 26.5 273.2 Transmission Revenues (c) 563.8 1,643.5 167.0 36.8 86.2 39.2 148.7 Total Wholesale Revenues 563.8 1,643.5 466.9 526.8 86.2 65.7 421.9 Other Revenues from Contracts with Customers (d) 24.6 8.2 100.6 122.4 222.4 29.1 24.7 Total Revenues from Contracts with Customers 1,848.0 1,651.7 3,520.7 2,659.7 3,672.1 1,875.7 2,283.2 Other Revenues: Alternative Revenue Programs (e) (1.2) (27.2) (1.3) 10.0 (25.6) (1.0) 1.2 Other Revenues (a) — — 0.5 (0.1) 18.6 — — Total Other Revenues (1.2) (27.2) (0.8) 9.9 (7.0) (1.0) 1.2 Total Revenues $ 1,846.8 $ 1,624.5 $ 3,519.9 $ 2,669.6 $ 3,665.1 $ 1,874.7 $ 2,284.4 (a) Amounts include affiliated and nonaffiliated revenues. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $170 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $1.3 billion, APCo was $78 million and SWEPCo was $51 million. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $62 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (e) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. Performance Obligations AEP has performance obligations as part of its normal course of business. A performance obligation is a promise to transfer a distinct good or service, or a series of distinct goods or services that are substantially the same and have the same pattern of transfer to a customer. The invoice practical expedient within the accounting guidance for “Revenue from Contracts with Customers” allows for the recognition of revenue from performance obligations in the amount of consideration to which there is a right to invoice the customer and when the amount for which there is a right to invoice corresponds directly to the value transferred to the customer. The purpose of the invoice practical expedient is to depict an entity’s measure of progress toward completion of the performance obligation within a contract and can only be applied to performance obligations that are satisfied over time and when the invoice is representative of services provided to date. AEP subsidiaries elected to apply the invoice practical expedient to recognize revenue for performance obligations satisfied over time as the invoices from the respective revenue streams are representative of services or goods provided to date to the customer. Performance obligations for AEP’s subsidiaries are summarized as follows: Retail Revenues AEP’s subsidiaries within the Vertically Integrated Utilities and Transmission and Distribution Utilities segments have performance obligations to generate, transmit and distribute electricity for sale to rate-regulated retail customers. The performance obligation to deliver electricity is satisfied over time as the customer simultaneously receives and consumes the benefits provided. Revenues are variable as they are subject to the customer’s usage requirements. Rate-regulated retail customers typically have the right to discontinue receiving service at will, therefore these contracts between AEP’s subsidiaries and their customers for rate-regulated services are generally limited to the services requested and received to date for such arrangements. Retail customers are generally billed on a monthly basis, and payment is typically due within 15 to 20 days after the issuance of the invoice. Payments from REPs are due to AEP Texas within 35 days. Wholesale Revenues - Generation AEP’s subsidiaries within the Vertically Integrated Utilities and Generation & Marketing segments have performance obligations to sell electricity to wholesale customers from generation assets in PJM, SPP and ERCOT. The performance obligation to deliver electricity from generation assets is satisfied over time as the customer simultaneously receives and consumes the benefits provided. Wholesale generation revenues are variable as they are subject to the customer’s usage requirements. AEP’s subsidiaries within the Vertically Integrated Utilities and Generation & Marketing segments also have performance obligations to stand ready in order to promote grid reliability. Stand ready services are sold into PJM’s RPM capacity market. RPM entails a base auction and at least three incremental auctions for a specific PJM delivery year, with the incremental auctions spanning three years. The performance obligation to stand ready is satisfied over time and the consideration for which is variable until the occurrence of the final incremental auction, at which point the performance obligation becomes fixed. Payments from the RTO for stand ready services are typically received within one week from the issuance of the invoice, which is typically issued weekly. Gross margin resulting from generation sales within the Vertically Integrated Utilities segment are primarily subject to margin sharing agreements with customers and vary by state, where the revenues are reflected gross in the disaggregated revenues tables above. APCo has a performance obligation to supply wholesale electricity to KGPCo through a PPA. The FERC regulates the cost-based wholesale power transactions between APCo and KGPCo. The purchased power agreement includes a component for the recovery of transmission costs under the FERC OATT. The transmission cost component of purchased power is cost-based and regulated by the Tennessee Regulatory Authority. APCo’s performance obligation under the purchased power agreement is satisfied over time as KGPCo simultaneously receives and consumes the wholesale electricity. APCo’s revenues from the purchased power agreement are presented within the Generation Revenues line in the disaggregated revenues tables above. Wholesale Revenues - Transmission AEP’s subsidiaries within the Vertically Integrated Utilities, Transmission and Distribution Utilities and AEP Transmission Holdco segments have performance obligations to transmit electricity to wholesale customers through assets owned and operated by AEP subsidiaries. The performance obligation to provide transmission services in PJM, SPP and ERCOT is partially fixed for a period of one year or less. Payments from the RTO for transmission services are typically received within one week from the issuance of the invoice, which is issued monthly for SPP and ERCOT and weekly for PJM. AEP subsidiaries within the PJM and SPP regions collect revenues through transmission formula rates. The FERC-approved rates establish the annual transmission revenue requirement (ATRR) and transmission service rates for transmission owners. The formula rates establish rates for a one year period and also include a true-up calculation for the prior year’s billings, allowing for over/under-recovery of the transmission owner’s ATRR. The annual true-ups meet the definition of alternative revenues in accordance with the accounting guidance for “Regulated Operations,” and are therefore presented as such in the disaggregated revenues tables above. AEP subsidiaries within the ERCOT region collect revenues through a combination of base rates and interim Transmission Costs of Services filings that are approved by the PUCT. The AEP East Companies are parties to the TA, which defines how transmission costs are allocated among the AEP East Companies on a 12-month average coincident peak basis. PSO, SWEPCo and AEPSC are parties to the TCA by and among PSO, SWEPCo and AEPSC, in connection with the operation of the transmission assets of the two AEP utility subsidiaries. AEPTCo is a transmission owner within the PJM and SPP regions providing transmission services to affiliates in accordance with the OATT, TA and TCA. Affiliate revenues as a result of the respective TA and the TCA are reflected as Transmission Revenues in the disaggregated revenues tables above. Marketing, Competitive Retail and Renewable Revenues AEP’s subsidiaries within the Generation & Marketing segment have performance obligations to deliver electricity to competitive retail and wholesale customers. Performance obligations for marketing, competitive retail and renewable offtake sales are satisfied over time as the customer simultaneously receives and consumes the benefits provided. Revenues are primarily variable as they are subject to customer’s usage requirements; however, certain contracts mandate a delivery of a set quantity of electricity at a predetermined price, resulting in a fixed performance obligation. Payment terms under marketing arrangements typically follow standard Edison Electric Institute and International Swaps and Derivatives Association terms, which call for payment in 20 days. Payments for competitive retail and offtake arrangements for renewable assets range from 15 to 60 days and are dependent on the product sold, location and the creditworthiness of customer. Invoices for marketing arrangements, competitive retail and offtake arrangements for renewable assets are issued monthly. Fixed Performance Obligations (Applies to AEP, APCo and I&M) The following table represents the Registrants’ remaining fixed performance obligations satisfied over time as of December 31, 2024. Fixed performance obligations primarily include electricity sales for fixed amounts of energy and stand ready services into PJM’s RPM market. The Registrants elected to apply the exemption to not disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less. Due to the annual establishment of revenue requirements, transmission revenues are excluded from the table below. The Registrant Subsidiaries amounts shown in the table below include affiliated and nonaffiliated revenues. Company 2025 2026-2027 2028-2029 After 2029 Total (in millions) AEP $ 93.7 $ 143.0 $ 48.8 $ 16.1 $ 301.6 APCo 16.1 32.1 23.1 11.6 82.9 I&M 4.4 8.8 6.8 2.4 22.4 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 any material contract assets as of December 31, 2024 and 2023. When the Registrants receive consideration, or such consideration is unconditionally due from a customer prior to transferring goods or services to the customer under the terms of a sales contract, they recognize a contract liability on the balance sheet in the amount of that consideration. Revenue for such consideration is subsequently recognized in the period or periods in which the remaining performance obligations in the contract are satisfied. The Registrants’ contract liabilities typically arise from services provided under joint use agreements for utility poles. The Registrants did not have any material contract liabilities as of December 31, 2024 and 2023. Accounts Receivable from Contracts with Customers Accounts receivable from contracts with customers are presented on the Registrants’ balance sheets within the Accounts Receivable - Customers line item. The Registrants’ balances for receivables from contracts that are not recognized in accordance with the accounting guidance for “Revenue from Contracts with Customers” included in Accounts Receivable - Customers were not material as of December 31, 2024 and 2023. See “Securitized Accounts Receivable - AEP Credit” section of Note 15 for additional information. The following table represents the amount of affiliated accounts receivable from contracts with customers included in Accounts Receivable - Affiliated Companies on the Registrant Subsidiaries’ balance sheets: Years Ended December 31, AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) 2024 $ — $ 131.6 $ 83.7 $ 55.0 $ 63.6 $ 13.0 $ 21.4 2023 — 123.2 71.7 44.0 70.1 12.4 27.4 Contract Costs Contract costs to obtain or fulfill a contract for AEP subsidiaries within the Generation & Marketing segment are accounted for under the guidance for “Other Assets and Deferred Costs” and presented as a single asset and are neither bifurcated nor reclassified between current and noncurrent assets on the Registrants’ balance sheets. Contract costs to acquire a contract are amortized in a manner consistent with the transfer of goods or services to the customer in Other Operation on the Registrants’ income statements. The Registrants did not have material contract costs as of December 31, 2024 and 2023.

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	12 Months Ended
	Dec. 31, 2024
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	SUBSEQUENT EVENTS Noncontrolling Interest in OHTCo and IMTCo (Applies to AEP and AEPTCo)

SCHEDULE I - CONDENSED FINANCIA

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY	12 Months Ended
	Dec. 31, 2024
Condensed Financial Information Disclosure [Abstract]
SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY	SCHEDULE I AMERICAN ELECTRIC POWER COMPANY, INC. (Parent) CONDENSED FINANCIAL INFORMATION CONDENSED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME For the Years Ended December 31, 2024, 2023 and 2022 (in millions, except per-share and share amounts) Years Ended December 31, 2024 2023 2022 REVENUES Revenues $ 5.5 $ 5.1 $ 5.1 TOTAL REVENUES 5.5 5.1 5.1 EXPENSES Other Operation 66.0 16.7 84.9 Loss on the Expected Sale of the Kentucky Operations — — 363.3 Depreciation and Amortization 0.6 0.5 0.4 Amortization of KPCo Basis Difference (21.4) (16.5) — TOTAL EXPENSES 45.2 0.7 448.6 OPERATING INCOME (LOSS) (39.7) 4.4 (443.5) Other Income (Expense): Interest Income 107.9 181.0 80.3 Interest Expense (531.8) (526.3) (275.5) LOSS BEFORE INCOME TAX BENEFIT AND EQUITY EARNINGS (463.6) (340.9) (638.7) Income Tax Benefit (150.5) (80.8) (136.3) Equity Earnings of Unconsolidated Subsidiaries 3,280.2 2,468.2 2,809.6 NET INCOME 2,967.1 2,208.1 2,307.2 Other Comprehensive Income (Loss) 52.4 (139.2) (101.1) TOTAL COMPREHENSIVE INCOME $ 3,019.5 $ 2,068.9 $ 2,206.1 WEIGHTED AVERAGE NUMBER OF BASIC AEP COMMON SHARES OUTSTANDING 530,092,672 518,903,682 511,841,946 TOTAL BASIC EARNINGS PER SHARE ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS $ 5.60 $ 4.26 $ 4.51 WEIGHTED AVERAGE NUMBER OF DILUTED AEP COMMON SHARES OUTSTANDING 531,337,703 520,206,258 513,484,609 TOTAL DILUTED EARNINGS PER SHARE ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS $ 5.58 $ 4.24 $ 4.49 See Condensed Notes to Condensed Financial Information beginning on page S- 6 . SCHEDULE I AMERICAN ELECTRIC POWER COMPANY, INC. (Parent) CONDENSED FINANCIAL INFORMATION CONDENSED BALANCE SHEETS ASSETS December 31, 2024 and 2023 (in millions) December 31, 2024 2023 CURRENT ASSETS Cash and Cash Equivalents $ 87.5 $ 197.8 Other Temporary Investments 2.9 2.6 Advances to Affiliates 1,944.6 2,004.5 Accounts Receivable: Affiliated Companies 32.5 47.7 General — 2.7 Total Accounts Receivable 32.5 50.4 Accrued Tax Benefits 93.7 77.7 Prepayments and Other Current Assets 11.6 11.6 TOTAL CURRENT ASSETS 2,172.8 2,344.6 PROPERTY, PLANT AND EQUIPMENT General 3.2 3.1 Total Property, Plant and Equipment 3.2 3.1 Accumulated Depreciation, Depletion and Amortization 1.7 1.4 TOTAL PROPERTY, PLANT AND EQUIPMENT – NET 1.5 1.7 OTHER NONCURRENT ASSETS Investments in Unconsolidated Subsidiaries 35,306.2 33,598.6 Affiliated Notes Receivable 105.0 295.0 Deferred Charges and Other Noncurrent Assets 184.6 137.0 TOTAL OTHER NONCURRENT ASSETS 35,595.8 34,030.6 TOTAL ASSETS $ 37,770.1 $ 36,376.9 See Condensed Notes to Condensed Financial Information beginning on page S- 6 . SCHEDULE I AMERICAN ELECTRIC POWER COMPANY, INC. (Parent) CONDENSED FINANCIAL INFORMATION CONDENSED BALANCE SHEETS LIABILITIES AND EQUITY December 31, 2024 and 2023 (dollars in millions) December 31, 2024 2023 CURRENT LIABILITIES Advances from Affiliates $ 506.6 $ 728.3 Accounts Payable: General 4.7 11.1 Affiliated Companies 2.2 12.3 Short-term Debt 1,618.3 1,937.9 Long-term Debt Due Within One Year – Nonaffiliated 1,281.5 1,104.0 Other Current Liabilities 202.4 137.7 TOTAL CURRENT LIABILITIES 3,615.7 3,931.3 NONCURRENT LIABILITIES Long-term Debt – Nonaffiliated 7,124.3 7,086.9 Deferred Credits and Other Noncurrent Liabilities 48.5 69.5 TOTAL NONCURRENT LIABILITIES 7,172.8 7,156.4 TOTAL LIABILITIES 10,788.5 11,087.7 MEZZANINE EQUITY Contingently Redeemable Performance Share Awards 37.8 42.5 COMMON SHAREHOLDERS’ EQUITY Common Stock – Par Value – $6.50 Per Share: 2024 2023 Shares Authorized 600,000,000 600,000,000 Shares Issued 534,094,530 527,369,157 (1,186,815 and 1,184,572 Shares were Held in Treasury as of December 31, 2024 and 2023, Respectively) 3,471.6 3,427.9 Paid-in Capital 9,606.1 9,073.9 Retained Earnings 13,869.2 12,800.4 Accumulated Other Comprehensive Income (Loss) (3.1) (55.5) TOTAL AEP COMMON SHAREHOLDERS’ EQUITY 26,943.8 25,246.7 TOTAL LIABILITIES, MEZZANINE EQUITY AND TOTAL EQUITY $ 37,770.1 $ 36,376.9 See Condensed Notes to Condensed Financial Information beginning on page S- 6 . SCHEDULE I AMERICAN ELECTRIC POWER COMPANY, INC. (Parent) CONDENSED FINANCIAL INFORMATION CONDENSED STATEMENTS OF CASH FLOWS For the Years Ended December 31, 2024, 2023 and 2022 (in millions) Years Ended December 31, 2024 2023 2022 OPERATING ACTIVITIES Net Income $ 2,967.1 $ 2,208.1 $ 2,307.2 Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities: Depreciation and Amortization 0.6 0.5 0.4 Amortization of KPCo Basis Difference (21.4) (16.5) — Deferred Income Taxes (53.3) 59.7 (63.3) Loss on the Expected Sale of the Kentucky Operations — — 363.3 Equity Earnings of Unconsolidated Subsidiaries (3,280.2) (2,468.2) (2,809.6) Cash Dividends Received from Unconsolidated Subsidiaries 1,143.4 686.3 603.9 Change in Other Noncurrent Assets 4.9 (28.4) (5.0) Change in Other Noncurrent Liabilities 70.8 92.3 83.5 Changes in Certain Components of Working Capital: Accounts Receivable, Net 17.9 28.7 (61.0) Accounts Payable (16.5) (15.9) 1.1 Other Current Assets — (3.6) (6.0) Other Current Liabilities 55.3 (14.5) (76.6) Net Cash Flows from Operating Activities 888.6 528.5 337.9 INVESTING ACTIVITIES Construction Expenditures (0.6) (0.8) (0.7) Change in Advances to Affiliates, Net 59.9 2,007.6 (1,411.3) Capital Contributions to Unconsolidated Subsidiaries (399.9) (789.9) (568.3) Return of Capital Contributions from Unconsolidated Subsidiaries 898.9 56.6 24.5 Issuance of Notes Receivable to Unconsolidated Subsidiaries — (210.0) (20.0) Repayment of Notes Receivable from Unconsolidated Subsidiaries 190.0 — — Other Investing Activities — — (0.2) Net Cash Flows from (Used for) Investing Activities 748.3 1,063.5 (1,976.0) FINANCING ACTIVITIES Issuance of Common Stock, Net 552.1 999.6 826.5 Issuance of Long-term Debt 1,285.4 1,829.8 986.6 Issuance of Short-term Debt with Original Maturities Greater Than 90 Days 723.8 1,069.9 833.9 Change in Short-term Debt with Original Maturities Less Than 90 Day, Net (172.3) (1,365.4) 1,650.4 Retirement of Long-term Debt (1,104.0) (1,050.0) (300.0) Change in Advances from Affiliates, Net (221.7) (191.6) 336.9 Redemption of Short-term Debt with Original Maturities Greater Than 90 Days (871.1) (1,128.8) (986.1) Dividends Paid on Common Stock (1,898.3) (1,752.3) (1,628.7) Other Financing Activities (41.1) (59.6) (74.5) Net Cash Flows from (Used for) Financing Activities (1,747.2) (1,648.4) 1,645.0 Net Increase (Decrease) in Cash and Cash Equivalents (110.3) (56.4) 6.9 Cash and Cash Equivalents at Beginning of Period 197.8 254.2 247.3 Cash and Cash Equivalents at End of Period $ 87.5 $ 197.8 $ 254.2 See Condensed Notes to Condensed Financial Information beginning on page S- 6 . SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Basis of Presentation The condensed financial information of Parent is required as a result of the restricted net assets of AEP consolidated subsidiaries exceeding 25% of AEP consolidated net assets as of December 31, 2024. Parent is a public utility holding company that owns all of the outstanding common stock of its public utility subsidiaries and varying percentages of other subsidiaries, including joint ventures and equity investments. The primary source of income for Parent is equity in its subsidiaries’ earnings. Its major source of cash is dividends from the subsidiaries, which are evaluated for cash flow presentation based on the nature of the distribution. Parent borrows the funds for the money pool that is used by the subsidiaries for their short-term cash needs. Parent financial statements should be read in conjunction with the AEP consolidated financial statements and the accompanying notes thereto. For purposes of these condensed financial statements, AEP wholly-owned and majority-owned subsidiaries are recorded based upon its proportionate share of the subsidiaries’ net assets (similar to presenting them on the equity method). Income Taxes Parent files a consolidated federal income tax return with its subsidiaries. The benefit of current tax loss of the parent company (Parent Company Loss Benefit) to the AEP System subsidiaries is accounted for as an allocation through equity. The consolidated NOL of the AEP System is allocated to each company in the consolidated group with taxable loss. With the exception of the allocation of the consolidated AEP System NOL, Parent Company Loss Benefit and general business tax credits, the method of allocation reflects a separate return result for each company in the consolidated group. COMMITMENTS, GUARANTEES AND CONTINGENCIES FINANCING ACTIVITIES The following details long-term debt outstanding as of December 31, 2024 and 2023: Long-term Debt Weighted-Average Interest Rate Ranges as of Outstanding as of Interest Rate as of December 31, December 31, Type of Debt Maturity December 31, 2024 2024 2023 2024 2023 (in millions) Senior Unsecured Notes 2025-2050 4.29% 1.00%-5.95% 1.00%-5.95% $ 5,290.0 $ 5,265.0 Pollution Control Bonds 2026-2029 (a) 3.12% 2.40%-3.75% 1.90%-2.60% 536.8 537.8 Junior Subordinated Notes 2025-2027 5.67% 3.88%-7.05% 2.03%-5.70% 2,579.0 2,388.1 Total Long-term Debt Outstanding 8,405.8 8,190.9 Long-term Debt Due Within One Year 1,281.5 1,104.0 Long-term Debt $ 7,124.3 $ 7,086.9 (a) Certain Pollution Control Bonds are subject to redemption earlier than the maturity date. Long-term debt outstanding as of December 31, 2024 is payable as follows: 2025 2026 2027 2028 2029 After 2029 Total (in millions) Principal Amount (a) $ 1,281.5 $ 50.0 $ 1,758.3 $ 930.4 $ 1,694.5 $ 2,750.0 $ 8,464.7 Unamortized Discount, Net and Debt Issuance Costs (58.9) Total Long-term Debt Outstanding $ 8,405.8 (a) Amounts reflect the impact of fair value hedge accounting. See “Accounting for Fair Value Hedging Strategies” section of Note 10 included in the 2024 Annual Report for additional information. Short-term Debt Parent’s outstanding short-term debt was as follows: December 31, 2024 December 31, 2023 Type of Debt Outstanding Weighted-Average Outstanding Weighted-Average (in millions) (in millions) Commercial Paper $ 1,618.3 4.70 % $ 1,937.9 5.69 % Total Short-term Debt $ 1,618.3 $ 1,937.9 RELATED PARTY TRANSACTIONS Payments on Behalf of Subsidiaries Due to occasional time sensitivity and complexity of payments, Parent makes certain insurance, tax and benefit payments on behalf of subsidiary companies. Parent is then fully reimbursed by the subsidiary companies. Short-term Lending to Subsidiaries Parent uses a commercial paper program to meet the short-term borrowing needs of subsidiaries. The program is used to fund both a Utility Money Pool, which funds the utility subsidiaries, and a Nonutility Money Pool, which funds certain nonutility subsidiaries. In addition, the program also funds, as direct borrowers, the short-term debt requirements of other subsidiaries that are not participants in either money pool for regulatory or operational reasons. The program also allows some direct borrowers to invest excess cash with Parent. Interest expense related to Parent’s short-term borrowing is included in Interest Expense on Parent’s statements of income. Parent incurred interest expense for amounts borrowed from subsidiaries of $28 million, $33 million and $30 million for the years ended December 31, 2024, 2023 and 2022, respectively. Interest income related to Parent’s short-term lending is included in Interest Income on Parent’s statements of income. Parent earned interest income for amounts advanced to subsidiaries of $84 million, $164 million and $71 million for the years ended December 31, 2024, 2023 and 2022, respectively. Affiliated Notes Parent issued long-term debt, portions of which were loaned to its subsidiaries. Parent pays interest on the affiliated notes, but the subsidiaries accrue interest for their share of the affiliated borrowing and remit the interest to Parent. Interest income related to Parent’s loans to subsidiaries is included in Interest Income on Parent’s statements of income. Parent earned interest income on loans to subsidiaries of $7 million, $6 million and $3 million for the years ended December 31, 2024, 2023 and 2022, respectively.

SCHEDULE II _ VALUATION AND QUA

SCHEDULE II – VALUATION AND QUALIFYING ACCOUNTS AND RESERVES	12 Months Ended
	Dec. 31, 2024
SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract]
SCHEDULE II – VALUATION AND QUALIFYING ACCOUNTS AND RESERVES	SCHEDULE II – VALUATION AND QUALIFYING ACCOUNTS AND RESERVES AEP Additions Description Balance at Charged to Charged to Other Deductions (b) Balance at (in millions) Deducted from Assets: Allowance for Credit Losses: Year Ended December 31, 2024 $ 60.1 $ 45.3 $ 2.9 $ 47.5 $ 60.8 Year Ended December 31, 2023 57.1 15.0 — 12.0 60.1 Year Ended December 31, 2022 55.4 41.2 0.8 40.3 57.1 (a) Recoveries offset by reclasses to other assets and liabilities. (b) Uncollectible accounts written off. Schedule II for the Registrant Subsidiaries is not presented because the amounts are not material.

SCHEDULE I - CONDENSED FINANC_2

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY - AEPTCO PARENT	12 Months Ended
	Dec. 31, 2024
Condensed Financial Statements, Captions [Line Items]
SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY	SCHEDULE I AMERICAN ELECTRIC POWER COMPANY, INC. (Parent) CONDENSED FINANCIAL INFORMATION CONDENSED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME For the Years Ended December 31, 2024, 2023 and 2022 (in millions, except per-share and share amounts) Years Ended December 31, 2024 2023 2022 REVENUES Revenues $ 5.5 $ 5.1 $ 5.1 TOTAL REVENUES 5.5 5.1 5.1 EXPENSES Other Operation 66.0 16.7 84.9 Loss on the Expected Sale of the Kentucky Operations — — 363.3 Depreciation and Amortization 0.6 0.5 0.4 Amortization of KPCo Basis Difference (21.4) (16.5) — TOTAL EXPENSES 45.2 0.7 448.6 OPERATING INCOME (LOSS) (39.7) 4.4 (443.5) Other Income (Expense): Interest Income 107.9 181.0 80.3 Interest Expense (531.8) (526.3) (275.5) LOSS BEFORE INCOME TAX BENEFIT AND EQUITY EARNINGS (463.6) (340.9) (638.7) Income Tax Benefit (150.5) (80.8) (136.3) Equity Earnings of Unconsolidated Subsidiaries 3,280.2 2,468.2 2,809.6 NET INCOME 2,967.1 2,208.1 2,307.2 Other Comprehensive Income (Loss) 52.4 (139.2) (101.1) TOTAL COMPREHENSIVE INCOME $ 3,019.5 $ 2,068.9 $ 2,206.1 WEIGHTED AVERAGE NUMBER OF BASIC AEP COMMON SHARES OUTSTANDING 530,092,672 518,903,682 511,841,946 TOTAL BASIC EARNINGS PER SHARE ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS $ 5.60 $ 4.26 $ 4.51 WEIGHTED AVERAGE NUMBER OF DILUTED AEP COMMON SHARES OUTSTANDING 531,337,703 520,206,258 513,484,609 TOTAL DILUTED EARNINGS PER SHARE ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS $ 5.58 $ 4.24 $ 4.49 See Condensed Notes to Condensed Financial Information beginning on page S- 6 . SCHEDULE I AMERICAN ELECTRIC POWER COMPANY, INC. (Parent) CONDENSED FINANCIAL INFORMATION CONDENSED BALANCE SHEETS ASSETS December 31, 2024 and 2023 (in millions) December 31, 2024 2023 CURRENT ASSETS Cash and Cash Equivalents $ 87.5 $ 197.8 Other Temporary Investments 2.9 2.6 Advances to Affiliates 1,944.6 2,004.5 Accounts Receivable: Affiliated Companies 32.5 47.7 General — 2.7 Total Accounts Receivable 32.5 50.4 Accrued Tax Benefits 93.7 77.7 Prepayments and Other Current Assets 11.6 11.6 TOTAL CURRENT ASSETS 2,172.8 2,344.6 PROPERTY, PLANT AND EQUIPMENT General 3.2 3.1 Total Property, Plant and Equipment 3.2 3.1 Accumulated Depreciation, Depletion and Amortization 1.7 1.4 TOTAL PROPERTY, PLANT AND EQUIPMENT – NET 1.5 1.7 OTHER NONCURRENT ASSETS Investments in Unconsolidated Subsidiaries 35,306.2 33,598.6 Affiliated Notes Receivable 105.0 295.0 Deferred Charges and Other Noncurrent Assets 184.6 137.0 TOTAL OTHER NONCURRENT ASSETS 35,595.8 34,030.6 TOTAL ASSETS $ 37,770.1 $ 36,376.9 See Condensed Notes to Condensed Financial Information beginning on page S- 6 . SCHEDULE I AMERICAN ELECTRIC POWER COMPANY, INC. (Parent) CONDENSED FINANCIAL INFORMATION CONDENSED BALANCE SHEETS LIABILITIES AND EQUITY December 31, 2024 and 2023 (dollars in millions) December 31, 2024 2023 CURRENT LIABILITIES Advances from Affiliates $ 506.6 $ 728.3 Accounts Payable: General 4.7 11.1 Affiliated Companies 2.2 12.3 Short-term Debt 1,618.3 1,937.9 Long-term Debt Due Within One Year – Nonaffiliated 1,281.5 1,104.0 Other Current Liabilities 202.4 137.7 TOTAL CURRENT LIABILITIES 3,615.7 3,931.3 NONCURRENT LIABILITIES Long-term Debt – Nonaffiliated 7,124.3 7,086.9 Deferred Credits and Other Noncurrent Liabilities 48.5 69.5 TOTAL NONCURRENT LIABILITIES 7,172.8 7,156.4 TOTAL LIABILITIES 10,788.5 11,087.7 MEZZANINE EQUITY Contingently Redeemable Performance Share Awards 37.8 42.5 COMMON SHAREHOLDERS’ EQUITY Common Stock – Par Value – $6.50 Per Share: 2024 2023 Shares Authorized 600,000,000 600,000,000 Shares Issued 534,094,530 527,369,157 (1,186,815 and 1,184,572 Shares were Held in Treasury as of December 31, 2024 and 2023, Respectively) 3,471.6 3,427.9 Paid-in Capital 9,606.1 9,073.9 Retained Earnings 13,869.2 12,800.4 Accumulated Other Comprehensive Income (Loss) (3.1) (55.5) TOTAL AEP COMMON SHAREHOLDERS’ EQUITY 26,943.8 25,246.7 TOTAL LIABILITIES, MEZZANINE EQUITY AND TOTAL EQUITY $ 37,770.1 $ 36,376.9 See Condensed Notes to Condensed Financial Information beginning on page S- 6 . SCHEDULE I AMERICAN ELECTRIC POWER COMPANY, INC. (Parent) CONDENSED FINANCIAL INFORMATION CONDENSED STATEMENTS OF CASH FLOWS For the Years Ended December 31, 2024, 2023 and 2022 (in millions) Years Ended December 31, 2024 2023 2022 OPERATING ACTIVITIES Net Income $ 2,967.1 $ 2,208.1 $ 2,307.2 Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities: Depreciation and Amortization 0.6 0.5 0.4 Amortization of KPCo Basis Difference (21.4) (16.5) — Deferred Income Taxes (53.3) 59.7 (63.3) Loss on the Expected Sale of the Kentucky Operations — — 363.3 Equity Earnings of Unconsolidated Subsidiaries (3,280.2) (2,468.2) (2,809.6) Cash Dividends Received from Unconsolidated Subsidiaries 1,143.4 686.3 603.9 Change in Other Noncurrent Assets 4.9 (28.4) (5.0) Change in Other Noncurrent Liabilities 70.8 92.3 83.5 Changes in Certain Components of Working Capital: Accounts Receivable, Net 17.9 28.7 (61.0) Accounts Payable (16.5) (15.9) 1.1 Other Current Assets — (3.6) (6.0) Other Current Liabilities 55.3 (14.5) (76.6) Net Cash Flows from Operating Activities 888.6 528.5 337.9 INVESTING ACTIVITIES Construction Expenditures (0.6) (0.8) (0.7) Change in Advances to Affiliates, Net 59.9 2,007.6 (1,411.3) Capital Contributions to Unconsolidated Subsidiaries (399.9) (789.9) (568.3) Return of Capital Contributions from Unconsolidated Subsidiaries 898.9 56.6 24.5 Issuance of Notes Receivable to Unconsolidated Subsidiaries — (210.0) (20.0) Repayment of Notes Receivable from Unconsolidated Subsidiaries 190.0 — — Other Investing Activities — — (0.2) Net Cash Flows from (Used for) Investing Activities 748.3 1,063.5 (1,976.0) FINANCING ACTIVITIES Issuance of Common Stock, Net 552.1 999.6 826.5 Issuance of Long-term Debt 1,285.4 1,829.8 986.6 Issuance of Short-term Debt with Original Maturities Greater Than 90 Days 723.8 1,069.9 833.9 Change in Short-term Debt with Original Maturities Less Than 90 Day, Net (172.3) (1,365.4) 1,650.4 Retirement of Long-term Debt (1,104.0) (1,050.0) (300.0) Change in Advances from Affiliates, Net (221.7) (191.6) 336.9 Redemption of Short-term Debt with Original Maturities Greater Than 90 Days (871.1) (1,128.8) (986.1) Dividends Paid on Common Stock (1,898.3) (1,752.3) (1,628.7) Other Financing Activities (41.1) (59.6) (74.5) Net Cash Flows from (Used for) Financing Activities (1,747.2) (1,648.4) 1,645.0 Net Increase (Decrease) in Cash and Cash Equivalents (110.3) (56.4) 6.9 Cash and Cash Equivalents at Beginning of Period 197.8 254.2 247.3 Cash and Cash Equivalents at End of Period $ 87.5 $ 197.8 $ 254.2 See Condensed Notes to Condensed Financial Information beginning on page S- 6 . SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Basis of Presentation The condensed financial information of Parent is required as a result of the restricted net assets of AEP consolidated subsidiaries exceeding 25% of AEP consolidated net assets as of December 31, 2024. Parent is a public utility holding company that owns all of the outstanding common stock of its public utility subsidiaries and varying percentages of other subsidiaries, including joint ventures and equity investments. The primary source of income for Parent is equity in its subsidiaries’ earnings. Its major source of cash is dividends from the subsidiaries, which are evaluated for cash flow presentation based on the nature of the distribution. Parent borrows the funds for the money pool that is used by the subsidiaries for their short-term cash needs. Parent financial statements should be read in conjunction with the AEP consolidated financial statements and the accompanying notes thereto. For purposes of these condensed financial statements, AEP wholly-owned and majority-owned subsidiaries are recorded based upon its proportionate share of the subsidiaries’ net assets (similar to presenting them on the equity method). Income Taxes Parent files a consolidated federal income tax return with its subsidiaries. The benefit of current tax loss of the parent company (Parent Company Loss Benefit) to the AEP System subsidiaries is accounted for as an allocation through equity. The consolidated NOL of the AEP System is allocated to each company in the consolidated group with taxable loss. With the exception of the allocation of the consolidated AEP System NOL, Parent Company Loss Benefit and general business tax credits, the method of allocation reflects a separate return result for each company in the consolidated group. COMMITMENTS, GUARANTEES AND CONTINGENCIES FINANCING ACTIVITIES The following details long-term debt outstanding as of December 31, 2024 and 2023: Long-term Debt Weighted-Average Interest Rate Ranges as of Outstanding as of Interest Rate as of December 31, December 31, Type of Debt Maturity December 31, 2024 2024 2023 2024 2023 (in millions) Senior Unsecured Notes 2025-2050 4.29% 1.00%-5.95% 1.00%-5.95% $ 5,290.0 $ 5,265.0 Pollution Control Bonds 2026-2029 (a) 3.12% 2.40%-3.75% 1.90%-2.60% 536.8 537.8 Junior Subordinated Notes 2025-2027 5.67% 3.88%-7.05% 2.03%-5.70% 2,579.0 2,388.1 Total Long-term Debt Outstanding 8,405.8 8,190.9 Long-term Debt Due Within One Year 1,281.5 1,104.0 Long-term Debt $ 7,124.3 $ 7,086.9 (a) Certain Pollution Control Bonds are subject to redemption earlier than the maturity date. Long-term debt outstanding as of December 31, 2024 is payable as follows: 2025 2026 2027 2028 2029 After 2029 Total (in millions) Principal Amount (a) $ 1,281.5 $ 50.0 $ 1,758.3 $ 930.4 $ 1,694.5 $ 2,750.0 $ 8,464.7 Unamortized Discount, Net and Debt Issuance Costs (58.9) Total Long-term Debt Outstanding $ 8,405.8 (a) Amounts reflect the impact of fair value hedge accounting. See “Accounting for Fair Value Hedging Strategies” section of Note 10 included in the 2024 Annual Report for additional information. Short-term Debt Parent’s outstanding short-term debt was as follows: December 31, 2024 December 31, 2023 Type of Debt Outstanding Weighted-Average Outstanding Weighted-Average (in millions) (in millions) Commercial Paper $ 1,618.3 4.70 % $ 1,937.9 5.69 % Total Short-term Debt $ 1,618.3 $ 1,937.9 RELATED PARTY TRANSACTIONS Payments on Behalf of Subsidiaries Due to occasional time sensitivity and complexity of payments, Parent makes certain insurance, tax and benefit payments on behalf of subsidiary companies. Parent is then fully reimbursed by the subsidiary companies. Short-term Lending to Subsidiaries Parent uses a commercial paper program to meet the short-term borrowing needs of subsidiaries. The program is used to fund both a Utility Money Pool, which funds the utility subsidiaries, and a Nonutility Money Pool, which funds certain nonutility subsidiaries. In addition, the program also funds, as direct borrowers, the short-term debt requirements of other subsidiaries that are not participants in either money pool for regulatory or operational reasons. The program also allows some direct borrowers to invest excess cash with Parent. Interest expense related to Parent’s short-term borrowing is included in Interest Expense on Parent’s statements of income. Parent incurred interest expense for amounts borrowed from subsidiaries of $28 million, $33 million and $30 million for the years ended December 31, 2024, 2023 and 2022, respectively. Interest income related to Parent’s short-term lending is included in Interest Income on Parent’s statements of income. Parent earned interest income for amounts advanced to subsidiaries of $84 million, $164 million and $71 million for the years ended December 31, 2024, 2023 and 2022, respectively. Affiliated Notes Parent issued long-term debt, portions of which were loaned to its subsidiaries. Parent pays interest on the affiliated notes, but the subsidiaries accrue interest for their share of the affiliated borrowing and remit the interest to Parent. Interest income related to Parent’s loans to subsidiaries is included in Interest Income on Parent’s statements of income. Parent earned interest income on loans to subsidiaries of $7 million, $6 million and $3 million for the years ended December 31, 2024, 2023 and 2022, respectively.
AEP TRANSMISSION COMPANY, LLC | Parent Company
Condensed Financial Statements, Captions [Line Items]
SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY	SCHEDULE I AEP TRANSMISSION COMPANY, LLC (AEPTCo Parent) CONDENSED FINANCIAL INFORMATION CONDENSED STATEMENTS OF INCOME For the Years Ended December 31, 2024, 2023 and 2022 (in millions) Years Ended December 31, 2024 2023 2022 EXPENSES Other Operation $ 1.7 $ 0.2 $ 0.7 TOTAL EXPENSES 1.7 0.2 0.7 OPERATING LOSS (1.7) (0.2) (0.7) Other Income (Expense): Interest Income - Affiliated 241.1 218.0 177.8 Interest Expense (238.7) (215.1) (177.1) INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS OF UNCONSOLIDATED SUBSIDIARIES 0.7 2.7 — Income Tax Expense 0.1 1.4 — Equity Earnings of Unconsolidated Subsidiaries 687.8 612.9 594.2 NET INCOME $ 688.4 $ 614.2 $ 594.2 See Condensed Notes to Condensed Financial Information beginning on page S- 15 . SCHEDULE I AEP TRANSMISSION COMPANY, LLC (AEPTCo Parent) CONDENSED FINANCIAL INFORMATION CONDENSED BALANCE SHEETS ASSETS December 31, 2024 and 2023 (in millions) December 31, 2024 2023 CURRENT ASSETS Advances to Affiliates $ 20.4 $ — Accounts Receivable: General — 28.1 Affiliated Companies 61.7 44.0 Total Accounts Receivable 61.7 72.1 Notes Receivable - Affiliated 90.0 95.0 TOTAL CURRENT ASSETS 172.1 167.1 OTHER NONCURRENT ASSETS Notes Receivable - Affiliated 8,498.1 5,319.4 Investments in Unconsolidated Subsidiaries 4,272.8 6,476.2 Deferred Charges and Other Noncurrent Assets 0.3 — TOTAL OTHER NONCURRENT ASSETS 12,771.2 11,795.6 TOTAL ASSETS $ 12,943.3 $ 11,962.7 See Condensed Notes to Condensed Financial Information beginning on page S- 15 . SCHEDULE I AEP TRANSMISSION COMPANY, LLC (AEPTCo Parent) CONDENSED FINANCIAL INFORMATION CONDENSED STATEMENTS OF CASH FLOWS For the Years Ended December 31, 2024, 2023 and 2022 (in millions) Years Ended December 31, 2024 2023 2022 OPERATING ACTIVITIES Net Income $ 688.4 $ 614.2 $ 594.2 Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities: Equity Earnings of Unconsolidated Subsidiaries (687.8) (612.9) (594.2) Change in Other Noncurrent Assets — 3.8 — Change in Other Noncurrent Liabilities 4.0 11.5 9.1 Changes in Certain Components of Working Capital: Accounts Receivable, Net 10.4 (37.5) (2.2) Accounts Payable 12.9 36.6 (0.6) Accrued Interest 5.4 10.8 — Other Current Liabilities 34.0 (30.5) (0.8) Net Cash Flows from (Used for) Operating Activities 67.3 (4.0) 5.5 INVESTING ACTIVITIES Change in Advances to Affiliates, Net (20.4) — 12.7 Repayment of Notes Receivable from Affiliated Companies 95.0 60.0 104.0 Issuance of Notes Receivable to Affiliated Companies (450.0) (700.0) (550.0) Return of Capital Contributions from Unconsolidated Subsidiaries 132.8 183.7 130.0 Capital Contributions to Subsidiaries (61.7) (29.7) (69.5) Net Cash Flows Used for Investing Activities (304.3) (486.0) (372.8) FINANCING ACTIVITIES Capital Contributions from Member 61.7 29.7 72.7 Return of Capital to Member (4.5) (8.6) — Issuance of Long-term Debt – Nonaffiliated 445.7 689.0 540.8 Retirement of Long-term Debt – Nonaffiliated (95.0) (60.0) (104.0) Change in Advances from Affiliates, Net (42.7) 14.9 27.8 Dividends Paid to Member (128.0) (175.0) (170.0) Other Financing Activities (0.2) — — Net Cash Flows from Financing Activities 237.0 490.0 367.3 Net Change in Cash and Cash Equivalents — — — Cash and Cash Equivalents at Beginning of Period — — — Cash and Cash Equivalents at End of Period $ — $ — $ — See Condensed Notes to Condensed Financial Information beginning on page S- 15 . SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Basis of Presentation The condensed financial information of AEPTCo Parent is required as a result of the restricted net assets of AEPTCo consolidated subsidiaries exceeding 25% of AEPTCo consolidated net assets as of December 31, 2024. AEPTCo Parent is the direct holding company for the seven State Transcos. The primary source of income for AEPTCo Parent is equity in its subsidiaries’ earnings. AEPTCo Parent financial statements should be read in conjunction with the AEPTCo consolidated financial statements and the accompanying notes thereto. For purposes of these condensed financial statements, AEPTCo wholly-owned and majority-owned subsidiaries are recorded based upon its proportionate share of the subsidiaries’ net assets (similar to presenting them on the equity method). Income Taxes AEPTCo Parent joins in the filing of a consolidated federal income tax return with its affiliates in the AEP System. The benefit of current tax loss of the parent company (Parent Company Loss Benefit) to the AEP System subsidiaries is accounted for as an allocation through equity. The consolidated NOL of the AEP System is allocated to each company in the consolidated group with taxable loss. With the exception of the allocation of the consolidated AEP System NOL, Parent Company Loss Benefit and general business tax credits, the method of allocation reflects a separate return result for each company in the consolidated group. Noncontrolling Interest in OHTCo and IMTCo In January 2025, AEP announced a partnership between nonaffiliated entities to acquire a 19.9% noncontrolling interest in OHTCo and IMTCo for $2.82 billion. The transaction is subject to FERC approval and clearance from the Committee on Foreign Investment in the United States. In December 2024, Midwest Transmission Holdings, LCC was formed as a consolidated joint venture by AEPTCo Parent in anticipation of the transaction being finalized in the second half of 2025. AEPTCo Parent recorded Notes Receivable – Affiliated of $2.82 billion as of December 31, 2024 in relation to Midwest Transmission Holdings, LLC. See Note 4 - Related Party Transactions for additional information. COMMITMENTS, GUARANTEES AND CONTINGENCIES AEPTCo Parent and its subsidiaries are parties to legal matters. For further discussion, see Note 6 - Commitments, Guarantees and Contingencies. FINANCING ACTIVITIES For discussion of Financing Activities, see Note 15 - Financing Activities to AEPTCo’s audited consolidated financial statements. RELATED PARTY TRANSACTIONS Payments on Behalf of Subsidiaries Due to occasional time sensitivity and complexity of payments, Parent makes certain insurance, tax and other payments on behalf of subsidiary companies. Parent is then fully reimbursed by the subsidiary companies. AEPTCo Parent also makes convenience payments on behalf of its State Transcos. AEPTCo Parent is then fully reimbursed by its State Transcos. Long-term Lending to Subsidiaries AEPTCo Parent enters into debt arrangements with nonaffiliated entities. AEPTCo Parent has long-term debt of $5.8 billion and $5.4 billion as of December 31, 2024 and 2023, respectively. AEPTCo Parent uses the proceeds from these nonaffiliated debt arrangements to make affiliated loans to its State Transcos using the same interest rates and maturity dates as the nonaffiliated debt arrangements. AEPTCo Parent has recorded Notes Receivable – Affiliated of $8.6 billion and $5.4 billion as of December 31, 2024 and 2023, respectively. Related to these nonaffiliated and affiliated debt arrangements, AEPTCo Parent has recorded Accrued Interest of $45 million and $40 million as of December 31, 2024 and 2023, respectively. AEPTCo Parent has also recorded Accounts Receivable – Affiliated Companies of $62 million and $44 million as of December 31, 2024 and 2023, respectively. AEPTCo Parent has recorded Interest Income – Affiliated of $238 million, $215 million and $177 million for the years ended December 31, 2024, 2023 and 2022, respectively, related to the Notes Receivable – Affiliated. AEPTCo Parent has recorded Interest Expense of $238 million, $215 million and $177 million for the years ended December 31, 2024, 2023 and 2022, respectively, related to the nonaffiliated debt arrangements. Short-term Lending to Subsidiaries Parent uses a commercial paper program to meet the short-term borrowing needs of subsidiaries. The program is used to fund both a Utility Money Pool, which funds the utility subsidiaries, and a Nonutility Money Pool, which funds certain nonutility subsidiaries. In addition, the program also funds, as direct borrowers, the short-term debt requirements of other subsidiaries that are not participants in either money pool for regulatory or operational reasons. The program also allows some direct borrowers to invest excess cash with Parent. Interest expense related to AEPTCo Parent’s short-term borrowing is included in Interest Expense on AEPTCo Parent’s statements of income. AEPTCo Parent incurred immaterial interest expense for amounts borrowed from AEP affiliates for the years ended December 31, 2024, 2023 and 2022. Interest income related to AEPTCo Parent’s short-term lending is included in Interest Income – Affiliated on AEPTCo Parent’s statements of income. AEPTCo Parent earned interest income for amounts advanced to AEP affiliates of $3 million, $3 million and $915 thousand for the years ended December 31, 2024, 2023 and 2022, respectively.

Insider Trading Arrangements

Insider Trading Arrangements	3 Months Ended
	Dec. 31, 2024
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

Insider Trading Policies and Pr

Insider Trading Policies and Procedures	12 Months Ended
	Dec. 31, 2024
Insider Trading Policies and Procedures [Line Items]
Insider Trading Policies and Procedures Adopted	true

Cybersecurity Risk Management a

Cybersecurity Risk Management and Strategy Disclosure	12 Months Ended
	Dec. 31, 2024
Cybersecurity Risk Management, Strategy, and Governance [Line Items]
Cybersecurity Risk Management Processes for Assessing, Identifying, and Managing Threats [Text Block]	The operations of AEP’s electric utility subsidiaries are subject to extensive and rigorous mandatory cyber and physical security requirements that are developed and enforced by NERC to protect grid security and reliability. Cook Plant is also subject to NRC regulation for cybersecurity. AEP’s enterprise-wide security program includes cyber and physical security and incorporates many of the guidelines set forth in the National Institute of Standards and Technology Cybersecurity Framework. AEP'’s Chief Security Officer (CSO) has accountability for cyber aspects of third-party risk and data loss prevention and is also its NERC Critical Infrastructure Protection Senior Manager, who is responsible for ensuring alignment of compliance with the enterprise-wide security program. AEP’s CSO possesses extensive experience across cybersecurity, risk and data controls and infrastructure engineering. AEP’s CSO was the Chief Security Officer at Bread Financial Holdings, Inc., a publicly registered financial services company, and an executive director of cyber security at JPMorgan Chase & Co. prior to joining AEP. Critical cyber assets, such as data centers, power plants, transmission operations centers and business networks are protected using multiple layers of cybersecurity controls and authentication. Cyber hackers and other malicious actors have caused material disruption by successfully breaching a number of very secure facilities of entities across the spectrum of industries, including federal agencies and financial institutions. As understanding of these events develop, AEP has adopted a defense in depth approach to cybersecurity and continually assesses its cybersecurity tools and processes to determine where to strengthen its defenses. These strategies include monitoring, alerting and emergency response, forensic analysis, disaster recovery, threat sharing and criminal activity reporting. This approach has allowed AEP to deal with cyber and related threats, intrusions and attempted breaches in real-time and to limit their impact to levels that would be expected in the ordinary course of business in the absence of such malicious activity. AEP is not aware of any occurrence from cybersecurity threats, including as a result of any previous cybersecurity incidents, that has materially affected or is reasonably likely to materially affect AEP’s business strategy, results of operations, cash flows or financial condition. AEP’s CSO leads the cybersecurity and physical security teams which are responsible for the design, implementation and execution of AEP’s security risk management strategy, which includes cybersecurity. AEP’s cybersecurity team operates a 24/7 Cybersecurity Intelligence and Response Center responsible for monitoring the AEP System for cyber risks and threats. The cybersecurity team constantly scans the AEP System for cyber risks and threats. In addition, under the direction of the CSO, the cybersecurity team actively monitors best practices, performs penetration testing, leads response exercises and internal awareness campaigns and provides training and communication across the organization. AEP’s security awareness training is mandatory for all employees and includes regular phish email testing to train employees to identify malicious emails that could put AEP at risk. AEP also continually reviews its business continuity plan to develop an effective recovery strategy that seeks to decrease response times, limit financial impacts and maintain customer confidence during any business interruption. AEP administers a third-party risk governance program that identifies potential risks introduced through third-party relationships, such as vendors, software and hardware manufacturers or professional service providers. As warranted, AEP obtains certain contractual security guarantees and assurances with these third-party relationships to help ensure the security and safety of its information. The cyber security team works closely with a broad range of departments, including legal, regulatory, corporate communications, internal audit services, information technology and operational technology functions critical to the power grid.
Cybersecurity Risk Management Processes Integrated [Flag]	true
Cybersecurity Risk Management Processes Integrated [Text Block]	AEP’s strategy and procedure for managing cyber-related risks is integrated within its enterprise risk management processes.
Cybersecurity Risk Management Third Party Engaged [Flag]	true
Cybersecurity Risk Third Party Oversight and Identification Processes [Flag]	true
Cybersecurity Risk Materially Affected or Reasonably Likely to Materially Affect Registrant [Flag]	false
Cybersecurity Risk Board of Directors Oversight [Text Block]	AEP has undertaken a variety of actions to monitor and address cyber-related risks. Cybersecurity and the effectiveness of AEP’s cybersecurity processes are reviewed annually with the Board of Directors and at several meetings throughout the year with the Technology Committee of the Board, the principal committee that exercises oversight with respect to these matters. AEP’s Chief Executive Officer and executive team participate in interactive threat briefings from AEP’s CSO and/or Chief Information & Technology Officer on a regular basis. AEP’s strategy and procedure for managing cyber-related risks is integrated within its enterprise risk management processes. These procedures are designed to ensure that any material information regarding potentially relevant cyber incidents is elevated in a timely manner both to the appropriate leadership and, where applicable, to our external financial reporting and disclosure team. AEP’s enterprise-wide security program continually adjusts staff and resources in response to the evolving threat landscape. The costs for such investments are material and have remained generally consistent over time, a pattern that is expected to continue. In addition, AEP maintains cyber liability insurance to cover certain damages caused by cyber incidents. AEP’s CSO leads the cybersecurity and physical security teams which are responsible for the design, implementation and execution of AEP’s security risk management strategy, which includes cybersecurity. AEP’s cybersecurity team operates a 24/7 Cybersecurity Intelligence and Response Center responsible for monitoring the AEP System for cyber risks and threats. The cybersecurity team constantly scans the AEP System for cyber risks and threats. In addition, under the direction of the CSO, the cybersecurity team actively monitors best practices, performs penetration testing, leads response exercises and internal awareness campaigns and provides training and communication across the organization. AEP’s security awareness training is mandatory for all employees and includes regular phish email testing to train employees to identify malicious emails that could put AEP at risk.
Cybersecurity Risk Board Committee or Subcommittee Responsible for Oversight [Text Block]	AEP has undertaken a variety of actions to monitor and address cyber-related risks. Cybersecurity and the effectiveness of AEP’s cybersecurity processes are reviewed annually with the Board of Directors and at several meetings throughout the year with the Technology Committee of the Board, the principal committee that exercises oversight with respect to these matters. AEP’s Chief Executive Officer and executive team participate in interactive threat briefings from AEP’s CSO and/or Chief Information & Technology Officer on a regular basis. AEP’s strategy and procedure for managing cyber-related risks is integrated within its enterprise risk management processes. These procedures are designed to ensure that any material information regarding potentially relevant cyber incidents is elevated in a timely manner both to the appropriate leadership and, where applicable, to our external financial reporting and disclosure team. AEP’s enterprise-wide security program continually adjusts staff and resources in response to the evolving threat landscape. The costs for such investments are material and have remained generally consistent over time, a pattern that is expected to continue. In addition, AEP maintains cyber liability insurance to cover certain damages caused by cyber incidents.
Cybersecurity Risk Process for Informing Board Committee or Subcommittee Responsible for Oversight [Text Block]	Cybersecurity and the effectiveness of AEP’s cybersecurity processes are reviewed annually with the Board of Directors and at several meetings throughout the year with the Technology Committee of the Board, the principal committee that exercises oversight with respect to these matters.
Cybersecurity Risk Role of Management [Text Block]	AEP’s CSO leads the cybersecurity and physical security teams which are responsible for the design, implementation and execution of AEP’s security risk management strategy, which includes cybersecurity. AEP’s cybersecurity team operates a 24/7 Cybersecurity Intelligence and Response Center responsible for monitoring the AEP System for cyber risks and threats. The cybersecurity team constantly scans the AEP System for cyber risks and threats. In addition, under the direction of the CSO, the cybersecurity team actively monitors best practices, performs penetration testing, leads response exercises and internal awareness campaigns and provides training and communication across the organization. AEP’s security awareness training is mandatory for all employees and includes regular phish email testing to train employees to identify malicious emails that could put AEP at risk.
Cybersecurity Risk Management Positions or Committees Responsible [Flag]	true
Cybersecurity Risk Management Positions or Committees Responsible [Text Block]	AEP'’s Chief Security Officer (CSO) has accountability for cyber aspects of third-party risk and data loss prevention and is also its NERC Critical Infrastructure Protection Senior Manager, who is responsible for ensuring alignment of compliance with the enterprise-wide security program.
Cybersecurity Risk Management Expertise of Management Responsible [Text Block]	AEP’s CSO possesses extensive experience across cybersecurity, risk and data controls and infrastructure engineering. AEP’s CSO was the Chief Security Officer at Bread Financial Holdings, Inc., a publicly registered financial services company, and an executive director of cyber security at JPMorgan Chase & Co. prior to joining AEP.
Cybersecurity Risk Process for Informing Management or Committees Responsible [Text Block]	Cybersecurity and the effectiveness of AEP’s cybersecurity processes are reviewed annually with the Board of Directors and at several meetings throughout the year with the Technology Committee of the Board, the principal committee that exercises oversight with respect to these matters.
Cybersecurity Risk Management Positions or Committees Responsible Report to Board [Flag]	true

ORGANIZATION AND SUMMARY OF S_2

ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
	Dec. 31, 2024
Accounting Policies [Abstract]
Principles of Consolidation	AEP and the Registrant Subsidiaries’ consolidated financial statements include wholly-owned subsidiaries and VIEs, of which AEP or a Registrant Subsidiary is the primary beneficiary. Intercompany items are eliminated in consolidation. The equity method of accounting is used for equity investments where the Registrants exercise significant influence but do not hold a controlling financial interest. Such investments are initially recorded at cost in Deferred Charges and Other Noncurrent Assets on the balance sheets. The proportionate share of the investee’s equity earnings or losses is included in Equity Earnings of Unconsolidated Subsidiaries on the statements of income.
Accounting for the Effects of Cost-Based Regulation	The Registrants’ financial statements reflect the actions of regulators that result in the recognition of certain revenues and expenses in different time periods than enterprises that are not rate-regulated. In accordance with accounting guidance for “Regulated Operations,” regulatory assets (deferred expenses to be recovered in the future) and regulatory liabilities (deferred revenue reductions or refunds) are recorded to reflect the economic effects of regulation in the same accounting period by matching expenses with their recovery through regulated revenues and by matching income with its passage to customers in cost-based regulated rates.
Use of Estimates	The preparation of these financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. These estimates include, but are not limited to, inventory valuation, allowance for credit losses, intangible and long-lived asset impairment, unbilled electricity revenue, valuation of long-term energy contracts, the effects of regulation, long-lived asset recovery, storm costs, AROs, the effects of contingencies and certain assumptions made in accounting for pension and postretirement benefits. The estimates and assumptions used are based upon management’s evaluation of the relevant facts and circumstances as of the date of the financial statements. Actual results could ultimately differ from those estimates.
Cash and Cash Equivalents	Cash and Cash Equivalents include temporary cash investments with original maturities of three months or less.
Restricted Cash	Restricted Cash primarily includes funds held by trustees for the payment of securitization bonds.
Other Temporary Investments	Other Temporary Investments primarily include marketable securities and investments by its protected cell of EIS. These securities have readily determinable fair values and are carried at fair value with changes in fair value recognized in net income.  The cost of securities sold is based on the specific identification or weighted-average cost method.
Inventory	Fossil fuel inventories are carried at average cost with the exception of AGR, which carries these inventories at the lower of average cost or net realizable value.  Materials and supplies inventories are carried at average cost.
Accounts Receivable and Allowance for Credit Losses	Customer accounts receivable primarily include receivables from wholesale and retail energy customers, receivables from energy contract counterparties related to risk management activities and customer receivables primarily related to other revenue-generating activities. Revenue is recognized over time as the performance obligations of delivering energy to customers are satisfied. To the extent that deliveries have occurred but a bill has not been issued, the Registrants accrue and recognize, as Accrued Unbilled Revenues on the balance sheets, an estimate of the revenues for energy delivered since the last billing. AEP Credit factors accounts receivable on a daily basis, excluding receivables from risk management activities, through purchase agreements with I&M, KGPCo, KPCo, OPCo, PSO, SWEPCo and a portion of APCo. Since APCo does not have regulatory authority to sell accounts receivable in its West Virginia regulatory jurisdiction, only a portion of APCo’s accounts receivable are sold to AEP Credit. AEP Credit has a receivables securitization agreement with bank conduits. Under the securitization agreement, AEP Credit receives financing from bank conduits for a portion of its interests in the billed and unbilled receivables acquired from the affiliated utility subsidiaries. See “Securitized Accounts Receivable – AEP Credit” section of Note 15 for additional information. Generally, AEP Credit recognizes bad debt expense based upon a 12-month rolling average of bad debt write-offs in proportion to gross accounts receivable purchased from participating AEP subsidiaries. The assessment is performed separately for each participating AEP subsidiary, which inherently contemplates any differences in geographical risk characteristics for the allowance for credit losses. For receivables related to APCo’s West Virginia operations, the allowance for credit losses is calculated based on a rolling two-year average write-off in proportion to gross accounts receivable. For customer accounts receivables relating to risk management activities, accounts receivable are reviewed for potential credit losses at a specific counterparty level basis. For AEP Texas, allowances for credit losses are calculated using the specific identification of receivable balances greater than 120 days delinquent, and for those balances less than 120 days where the collection is doubtful. For miscellaneous accounts receivable, bad debt expense is recognized based upon a 12-month rolling average of bad debt write-offs in proportion to gross accounts receivable, unless specifically identified. In addition to these processes, management contemplates available current information, as well as any reasonable and supportable forecast information, to determine if allowances for credit losses should be further adjusted in accordance with the accounting guidance for “Credit Losses.” Management’s assessments contemplate expected losses over the life of the accounts receivable.
Concentrations of Credit Risk and Significant Customers	The Registrant Subsidiaries monitor credit levels and the financial condition of their customers on a continuous basis to minimize credit risk. The regulatory commissions allow recovery in rates for a reasonable level of bad debt costs. Management believes adequate provisions for credit loss have been made in the accompanying Registrant Subsidiary financial statements.
Renewable Energy Credits	In regulated jurisdictions, the Registrants record renewable energy credits (RECs) at cost. For RECs acquired in AEP’s nonregulated operations within the Generation & Marketing segment, management records those RECs at the lower of cost or net realizable value. The Registrants follow the inventory model for these RECs. RECs are reported in Materials and Supplies on the balance sheets. The purchases and sales of RECs are reported in the Operating Activities section of the statements of cash flows. RECs that are consumed to meet applicable state renewable portfolio standards are recorded in Fuel and Other Consumables Used for Electric Generation at an average cost on the statements of income. The net margin on sales of RECs affects the determination of deferred fuel and REC costs.
Property, Plant and Equipment	Regulated Electric utility property, plant and equipment for rate-regulated operations are stated at original cost. Additions, major replacements and betterments are added to the plant accounts. Under the group composite method of depreciation, continuous interim routine replacements of items such as boiler tubes, pumps, motors, etc. result in original cost retirements, less salvage, being charged to accumulated depreciation. The group composite method of depreciation assumes that on average, asset components are retired at the end of their useful lives and thus there is no gain or loss. The equipment in each primary electric plant account is identified as a separate group. The depreciation rates that are established take into account the past history of interim capital replacements and the amount of removal cost incurred and salvage received. These rates and the related lives are subject to periodic review. Removal costs accrued are typically recorded as regulatory liabilities when the revenue received for removal costs accrued exceeds actual removal costs incurred. The asset removal costs liability is relieved as removal costs are incurred. A regulatory asset balance will occur if actual removal costs incurred exceed accumulated removal costs accrued. The costs of labor, materials and overhead incurred to operate and maintain plant and equipment are included in operating expenses. Nuclear fuel, including nuclear fuel in the fabrication phase, is included in Other Property, Plant and Equipment on the balance sheets. Long-lived assets are required to be tested for impairment when it is determined that the carrying value of the assets may no longer be recoverable or when the assets meet the held-for-sale criteria under the accounting guidance for “Impairment or Disposal of Long-Lived Assets.” When it becomes probable that an asset in-service or an asset under construction will be abandoned and regulatory cost recovery has been disallowed or is not probable, the cost of that asset shall be written down to its then current estimated fair value, with the change charged to expense, and the asset is removed from plant-in-service or CWIP. The fair value of an asset is the amount at which that asset could be bought or sold in a current transaction between willing parties, as opposed to a forced or liquidation sale. Quoted market prices in active markets are the best evidence of fair value and are used as the basis for the measurement, if available. In the absence of quoted prices for identical or similar assets in active markets, fair value is estimated using various internal and external valuation methods including cash flow analysis and appraisals. Nonregulated Nonregulated operations generally follow the policies of rate-regulated operations listed above but with the following exceptions. Property, plant and equipment of nonregulated operations are stated at original cost (or as adjusted for any applicable impairments) plus the original cost of property acquired or constructed since the acquisition, less disposals. Normal and routine retirements from the plant accounts, net of salvage, are charged to accumulated depreciation for most nonregulated operations under the group composite method of depreciation. A gain or loss would be recorded if the retirement is not considered an interim routine replacement. Removal costs are charged to expense.
Allowance for Funds Used During Construction and Interest Capitalization	For regulated operations, AFUDC represents the estimated cost of borrowed and equity funds used to finance construction projects that is capitalized and recovered through depreciation over the service life of regulated electric utility plant. The Registrants record the equity component of AFUDC in Allowance for Equity Funds Used During Construction and the debt component of AFUDC as a reduction to Interest Expense on the statements of income. For nonregulated operations, including certain generating assets, interest is capitalized during construction in accordance with the accounting guidance for “Capitalization of Interest.”
Asset Retirement Obligation	The Registrants record ARO in accordance with the accounting guidance for “Asset Retirement and Environmental Obligations” for legal obligations for asbestos removal and for the retirement of certain ash disposal facilities, wind farms, solar farms and certain coal-mining facilities. I&M records ARO for the decommissioning of the Cook Plant. Certain registrants also record AROs related to the Federal EPA’s revised CCR Rule. For operating facilities, the present value of the liability is added to the cost of the associated asset and depreciated over the remaining life of the asset. For retired facilities, the present value of the liability is expensed, and where future recovery through rates is probable, the present value of the liability is subsequently deferred as a regulatory asset.
Valuation of Nonderivative Financial Instruments and Fair Value Measurements of Assets and Liabilities	The book values of Cash and Cash Equivalents, Advances to/from Affiliates, Accounts Receivable, Accounts Payable and Short-term Debt approximate fair value because of the short-term maturity of these instruments. Fair Value Measurements of Assets and Liabilities (Applies to all Registrants except AEPTCo) The accounting guidance for “Fair Value Measurements and Disclosures” establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). Where observable inputs are available for substantially the full term of the asset or liability, the instrument is categorized in Level 2. When quoted market prices are not available, pricing may be completed using comparable securities, dealer values, operating data and general market conditions to determine fair value. Valuation models utilize various inputs such as commodity, interest rate and, to a lesser degree, volatility and credit that include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, market corroborated inputs (i.e. inputs derived principally from, or correlated to, observable market data) and other observable inputs for the asset or liability. For commercial activities, exchange-traded derivatives, namely futures contracts, are generally fair valued based on unadjusted quoted prices in active markets and are classified as Level 1. Level 2 inputs primarily consist of OTC broker quotes in moderately active or less active markets, as well as exchange-traded derivatives where there is insufficient market liquidity to warrant inclusion in Level 1. Management verifies price curves using these broker quotes and classifies these fair values within Level 2 when substantially all of the fair value can be corroborated. Management typically obtains multiple broker quotes, which are nonbinding in nature but are based on recent trades in the marketplace. When multiple broker quotes are obtained, the quoted bid and ask prices are averaged. In certain circumstances, a broker quote may be discarded if it is a clear outlier. Management uses a historical correlation analysis between the broker quoted location and the illiquid locations. If the points are highly correlated, these locations are included within Level 2 as well. Certain OTC and bilaterally executed derivative instruments are executed in less active markets with a lower availability of pricing information. Illiquid transactions, complex structured transactions, FTRs and counterparty credit risk may require nonmarket-based inputs. Some of these inputs may be internally developed or extrapolated and utilized to estimate fair value. When such inputs have a significant impact on the measurement of fair value, the instrument is categorized as Level 3. The main driver of contracts being classified as Level 3 is the inability to substantiate energy price curves in the market. A portion of the Level 3 instruments have been economically hedged which limits potential earnings volatility. AEP utilizes its trustee’s external pricing service to estimate the fair value of the underlying investments held in the benefit plan and nuclear trusts. AEP’s investment managers review and validate the prices utilized by the trustee to determine fair value. AEP’s management performs its own valuation testing to verify the fair values of the securities. AEP receives audit reports of the trustee’s operating controls and valuation processes. Assets in the benefits and nuclear trusts, cash and cash equivalents, other temporary investments and restricted cash for securitized funding are classified using the following methods. Equities are classified as Level 1 holdings if they are actively traded on exchanges. Items classified as Level 1 are investments in money market funds, fixed income and equity mutual funds and equity securities. They are valued based on observable inputs, primarily unadjusted quoted prices in active markets for identical assets. Items classified as Level 2 are primarily investments in individual fixed income securities. Fixed income securities generally do not trade on exchanges and do not have an official closing price but their valuation inputs are based on observable market data. Pricing vendors calculate bond valuations using financial models and matrices. The models use observable inputs including yields on benchmark securities, quotes by securities brokers, rating agency actions, discounts or premiums on securities compared to par prices, changes in yields for U.S. Treasury securities, corporate actions by bond issuers, prepayment schedules and histories, economic events and, for certain securities, adjustments to yields to reflect changes in the rate of inflation. Other securities with model-derived valuation inputs that are observable are also classified as Level 2 investments. Investments with unobservable valuation inputs are classified as Level 3 investments. Investments classified as Other are valued using Net Asset Value as a practical expedient. Items classified as Other are primarily cash equivalent funds, common collective trusts, commingled funds, structured products, private equity, real estate and infrastructure investments. These investments do not have a readily determinable fair value or they contain redemption restrictions which may include the right to suspend redemptions under certain circumstances. Redemption restrictions may also prevent certain investments from being redeemed at the reporting date for the underlying value.
Deferred Fuel Costs	The cost of purchased electricity, fuel and related emission allowances and emission control chemicals/consumables is charged to Purchased Electricity, Fuel and Other Consumables Used for Electric Generation expense when the fuel is burned or the allowance or consumable is utilized. The cost of fuel also includes the cost of nuclear fuel burned which is computed primarily using the units-of-production method. In regulated jurisdictions with an active FAC, fuel cost over-recoveries (the excess of fuel-related revenues over applicable fuel costs incurred) are generally deferred as current regulatory liabilities and under-recoveries (the excess of applicable fuel costs incurred over fuel-related revenues) are generally deferred as current regulatory assets. Fuel cost over-recovery and under-recovery balances are classified as noncurrent when there is an expectation that refunds or recoveries will extend beyond a one year period, based on a company’s filing with a commission or a commission directive. These deferrals are incorporated into the development of future fuel rates billed to or refunded to customers. The amount of an over-recovery or under-recovery can also be affected by actions of the state regulatory commissions. On a routine basis, state regulatory commissions review and/or audit the Registrants’ fuel procurement policies and practices, the fuel cost calculations and FAC deferrals. FAC deferrals are adjusted when costs are no longer probable of recovery or when refunds of fuel reserves are probable. The Registrants share the majority of their Off-system Sales margins to customers either through an active FAC or other rate mechanisms. Where the FAC or Off-system Sales sharing mechanism is capped, frozen, non-existent or applicable to merchant operations, changes in fuel costs or sharing of Off-system Sales impact earnings.
Revenue Recognition	Regulatory Accounting The Registrants’ financial statements reflect the actions of regulators that can result in the recognition of revenues and expenses in different time periods than enterprises that are not rate-regulated. Regulatory assets (deferred expenses or alternative revenues recognized in accordance with the guidance for “Regulated Operations”) and regulatory liabilities (deferred revenue reductions or refunds) are recorded to reflect the economic effects of regulation in the same accounting period by matching expenses with their recovery through regulated revenues and by matching revenue with its passage to customers in cost-based regulated rates. When regulatory assets are probable of recovery through regulated rates, assets are recorded on the balance sheets. Regulatory assets are reviewed for probability of recovery at each balance sheet date or whenever new events occur. Examples of new events include the issuance of a regulatory commission order or passage of new legislation. If it is determined that recovery of a regulatory asset is no longer probable, the regulatory asset is derecognized as a charge against income. Retail and Wholesale Supply and Delivery of Electricity The Registrants recognize revenues from customers for retail and wholesale electricity sales and electricity transmission and distribution delivery services. The Registrants recognize such revenues on the statements of income as the performance obligations of delivering energy to customers are satisfied. Recognized revenues include both billed and unbilled amounts. In accordance with the applicable state commission’s regulatory treatment, PSO and SWEPCo do not include the fuel portion in unbilled revenue, but rather recognize such revenues when billed to customers. Wholesale transmission revenue is based on FERC-approved formula rate filings made for each calendar year using estimated costs. Revenues initially recognized per the annual rate filing are compared to actual costs, resulting in the subsequent recognition of an over or under-recovered amount, with interest, that is refunded or recovered, respectively, in a future year’s rates. These annual true-ups meet the definition of alternative revenues in accordance with the accounting guidance for “Regulated Operations”. An estimated annual true-up is recorded by the Registrants in the fourth quarter of each calendar year and a final annual true-up is recognized by the Registrants in the second quarter of each calendar year following the filing of annual FERC reports. Any portion of the true-ups applicable to an affiliated company is recorded as Accounts Receivable - Affiliated Companies or Accounts Payable - Affiliated Companies on the balance sheets. Any portion of the true-ups applicable to third-parties is recorded as Regulatory Assets or Regulatory Liabilities on the balance sheets. See Note 20 - Revenue from Contracts with Customers for additional information. Gross versus Net Presentation of Certain Electricity Supply and Delivery Activities Most of the power produced at the generation plants is sold to PJM or SPP. The Registrants also purchase power from PJM and SPP to supply power to customers. Generally, these power sales and purchases are reported on a net basis as revenues on the statements of income. However, purchases of power in excess of sales to PJM or SPP, on an hourly net basis, used to serve retail load are recorded gross as Purchased Electricity on the statements of income. With the exception of certain dedicated load bilateral power supply contracts, the transactions of AEP’s nonregulated subsidiaries are reported as gross purchases or sales. Physical energy purchases arising from non-derivative contracts are accounted for on a gross basis in Purchased Electricity for Resale on the statements of income. Energy purchases arising from non-trading derivative contracts are recorded based on the transaction’s facts and circumstances. 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. Realized gains and losses on cash flow hedges are recorded in Total Revenues or Purchased Electricity depending on the nature of the risk being hedged. Derivative purchases elected normal used to serve accrual based obligations are recorded in Purchased Electricity on the statements of income. All other non-trading derivative purchases are recorded net in revenues. In general, the Registrants record expenses when purchased electricity is received and when expenses are incurred, with the exception of certain power purchase contracts that are derivatives and accounted for using MTM accounting where generation/supply rates are not cost-based regulated. In jurisdictions where the generation/supply business is subject to cost-based regulation, the unrealized MTM amounts are deferred as regulatory assets (for losses) and regulatory liabilities (for gains). Energy Marketing and Risk Management Activities (Applies to all Registrants except AEPTCo) The Registrants engage in power, capacity and, to a lesser extent, natural gas marketing as major power producers and participants in electricity and natural gas markets. The Registrants also engage in power, capacity, coal, natural gas and, to a lesser extent, heating oil, gasoline and other commodity risk management activities focused on markets where the AEP System owns assets and on adjacent markets. These activities include the purchase-and-sale of energy under forward contracts at fixed and variable prices. These contracts include physical transactions, exchange-traded futures, and to a lesser extent, OTC swaps and options. Certain energy marketing and risk management transactions are with RTOs. The Registrants recognize revenues from marketing and risk management transactions that are not derivatives as the performance obligation of delivering the commodity is satisfied. Expenses from marketing and risk management transactions that are not derivatives are also recognized upon delivery of the commodity. The Registrants use MTM accounting for marketing and risk management transactions that are derivatives unless the derivative is designated in a qualifying cash flow hedge relationship or elected normal under the normal purchase normal sale election. Unrealized MTM gains and losses are included on the balance sheets as Risk Management Assets or Liabilities, as appropriate, and on the statements of income in Total Revenues. Realized gains and losses on marketing and risk management transactions are included in revenues or expenses based on the transaction’s facts and circumstances. However, in regulated jurisdictions subject to cost-based regulation, unrealized MTM amounts and some realized gains and losses are deferred as regulatory assets (for losses) and regulatory liabilities (for gains).
Levelization of Nuclear Refueling Outage Costs	In accordance with regulatory orders, I&M defers incremental operation and maintenance costs associated with periodic refueling outages at its Cook Plant and amortizes the costs over approximately 18 months, beginning with the month following the start of each unit’s refueling outage and lasting until the end of the month in which the same unit’s next scheduled refueling outage begins.
Maintenance	The Registrants expense maintenance costs as incurred. If it becomes probable that the Registrants will recover specifically-incurred costs through future rates, a regulatory asset is established to match the expensing of those maintenance costs with their recovery in cost-based regulated revenues. In certain regulated jurisdictions, the Registrants defer costs above the level included in base rates and amortize those deferrals commensurate with recovery through rate riders.
Income Taxes and Investment and Production Tax Credits	The Registrants use the liability method of accounting for income taxes. Under the liability method, deferred income taxes are provided for all temporary differences between the book and tax basis of assets and liabilities which will result in a future tax consequence. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which the temporary differences are expected to be recovered or settled. When the flow-through method of accounting for temporary differences is required by a regulator to be reflected in regulated revenues (that is, when deferred taxes are not included in the cost-of-service for determining regulated rates for electricity), deferred income taxes are recorded and related regulatory assets and liabilities are established to match the regulated revenues and tax expense. AEP and subsidiaries apply the deferral methodology for the recognition of ITCs. Deferred ITCs are amortized to income tax expense over the life of the asset that generated the credit. Amortization of deferred ITCs begins when the asset is placed in-service, except where regulatory commissions reflect ITCs in the rate-making process, then amortization begins when the utility is able to utilize the ITC on a stand-alone basis. Alternatively, PTCs reduce income tax expense as they are earned. PTCs are earned when electricity is produced. Absent IRS guidance on the calculation of “gross receipts”, the Nuclear PTC recognized is based on electricity produced and an estimate of gross receipts. If, and when, IRS guidance is issued, the value of the Nuclear PTC will be updated to reflect such guidance, if necessary. Transferable tax credits established by the IRA are accounted for in accordance with the accounting guidance for “Income Taxes” by the Registrants. Proceeds from sales of transferable tax credits are included as a component of Operating Activities on the statement of cash flows and presented as gross within the Supplementary Cash Flow Information. The Registrants account for uncertain tax positions in accordance with the accounting guidance for “Income Taxes.” The Registrants classify interest expense or income related to uncertain tax positions as interest expense or income as appropriate and classify penalties as Other Operation expense on the statements of income. AEP and subsidiaries join in the filing of a consolidated federal income tax return. The benefit of current tax loss of the parent company (Parent Company Loss Benefit) to the AEP System subsidiaries is accounted for as an allocation through equity. The consolidated NOL of the AEP System is allocated to each company in the consolidated group with taxable loss. With the exception of the allocation of the consolidated AEP System NOL, Parent Company Loss Benefit and general business tax credits, the method of allocation reflects a separate return result for each company in the consolidated group.
Excise Taxes	As agents for some state and local governments, the Registrants collect from customers certain excise taxes levied by those state or local governments on customers. The Registrants do not record these taxes as revenue or expense.
Debt	Gains and losses from the reacquisition of debt used to finance regulated electric utility assets are deferred and amortized over the remaining term of the reacquired debt in accordance with their rate-making treatment unless the debt is refinanced. If the reacquired debt associated with the regulated business is refinanced, the reacquisition costs attributable to the portions of the business that are subject to cost-based regulatory accounting are generally deferred and amortized over the term of the replacement debt consistent with its recovery in rates. Operations not subject to cost-based rate regulation report gains and losses on the reacquisition of debt in Interest Expense on the statements of income upon reacquisition. Debt discounts, premiums and debt issuance expenses are deferred and amortized generally utilizing the straight-line method over the term of the related debt. The straight-line method approximates the effective interest method and is consistent with the treatment in rates for regulated operations. The net amortization expense is included in Interest Expense on the statements of income.
Pension and OPEB Plans	AEPSC sponsors a qualified pension plan and two unfunded non-qualified pension plans.  Substantially all AEP subsidiary employees are covered by the qualified plan or both the qualified and a non-qualified pension plan.  AEPSC also sponsors OPEB plans to provide health and life insurance benefits for retired employees.  The Registrant Subsidiaries account for their participation in the AEPSC sponsored pension and OPEB plans using multiple-employer accounting.
Investments Held in Trust for Future Liabilities	AEP has several trust funds with significant investments intended to provide for future payments of pension and OPEB benefits, nuclear decommissioning and SNF disposal. All of the trust funds’ investments are diversified and managed in compliance with all laws and regulations. The investment strategy for the trust funds is to use a diversified portfolio of investments to achieve an acceptable rate of return while managing the investment risk of the assets relative to the associated liabilities. To minimize investment risk, the trust funds are broadly diversified among classes of assets, investment strategies and investment managers. Management regularly reviews the actual asset allocations and periodically rebalances the investments to targeted allocations when appropriate. Investment policies and guidelines allow investment managers in approved strategies to use financial derivatives to obtain or manage market exposures and to hedge assets and liabilities. The investments are reported at fair value under the “Fair Value Measurements and Disclosures” accounting guidance. Benefit Plans All benefit plan assets are invested in accordance with each plan’s investment policy. The investment policy outlines the investment objectives, strategies and target asset allocations by plan. The investment philosophies for AEP’s benefit plans support the allocation of assets to minimize risks and optimize net returns. Strategies used include: • Maintaining a long-term investment horizon. • Diversifying assets to help control volatility of returns at acceptable levels. • Managing fees, transaction costs and tax liabilities to maximize investment earnings. • Using active management of investments where appropriate risk/return opportunities exist. • Keeping portfolio structure style-neutral to limit volatility compared to applicable benchmarks. • Using alternative asset classes such as real estate and private equity to maximize return and provide additional portfolio diversification. The objective of the investment policy for the pension fund is to maintain the funded status of the plan while providing for growth in the plan assets to offset the growth in the plan liabilities. The current target asset allocations are as follows: Pension Plan Assets Target Equity 35 % Fixed Income 49 % Other Investments 15 % Cash and Cash Equivalents 1 % OPEB Plans Assets Target Equity 67 % Fixed Income 32 % Cash and Cash Equivalents 1 % The investment policy for each benefit plan contains various investment limitations. The investment policies establish concentration limits for securities and prohibit the purchase of securities issued by AEP (with the exception of proportionate and immaterial holdings of AEP securities in passive index strategies or certain commingled funds). However, the investment policies do not preclude the benefit trust funds from receiving contributions in the form of AEP securities, provided that the AEP securities acquired by each plan may not exceed the limitations imposed by law. For equity investments, the concentration limits are generally as follows: • No security in excess of 5% of the outstanding class of equity of any one company. • Cash equivalents must be less than 10% of an investment manager’s equity portfolio. • No securities may be bought or sold on margin or other use of leverage. For fixed income investments, each investment manager’s portfolio is compared to investment grade, diversified benchmark indices. A portion of the pension assets is invested in real estate funds to provide diversification, add return and hedge against inflation. Real estate properties are illiquid, difficult to value and not actively traded. The pension plan uses external real estate investment managers to invest in commingled funds that hold real estate properties. To mitigate investment risk in the real estate portfolio, commingled real estate funds are used to ensure that holdings are diversified by region, property type and risk classification. Real estate holdings include core, value-added and opportunistic classifications. A portion of the pension assets is invested in private equity. Private equity investments add return and provide diversification and typically require a long-term time horizon to evaluate investment performance. Private equity is classified as an alternative investment because it is illiquid, difficult to value and not actively traded. The pension plan uses limited partnerships to invest across the private equity investment spectrum. The private equity holdings are with multiple general partners who help monitor the investments and provide investment selection expertise. The holdings are currently comprised of venture capital, buyout and hybrid debt and equity investments. AEP participates in a securities lending program with BNY Mellon to provide incremental income on idle assets and to provide income to offset custody fees and other administrative expenses. AEP lends securities to borrowers approved by BNY Mellon in exchange for collateral. All loans are collateralized by at least 102% of the loaned asset’s market value and the collateral is invested. The difference between the rebate owed to the borrower and the collateral rate of return determines the earnings on the loaned security. The securities lending program’s objective is to provide modest incremental income with a limited increase in risk. As of December 31, 2024 and 2023, the fair value of securities on loan as part of the program was $60 million and $62 million, respectively. Cash and securities obtained as collateral exceeded the fair value of the securities loaned as of December 31, 2024 and 2023. Trust owned life insurance (TOLI) underwritten by The Prudential Insurance Company is held in the OPEB plan trusts. The strategy for holding life insurance contracts in the taxable Voluntary Employees’ Beneficiary Association trust is to minimize taxes paid on the asset growth in the trust. Earnings on plan assets are tax-deferred within the TOLI contract and can be tax-free if held until claims are paid. Life insurance proceeds remain in the trust and are used to fund future retiree medical benefit liabilities. With consideration to other investments held in the trust, the cash value of the TOLI contracts is invested in two diversified funds. A portion is invested in a commingled fund with underlying investments in stocks that are actively traded on major international equity exchanges. The other portion of the TOLI cash value is invested in a diversified, commingled fixed income fund with underlying investments in government bonds, corporate bonds and asset-backed securities. Cash and cash equivalents are held in each trust to provide liquidity and meet short-term cash needs. Cash equivalent funds are used to provide diversification and preserve principal. The underlying holdings in the cash funds are investment grade money market instruments including commercial paper, certificates of deposit, treasury bills and other types of investment grade short-term debt securities. Nuclear Trust Funds (Applies to AEP and I&M) Nuclear decommissioning and SNF trust funds represent funds that regulatory commissions allow I&M to collect through rates to fund future decommissioning and SNF disposal liabilities. By rules or orders, the IURC, the MPSC and the FERC established investment limitations and general risk management guidelines. In general, limitations include: • Acceptable investments (rated investment grade or above when purchased). • Maximum percentage invested in a specific type of investment. • Prohibition of investment in obligations of AEP, I&M or their affiliates. • Withdrawals permitted only for payment of decommissioning costs and trust expenses. I&M maintains trust funds for each regulatory jurisdiction. Regulatory approval is required to withdraw decommissioning funds. These funds are managed by an external investment manager that must comply with the guidelines and rules of the applicable regulatory authorities. The trust assets are invested to optimize the net of tax earnings of the trust giving consideration to liquidity, risk, diversification and other prudent investment objectives. I&M records securities held in these trust funds in Spent Nuclear Fuel and Decommissioning Trusts on its balance sheets. I&M records these securities at fair value. I&M classifies debt securities in the trust funds as available-for-sale due to their long-term purpose.
Comprehensive Income (Loss)	Comprehensive income (loss) is defined as the change in equity (net assets) of a business enterprise during a period from transactions and other events and circumstances from non-owner sources. It includes all changes in equity during a period except those resulting from investments by owners and distributions to owners. Comprehensive income (loss) has two components: net income (loss) and other comprehensive income (loss).
Stock-Based Compensation Plans	As of December 31, 2024, AEP had performance shares and restricted stock units outstanding under the American Electric Power System 2024 Long-Term Incentive Plan (2024 LTIP) and the American Electric Power System 2015 Long-Term Incentive Plan (2015 LTIP). Upon vesting, all outstanding performance shares and restricted stock units settle in AEP common stock. The impact of AEP’s stock-based compensation plan is insignificant to the financial statements of the Registrant Subsidiaries. AEP maintains a variety of tax qualified and non-qualified deferred compensation plans for employees and non-employee directors that include, among other options, an investment in or an investment return equivalent to that of AEP common stock. This includes AEP career shares maintained under the American Electric Power System Stock Ownership Requirement Plan (SORP), which facilitates executives in meeting minimum stock ownership requirements assigned to them by the Human Resources Committee of the Board of Directors. AEP career shares are derived from vested performance shares granted to employees under a long-term incentive plan. AEP career shares accrue additional dividend shares in an amount equal to dividends paid on AEP common shares at the closing market price on the dividend payments date. All AEP career shares are settled in shares of AEP common stock after the executive’s service with AEP ends. Performance shares are classified as temporary equity in the Mezzanine Equity section of the balance sheets until the awards vest. Upon vesting, the performance shares are classified as permanent equity. These awards may be settled in cash upon an employee’s qualifying termination due to a change in control. Because such event is not solely within the control of the company, these awards are classified outside of permanent equity until the awards vest. AEP compensates non-employee directors, in part, with stock units under the American Electric Power Company, Inc. Stock Unit Accumulation Plan for Non-Employee Directors. Prior to June 2022, these stock units were payable in cash to directors after their service ended and are now payable in AEP common stock. Management measures and recognizes compensation expense for all share-based payment awards to employees and directors based on estimated fair values. For awards that are paid in shares with service only vesting conditions, management recognizes compensation expense on a straight-line basis. Stock-based compensation expense recognized on the statements of income for the years ended December 31, 2024, 2023 and 2022 is based on the number of outstanding awards at the end of each period without a reduction for estimated forfeitures. AEP accounts for forfeitures in the period in which they occur.
Equity Method Investments in Unconsolidated Entities	The equity method of accounting is used for equity investments where either AEP or SWEPCo exercise significant influence but do not hold a controlling financial interest. Such investments are initially recorded at cost in Deferred Charges and Other Noncurrent Assets on the balance sheets. The proportionate share of the investee’s equity earnings or losses is included in Equity Earnings (Loss) of Unconsolidated Subsidiaries on the statements of income. AEP and SWEPCo regularly monitor and evaluate equity method investments to determine whether they are impaired. An impairment is recognized when the investment has experienced a loss in value that is other-than-temporary in nature.
Earnings Per Share (EPS)	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.
New Accounting Standards	NEW ACCOUNTING STANDARDS The disclosures in this note apply to all Registrants unless indicated otherwise. Management reviews the FASB’s standard-setting process and the SEC’s rulemaking activity to determine the relevance, if any, to the Registrants’ business. The following standards/rules will impact the Registrants’ financial statements. SEC Climate Disclosure Rule On March 6, 2024, the SEC adopted final rules that require registrants to disclose certain climate-related information in registration statements and annual reports. The final rules require registrants to disclose, among other things, material climate-related risks, activities to mitigate such risks and information about a registrant’s board of directors oversight and management’s role in managing material climate-related risks. The final rules also require registrants to provide information related to any climate-related targets or goals that are material to a registrant’s business, results of operations or financial condition. A majority of the reporting requirements are applicable to the fiscal year beginning in 2025, with the addition of assurance reporting for GHG emissions starting in 2029 for large accelerated filers. Litigation challenging the new rules was filed by multiple parties in multiple jurisdictions, which have been consolidated and assigned to the U.S. Court of Appeals for the Eighth Circuit. On April 4, 2024, the SEC issued an order staying the final climate disclosure rules pending the completion of judicial review at the Court of Appeals. The Registrants are currently evaluating the impact of the final rules on their respective consolidated financial statements and related disclosures. ASU 2023-07 “Improvements to Reportable Segment Disclosures” (ASU 2023-07) In November 2023, the FASB issued ASU 2023-07, to address investors’ observations that there is limited information disclosed about segment expenses and to better understand expense categories and amounts included in segment profit or loss. The new standard requires annual and interim disclosure of (a) the categories and amounts of significant segment expenses (determined by management using both qualitative and quantitative factors) that are regularly provided to the CODM and included within each reported measure of segment profit or loss, (b) the amounts and a qualitative description of “other segment items”, defined as the difference between reported segment revenues less the significant segment expenses and each reported measure of segment profit or loss disclosed, (c) reportable segment profit or loss and assets that are currently only required annually, (d) the CODM’s title and position, and an explanation of how the CODM uses the reported measure(s) of segment profit or loss in assessing segment performance and deciding how to allocate resources and (e) a requirement that entities with a single reportable segment provide all disclosures required by ASU 2023-07 and all existing segment disclosures in Topic 280. Additionally, this new standard allows disclosure of one or more of additional profit or loss measures if the CODM uses more than one measure provided that at least one of the disclosed measures is determined in a manner “most consistent with the measurement principles under GAAP”. If multiple measures are presented, additional disclosure is required about how the CODM uses each measure to assess performance and decide how to allocate resources. Management adopted ASU 2023-07 and its related implementation guidance effective January 1, 2024 for the annual reporting period and applied the amendments retrospectively to all prior periods presented in the consolidated financial statements. The amendments for interim periods will be adopted in our fiscal year beginning on January 1, 2025. The adoption of the new standard did not impact the results of operations, statements of financial position or cash flows. See Note 9 - Business Segments for additional information. ASU 2023-09 “Improvements to Income Tax Disclosures” (ASU 2023-09) In December 2023, the FASB issued ASU 2023-09, to address investors’ suggested enhancements to (a) better understand an entity’s exposure to potential changes in jurisdictional tax legislation and the ensuing risks and opportunities, (b) assess income tax information that affects cash flow forecasts and capital allocation decisions and (c) identify potential opportunities to increase future cash flows. The new standard requires an annual rate reconciliation disclosure of the following categories regardless of materiality: state and local income tax, net of federal income tax effect, foreign tax effects, effect of changes in tax laws or rates enacted in the current period, effect of cross-border tax laws, tax credits, changes in valuation allowances, nontaxable or nondeductible items and changes in unrecognized tax benefits. The new standard also requires an annual disclosure of the amount of income taxes paid (net of refunds received) disaggregated by federal, state and foreign taxes and by individual jurisdictions that are equal to or greater than 5 percent of total income taxes paid. Disclosure of income (loss) from continuing operations before income tax expense (benefit) disaggregated between domestic and foreign jurisdictions and income tax expense (benefit) from continuing operations disaggregated by federal, state and foreign jurisdictions is required. The new standard removes the requirement to disclose the cumulative amount of each type of temporary difference when a deferred tax liability is not recognized because of the exceptions to comprehensive recognition of deferred taxes related to subsidiaries and corporate joint ventures. The amendments in the new standard may be applied on either a prospective or retrospective basis for public business entities for fiscal years beginning after December 15, 2024 with early adoption permitted. Management has concluded to adopt the amendments to this standard prospectively beginning on January 1, 2025. ASU 2024-03 “Income Statement-Reporting Comprehensive Income-Expense Disaggregation Disclosures” (ASU 2024-03) In November 2024, the FASB issued ASU 2024-03, the intent of which is to improve financial reporting and respond to investor input by requiring public business entities to disclose additional information about certain expenses in the notes to financial statements in interim and annual reporting periods. Among other provisions, the new standard requires disclosure of disaggregated amounts for expenses such as employee compensation, depreciation, and intangible asset amortization included in each expense caption presented on the face of the income statement. Public business entities are required to include certain amounts that are already required to be disclosed under GAAP in the same disclosure as the other disaggregation requirements as well as a qualitative description of any amounts remaining in relevant expense captions that are not separately disaggregated quantitatively. The new standard also requires disclosure of the total amount of selling expenses and, in annual reporting periods, an entity’s definition of selling expenses. An entity is not precluded from providing additional voluntary disclosures that may provide investors with additional decision-useful information.
Lease	The Registrants lease property, plant and equipment including, but not limited to, fleet, information technology and real estate leases. These leases require payments of non-lease components, including related property taxes, operating and maintenance costs. AEP does not separate non-lease components from associated lease components. Many of these leases have purchase or renewal options. Leases not renewed are often replaced by other leases. Options to renew or purchase a lease are included in the measurement of lease assets and liabilities if it is reasonably certain the Registrant will exercise the option. Lease obligations are measured using the discount rate implicit in the lease when that rate is readily determinable. AEP has visibility into the rate implicit in the lease when assets are leased from selected financial institutions under master leasing agreements. When the implicit rate is not readily determinable, the Registrants measure their lease obligation using their estimated secured incremental borrowing rate. Incremental borrowing rates are comprised of an underlying risk-free rate and a secured credit spread relative to the lessee on a matched maturity basis.

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities (Policies)	12 Months Ended
	Dec. 31, 2024
Derivative Instruments and Hedging Activities Disclosure [Abstract]
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. Realized gains and losses on derivative contracts for the purchase and sale of power designated as cash flow hedges are included in Total Revenues or Purchased Electricity, Fuel and Other Consumables Used for Electric Generation on the statements of income or in Regulatory Assets or Regulatory Liabilities on the balance sheets, depending on the specific nature of the risk being hedged. During the years ended 2024, 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 year ended 2024, AEP, AEP Texas and PSO applied cash flow hedging to outstanding interest rate derivatives and the other Registrant Subsidiaries did not. During the year ended 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 year ended 2022, AEP and PSO applied cash flow hedging to outstanding interest rate derivatives and the other Registrant Subsidiaries did not. 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) A limited number of derivative contracts include collateral triggering events, which include a requirement to maintain certain credit ratings. On an ongoing basis, AEP’s risk management organization assesses the appropriateness of these collateral triggering events in contracts. The Registrants have not experienced a downgrade below a specified credit rating threshold that would require the posting of additional collateral. The total exposure of AEP’s derivative contracts with collateral triggering events in a net liability position was immaterial as of December 31, 2024 and 2023. The Registrant Subsidiaries had no derivative contracts with collateral triggering events in a net liability position as of December 31, 2024 and 2023. Cross-Acceleration Triggers (Applies to AEP) Cross-Default Triggers (Applies to AEP, APCo, PSO and SWEPCo)

ORGANIZATION AND SUMMARY OF S_3

ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	12 Months Ended
	Dec. 31, 2024
Accounting Policies [Abstract]
Schedule of Cash and Cash Equivalents	The following tables provide a reconciliation of Cash, Cash Equivalents and Restricted Cash reported within the balance sheets that sum to the total of the same amounts shown on the statement of cash flows: AEP AEP Texas APCo SWEPCo Year Ended December 31, 2024 2023 2024 2023 2024 2023 2024 2023 (in millions) Cash and Cash Equivalents $ 202.9 $ 330.1 $ 0.1 $ 0.1 $ 3.9 $ 5.0 $ 1.2 $ 2.4 Restricted Cash 43.1 48.9 23.5 34.0 16.2 14.9 3.4 — Total Cash, Cash Equivalents and Restricted Cash $ 246.0 $ 379.0 $ 23.6 $ 34.1 $ 20.1 $ 19.9 $ 4.6 $ 2.4
Restrictions on Cash and Cash Equivalents	The following tables provide a reconciliation of Cash, Cash Equivalents and Restricted Cash reported within the balance sheets that sum to the total of the same amounts shown on the statement of cash flows: AEP AEP Texas APCo SWEPCo Year Ended December 31, 2024 2023 2024 2023 2024 2023 2024 2023 (in millions) Cash and Cash Equivalents $ 202.9 $ 330.1 $ 0.1 $ 0.1 $ 3.9 $ 5.0 $ 1.2 $ 2.4 Restricted Cash 43.1 48.9 23.5 34.0 16.2 14.9 3.4 — Total Cash, Cash Equivalents and Restricted Cash $ 246.0 $ 379.0 $ 23.6 $ 34.1 $ 20.1 $ 19.9 $ 4.6 $ 2.4
Significant Customers	AEP Texas had significant customers which account for the following percentages of Total Revenues for the years ended December 31 and Accounts Receivable – Customers as of December 31: Significant Customers of AEP Texas: NRG Energy and TXU Energy 2024 2023 2022 Percentage of Total Revenues 40 % 41 % 45 % Percentage of Accounts Receivable – Customers 37 % 34 % 42 % AEPTCo had significant transactions with AEP Subsidiaries which on a combined basis account for the following percentages of Total Revenues for the years ended December 31 and Total Accounts Receivable as of December 31: Significant Customers of AEPTCo: AEP Subsidiaries 2024 2023 2022 Percentage of Total Revenues 80 % 79 % 79 % Percentage of Total Accounts Receivable 69 % 60 % 72 %
Defined Benefit Plan, Plan Assets, Allocation	The current target asset allocations are as follows: Pension Plan Assets Target Equity 35 % Fixed Income 49 % Other Investments 15 % Cash and Cash Equivalents 1 % OPEB Plans Assets Target Equity 67 % Fixed Income 32 % Cash and Cash Equivalents 1 %
Schedule of Earnings Per Share, Basic and Diluted	The following table presents AEP’s basic and diluted EPS calculations included on the statements of income: Years Ended December 31, 2024 2023 2022 (in millions, except per-share data) $/share $/share $/share Earnings Attributable to AEP Common Shareholders $ 2,967.1 $ 2,208.1 $ 2,307.2 Weighted-Average Number of Basic AEP Common Shares Outstanding 530.1 $ 5.60 518.9 $ 4.26 511.8 $ 4.51 Weighted-Average Dilutive Effect of Stock-Based Awards 1.2 (0.02) 1.3 (0.02) 1.7 (0.02) Weighted-Average Number of Diluted AEP Common Shares Outstanding 531.3 $ 5.58 520.2 $ 4.24 513.5 $ 4.49
Supplementary Income Statement Information	The following tables provide the components of Depreciation and Amortization for the years ended December 31, 2024, 2023 and 2022: 2024 Depreciation and Amortization AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Depreciation and Amortization of Property, Plant and Equipment $ 3,148.6 $ 405.9 $ 430.9 $ 600.4 $ 456.2 $ 386.0 $ 263.1 $ 375.4 Amortization of Certain Securitized Assets 91.3 91.3 — — — — — — Amortization of Regulatory Assets and Liabilities 50.0 (3.7) — 2.0 24.9 — 9.1 13.9 Total Depreciation and Amortization $ 3,289.9 $ 493.5 $ 430.9 $ 602.4 $ 481.1 $ 386.0 $ 272.2 $ 389.3 2023 Depreciation and Amortization AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Depreciation and Amortization of Property, Plant and Equipment $ 2,927.5 $ 380.0 $ 393.8 $ 571.1 $ 439.8 $ 315.8 $ 240.3 $ 323.4 Amortization of Certain Securitized Assets 91.9 91.9 — — — — — — Amortization of Regulatory Assets and Liabilities 71.0 (3.4) — 0.8 30.2 0.4 15.2 19.4 Total Depreciation and Amortization $ 3,090.4 $ 468.5 $ 393.8 $ 571.9 $ 470.0 $ 316.2 $ 255.5 $ 342.8 2022 Depreciation and Amortization AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Depreciation and Amortization of Property, Plant and Equipment $ 3,072.8 $ 363.5 $ 346.2 $ 576.1 $ 511.9 $ 293.1 $ 226.2 $ 319.3 Amortization of Certain Securitized Assets 93.3 93.3 — — — — — — Amortization of Regulatory Assets and Liabilities 36.7 (4.4) — (0.2) 15.3 1.2 3.9 5.5 Total Depreciation and Amortization $ 3,202.8 $ 452.4 $ 346.2 $ 575.9 $ 527.2 $ 294.3 $ 230.1 $ 324.8
Supplementary Cash Flow Information	Years Ended December 31, Cash Flow Information 2024 2023 2022 (in millions) Cash Paid (Received) for: Interest, Net of Capitalized Amounts $ 1,837.8 $ 1,673.5 $ 1,286.3 Income Taxes 133.4 78.4 116.8 Sale of Transferable Tax Credits (202.0) (102.0) — Noncash Investing and Financing Activities: Acquisitions Under Finance Leases 29.5 48.7 31.8 Construction Expenditures Included in Current Liabilities as of December 31, 1,312.0 842.4 1,258.9 Acquisition of Nuclear Fuel Included in Current Liabilities as of December 31, 23.5 24.2 — Noncash Increase in Noncurrent Assets from the Sale of the Competitive Contracted Renewables Portfolio — 74.7 —

COMPREHENSIVE INCOME (Tables)

COMPREHENSIVE INCOME (Tables)	12 Months Ended
	Dec. 31, 2024
Stockholders' Equity Note [Abstract]
Changes in Accumulated Other Comprehensive Income (Loss) by Component	The following tables provide AEP’s components of changes in AOCI and details of reclassifications from AOCI for the years ended December 31, 2024, 2023 and 2022. The amortization of pension and OPEB AOCI components are included in the computation of net periodic pension and OPEB costs. See Note 8 - Benefit Plans for additional information. Cash Flow Hedges Pension and OPEB For the Year Ended December 31, 2024 Commodity Interest Rate Amortization of Deferred Costs Changes in Funded Status Total (in millions) Balance in AOCI as of December 31, 2023 $ 104.9 $ (8.1) $ 92.6 $ (244.9) $ (55.5) Change in Fair Value Recognized in AOCI, Net of Tax 2.5 7.1 — 41.0 50.6 Amount of (Gain) Loss Reclassified from AOCI Purchased Electricity, Fuel and Other Consumables Used for Electric Generation (a) (11.2) — — — (11.2) Interest Expense (a) — 5.3 — — 5.3 Amortization of Prior Service Cost (Credit) — — (5.4) — (5.4) Amortization of Actuarial (Gains) Losses — — 2.2 — 2.2 Recognition of Pension Settlement Costs — — 11.3 — 11.3 Reclassifications from AOCI, before Income Tax (Expense) Benefit (11.2) 5.3 8.1 — 2.2 Income Tax (Expense) Benefit (2.3) 1.0 1.7 — 0.4 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (8.9) 4.3 6.4 — 1.8 Net Current Period Other Comprehensive Income (Loss) (6.4) 11.4 6.4 41.0 52.4 Balance in AOCI as of December 31, 2024 $ 98.5 $ 3.3 $ 99.0 $ (203.9) $ (3.1) Cash Flow Hedges Pension and OPEB For the Year Ended December 31, 2023 Commodity Interest Rate Amortization of Deferred Costs Changes in Funded Status Total (in millions) Balance in AOCI as of December 31, 2022 $ 223.5 $ 0.3 $ 105.2 $ (245.3) $ 83.7 Change in Fair Value Recognized in AOCI, Net of Tax (175.8) (6.4) — (16.3) (198.5) Amount of (Gain) Loss Reclassified from AOCI Purchased Electricity, Fuel and Other Consumables Used for Electric Generation (a) 72.2 — — — 72.2 Interest Expense (a) — (2.4) — — (2.4) Amortization of Prior Service Cost (Credit) — — (21.2) — (21.2) Amortization of Actuarial (Gains) Losses — — 5.2 — 5.2 Reclassifications from AOCI, before Income Tax (Expense) Benefit 72.2 (2.4) (16.0) — 53.8 Income Tax (Expense) Benefit 15.0 (0.4) (3.4) — 11.2 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 57.2 (2.0) (12.6) — 42.6 Reclassifications of KPCo Pension and OPEB Regulatory Assets to 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 to AOCI, Net of Income Tax (Expense) Benefit — — — 16.7 16.7 Net Current Period Other Comprehensive Income (Loss) (118.6) (8.4) (12.6) 0.4 (139.2) Balance in AOCI as of December 31, 2023 $ 104.9 $ (8.1) $ 92.6 $ (244.9) $ (55.5) Cash Flow Hedges Pension and OPEB For the Year Ended December 31, 2022 Commodity Interest Rate Amortization of Deferred Costs Changes in Funded Status Total (in millions) Balance in AOCI as of December 31, 2021 $ 163.7 $ (21.3) $ 115.6 $ (73.2) $ 184.8 Change in Fair Value Recognized in AOCI, Net of Tax 477.3 18.4 — (155.4) 340.3 Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (a) 0.1 — — — 0.1 Purchased Electricity, Fuel and Other Consumables Used for Electric Generation (a) (528.6) — — — (528.6) Interest Expense (a) — 4.0 — — 4.0 Amortization of Prior Service Cost (Credit) — — (21.8) — (21.8) Amortization of Actuarial (Gains) Losses — — 8.6 — 8.6 Reclassifications from AOCI, before Income Tax (Expense) Benefit (528.5) 4.0 (13.2) — (537.7) Income Tax (Expense) Benefit (111.0) 0.8 (2.8) — (113.0) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (417.5) 3.2 (10.4) — (424.7) Reclassifications of KPCo Pension and OPEB Regulatory Assets to 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 to AOCI, Net of Income Tax (Expense) Benefit — — — (16.7) (16.7) Net Current Period Other Comprehensive Income (Loss) 59.8 21.6 (10.4) (172.1) (101.1) Balance in AOCI as of December 31, 2022 $ 223.5 $ 0.3 $ 105.2 $ (245.3) $ 83.7 (a)

RATE MATTERS (Tables)

RATE MATTERS (Tables)	12 Months Ended
	Dec. 31, 2024
Public Utilities, General Disclosures [Abstract]
Natural Gas Expenses and Purchases of Electricity to be Recovered from Customers	For the time period of February 9, 2021, to February 20, 2021, SWEPCo’s natural gas expenses and purchases of electricity still to be recovered from customers are shown in the table below: December 31, Approved Approved Jurisdiction 2024 2023 Recovery Period Carrying Charge (in millions) Arkansas $ 37.2 $ 54.2 6 years (a) Louisiana 70.6 97.2 (b) (b) Texas 72.7 101.9 5 years 1.65% Total $ 180.5 $ 253.3 (a) SWEPCo is permitted to record carrying costs on the unrecovered balance of fuel costs at a weighted-cost of capital approved by the APSC. In August 2024, the APSC issued an order that found SWEPCo had prudently incurred these costs. (b) In March 2021, the LPSC approved a special order granting a temporary modification to the FAC and shortly after SWEPCo began recovery of its Louisiana jurisdictional share of these fuel costs based on a five-year recovery period inclusive of an interim carrying charge equal to the prime rate. The special order states the fuel and purchased power costs incurred will be subject to a future LPSC audit.

EFFECTS OF REGULATION (Tables)

EFFECTS OF REGULATION (Tables)	12 Months Ended
	Dec. 31, 2024
Regulatory Assets and Liabilities Disclosure [Abstract]
Regulatory Assets, Early Retirement	The table below summarizes the net book value including CWIP, before cost of removal and materials and supplies, as of December 31, 2024, of generating facilities planned for early retirement: Plant Net Book Value Accelerated Depreciation Regulatory Asset Cost of Removal Projected Current Authorized Annual (dollars in millions) Northeastern Plant, Unit 3 $ 101.7 $ 189.0 $ 21.0 (b) 2026 (c) $ 16.2 Welsh Plant, Units 1 and 3 324.3 168.6 57.6 (d) 2028 (e) (f) 43.6 (a) Represents the amount of annual depreciation that has been collected from customers over the prior 12-month period. (b) Includes Northeastern Plant, Unit 4, which was retired in 2016. Removal of Northeastern Plant, Unit 4, will be performed with the removal of Northeastern Plant, Unit 3, after retirement. (c) Northeastern Plant, Unit 3 is currently being recovered through 2040. (d) Includes Welsh Plant, Unit 2, which was retired in 2016. Removal of Welsh Plant, Unit 2, will be performed with the removal of Welsh Plant, Units 1 and 3, after retirement. (e) Represents projected retirement date of coal assets. (f)
Regulatory Assets	AEP December 31, Remaining Recovery Period 2024 2023 Current Regulatory Assets (in millions) Under-recovered Fuel Costs - earns a return $ 245.7 $ 357.4 1 year Under-recovered Fuel Costs - does not earn a return 116.0 62.7 1 year Unrecovered Winter Storm Fuel Costs - earns a return (a) 84.2 93.9 1 year Total Current Regulatory Assets $ 445.9 $ 514.0 Noncurrent Regulatory Assets Regulatory assets pending final regulatory approval: Regulatory Assets Currently Earning a Return Welsh Plant, Units 1 and 3 Accelerated Depreciation $ 168.6 $ 125.6 Pirkey Plant Accelerated Depreciation 121.3 114.4 Storm-Related Costs 51.0 — Unrecovered Winter Storm Fuel Costs (a) 33.5 60.1 Other Regulatory Assets Pending Final Regulatory Approval 20.7 49.8 Total Regulatory Assets Currently Earning a Return 395.1 349.9 Regulatory Assets Currently Not Earning a Return Plant Retirement Costs - Asset Retirement Obligation Costs (b) 357.4 25.9 Storm-Related Costs 300.8 408.9 NOLC - Costs (c) 92.8 — 2024-2025 Virginia Under-Earnings 78.4 — Other Regulatory Assets Pending Final Regulatory Approval 86.3 52.6 Total Regulatory Assets Currently Not Earning a Return 915.7 487.4 Total Regulatory Assets Pending Final Regulatory Approval 1,310.8 837.3 Regulatory assets approved for recovery: Regulatory Assets Currently Earning a Return Plant Retirement Costs - Unrecovered Plant (d) 661.2 664.2 22 years Long-term Under-recovered Fuel Costs - West Virginia 283.8 291.5 10 years Plant Retirement Costs - Asset Retirement Obligation Costs 111.0 110.8 16 years Storm-Related Costs 106.7 170.9 7 years Fuel Mine Closure Costs - Texas 70.6 74.3 11 years Pirkey Plant Accelerated Depreciation - Louisiana 66.4 65.8 8 years Unrecovered Winter Storm Fuel Costs (a) 62.8 99.3 3 years Kentucky Deferred Purchased Power Expenses 45.0 43.5 3 years Rockport Plant Dry Sorbent Injection System and Selective Catalytic Reduction 37.3 46.9 4 years Texas Mobile Temporary Emergency Electric Energy Facilities Rider 32.6 33.4 2 years Environmental Control Projects 29.1 31.4 16 years Ohio Basic Transmission Cost Rider 26.1 42.2 2 years Plant Retirement Costs - Unrecovered Plant, Dolet Hills Power Station, Louisiana 19.0 40.8 8 years Long-term Under-recovered Fuel Costs - Virginia — 107.0 Other Regulatory Assets Approved for Recovery 159.9 124.9 various Total Regulatory Assets Currently Earning a Return 1,711.5 1,946.9 Regulatory Assets Currently Not Earning a Return Pension and OPEB Funded Status 974.2 1,054.1 12 years Plant Retirement Costs - Asset Retirement Obligation Costs 360.1 330.2 18 years Unamortized Loss on Reacquired Debt 90.9 97.2 24 years Storm-Related Costs 66.5 38.5 7 years Fuel and Purchased Power Adjustment Rider 57.4 68.3 2 years Unrealized Loss on Forward Commitments 53.3 131.4 8 years OVEC Purchased Power 52.0 50.1 2 years Plant Retirement Costs - Unrecovered Plant, Texas 44.5 48.7 22 years Cook Plant Nuclear Refueling Outage Levelization 43.0 55.7 3 years Smart Grid Costs 33.8 26.3 2 years Postemployment Benefits 27.9 30.6 3 years Ohio Enhanced Service Reliability Plan 26.2 35.3 2 years 2020-2022 Virginia Triennial Under Earnings 26.0 37.4 3 years Ohio Distribution Investment Rider 11.0 35.3 2 years Other Regulatory Assets Approved for Recovery 240.1 269.1 various Total Regulatory Assets Currently Not Earning a Return 2,106.9 2,308.2 Total Regulatory Assets Approved for Recovery 3,818.4 4,255.1 Total Noncurrent Regulatory Assets $ 5,129.2 $ 5,092.4 (a) See “February 2021 Severe Winter Weather Impacts in SPP” section of Note 4 for additional information. (b) See “Federal EPA’s Revised CCR Rule” section of Note 6 for additional information. (c) In the second quarter of 2024, requests seeking to establish a recovery mechanism for these regulatory assets were filed in Indiana, Oklahoma and Texas. In Indiana and Oklahoma, certain intervenors have challenged the recovery, or have proposed ratemaking treatment that would offset the recovery, of the regulatory assets. In the third quarter of 2024, PUCT Staff and certain intervenors in Texas requested a hearing and direct testimony was filed by SWEPCo in October 2024. In the fourth quarter of 2024, hearings on the merits were held in Indiana and Oklahoma. In January 2025, a second hearing on the merits in Oklahoma was held. A hearing is scheduled for the first quarter of 2025 in Texas. (d) Northeastern Plant, Unit 3 is approved for recovery through 2040, but expected to retire in 2026. PSO records a regulatory asset for accelerated depreciation. See “Regulated Generating Units to be Retired” section above for additional information. AEP Texas December 31, Remaining Regulatory Assets: 2024 2023 (in millions) Noncurrent Regulatory Assets Regulatory assets pending final regulatory approval: Regulatory Assets Currently Earning a Return Storm-Related Costs $ 41.3 $ — Total Regulatory Assets Currently Earning a Return 41.3 — Regulatory Assets Currently Not Earning a Return Deferred Pension and OPEB Costs 15.6 — Storm-Related Costs 13.1 37.7 Line Inspection Costs 5.8 5.7 Other Regulatory Assets Pending Final Regulatory Approval 1.3 20.9 Total Regulatory Assets Currently Not Earning a Return 35.8 64.3 Total Regulatory Assets Pending Final Regulatory Approval 77.1 64.3 Regulatory assets approved for recovery: Regulatory Assets Currently Earning a Return Texas Mobile Temporary Emergency Electric Energy Facilities Rider 32.6 33.4 2 years Meter Replacement Costs 5.8 9.4 2 years Other Regulatory Assets Approved for Recovery 22.4 0.7 various Total Regulatory Assets Currently Earning a Return 60.8 43.5 Regulatory Assets Currently Not Earning a Return Pension and OPEB Funded Status 177.5 183.2 12 years Texas Transmission Cost Recovery Factor 14.2 — 2 years Peak Demand Reduction/Energy Efficiency 9.2 9.2 2 years Other Regulatory Assets Approved for Recovery 14.8 15.1 various Total Regulatory Assets Currently Not Earning a Return 215.7 207.5 Total Regulatory Assets Approved for Recovery 276.5 251.0 Total Noncurrent Regulatory Assets $ 353.6 $ 315.3 AEPTCo December 31, Remaining Regulatory Assets: 2024 2023 (in millions) Noncurrent Regulatory Assets Regulatory assets approved for recovery: Regulatory Assets Currently Not Earning a Return PJM/SPP Annual Formula Rate True-up $ 0.4 $ 3.1 2 years Total Regulatory Assets Approved for Recovery 0.4 3.1 Total Noncurrent Regulatory Assets $ 0.4 $ 3.1 APCo December 31, Remaining Regulatory Assets: 2024 2023 (in millions) Current Regulatory Assets Under-recovered Fuel Costs, Virginia - earns a return $ 148.1 $ 147.4 1 year Under-recovered Fuel Costs, West Virginia - does not earn a return — 8.0 1 year Total Current Regulatory Assets $ 148.1 $ 155.4 Noncurrent Regulatory Assets Regulatory assets pending final regulatory approval: Regulatory Assets Currently Earning a Return Other Regulatory Assets Pending Final Regulatory Approval $ 1.1 $ 0.6 Total Regulatory Assets Currently Earning a Return 1.1 0.6 Regulatory Assets Currently Not Earning a Return Plant Retirement Costs - Asset Retirement Obligation Costs (a) 282.1 25.9 Storm-Related Costs - West Virginia 144.2 91.5 2024-2025 Virginia Under-Earnings 78.4 — Pension Settlement 17.8 — Other Regulatory Assets Pending Final Regulatory Approval 11.9 7.5 Total Regulatory Assets Currently Not Earning a Return 534.4 124.9 Total Regulatory Assets Pending Final Regulatory Approval 535.5 125.5 Regulatory assets approved for recovery: Regulatory Assets Currently Earning a Return Long-term Under-recovered Fuel Costs - West Virginia 154.1 154.2 10 years Plant Retirement Costs - Unrecovered Plant 68.0 72.0 19 years Long-term Under-recovered Fuel Costs - Virginia — 107.0 Other Regulatory Assets Approved for Recovery 5.2 7.1 various Total Regulatory Assets Currently Earning a Return 227.3 340.3 Regulatory Assets Currently Not Earning a Return Plant Retirement Costs - Asset Retirement Obligation Costs 307.5 324.7 15 years Pension and OPEB Funded Status 107.9 115.8 12 years Unamortized Loss on Reacquired Debt 67.0 70.7 21 years 2020-2022 Virginia Triennial Under-Earnings 26.0 37.4 3 years Peak Demand Reduction/Energy Efficiency 14.2 15.0 2 years Postemployment Benefits 13.2 14.9 3 years Vegetation Management Program - West Virginia 11.9 12.9 2 years Virginia Generation Rate Adjustment Clause 11.6 10.9 2 years Excess SO 2 Allowance Inventory - Virginia 10.5 11.8 8 years Virginia Transmission Rate Adjustment Clause 3.4 25.5 2 years Unrealized Loss on Forward Commitments — 21.9 Other Regulatory Assets Approved for Recovery 30.0 27.8 various Total Regulatory Assets Currently Not Earning a Return 603.2 689.3 Total Regulatory Assets Approved for Recovery 830.5 1,029.6 Total Noncurrent Regulatory Assets $ 1,366.0 $ 1,155.1 (a) See “Federal EPA’s Revised CCR Rule” section of Note 6 for additional information. I&M December 31, Remaining Regulatory Assets: 2024 2023 (in millions) Current Regulatory Assets Under-recovered Fuel Costs, Michigan - earns a return $ 10.6 $ 14.8 1 year Total Current Regulatory Assets $ 10.6 $ 14.8 Noncurrent Regulatory Assets Regulatory assets pending final regulatory approval: Regulatory Assets Currently Earning a Return Other Regulatory Assets Pending Final Regulatory Approval $ 6.4 $ 0.2 Total Regulatory Assets Currently Earning a Return 6.4 0.2 Regulatory Assets Currently Not Earning a Return Plant Retirement Costs - Asset Retirement Obligation Costs (a) 74.0 — NOLC Costs - Indiana (b) 26.7 — Storm-Related Costs - Indiana 6.3 29.7 Other Regulatory Assets Pending Final Regulatory Approval 1.6 3.3 Total Regulatory Assets Currently Not Earning a Return 108.6 33.0 Total Regulatory Assets Pending Final Regulatory Approval 115.0 33.2 Regulatory assets approved for recovery: Regulatory Assets Currently Earning a Return Plant Retirement Costs - Unrecovered Plant 98.0 122.5 4 years Rockport Plant Dry Sorbent Injection System and Selective Catalytic Reduction 37.3 46.9 4 years Cook Plant Uprate Project 20.5 22.9 9 years Deferred Cook Plant Life Cycle Management Project Costs - Michigan, FERC 10.1 11.1 10 years Cook Plant Turbine - Indiana 7.8 8.4 14 years Other Regulatory Assets Approved for Recovery 21.1 17.5 various Total Regulatory Assets Currently Earning a Return 194.8 229.3 Regulatory Assets Currently Not Earning a Return Income Taxes, Net 108.8 — (c) Cook Plant Nuclear Refueling Outage Levelization 43.0 55.7 3 years Storm-Related Costs - Indiana 20.2 3.4 4 years Pension and OPEB Funded Status 14.6 25.4 12 years Excess SO 2 Allowance Inventory - Indiana 11.9 14.8 4 years Unamortized Loss on Reacquired Debt 10.9 11.8 24 years Postemployment Benefits 7.3 7.0 3 years Environmental Cost Rider - Indiana 1.4 8.1 2 years Other Regulatory Assets Approved for Recovery 20.2 17.6 various Total Regulatory Assets Currently Not Earning a Return 238.3 143.8 Total Regulatory Assets Approved for Recovery 433.1 373.1 Total Noncurrent Regulatory Assets $ 548.1 $ 406.3 (a) See “Federal EPA’s Revised CCR Rule” section of Note 6 for additional information. (b) In the second quarter of 2024, a request seeking to establish a recovery mechanism for these regulatory assets were filed in Indiana. Certain intervenors have challenged the recovery, or have proposed ratemaking treatment that would offset the recovery, of the regulatory assets. In the fourth quarter of 2024, a hearing on the merits was held in Indiana. (c) Recovered over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements was $12 million for the year ended December 31, 2024 and is to be refunded over 4 years. OPCo December 31, Remaining Regulatory Assets: 2024 2023 (in millions) Noncurrent Regulatory Assets Regulatory assets pending final regulatory approval: Regulatory Assets Currently Earning a Return Other Regulatory Assets Pending Final Regulatory Approval $ 0.4 $ — Total Regulatory Assets Currently Earning a Return 0.4 — Regulatory Assets Currently Not Earning a Return Other Regulatory Assets Pending Final Regulatory Approval 0.1 — Total Regulatory Assets Pending Final Regulatory Approval 0.1 23.6 Total Regulatory Assets Pending Final Regulatory Approval 0.5 23.6 Regulatory assets approved for recovery: Regulatory Assets Currently Earning a Return Ohio Basic Transmission Cost Rider 26.1 42.2 2 years Ohio Distribution Decoupling — 1.8 Total Regulatory Assets Currently Earning a Return 26.1 44.0 Regulatory Assets Currently Not Earning a Return Pension and OPEB Funded Status 134.0 147.1 12 years OVEC Purchased Power 52.0 50.1 2 years Unrealized Loss on Forward Commitments 47.6 50.8 8 years Smart Grid Costs 33.8 26.3 2 years Storm-Related Costs 28.6 30.9 2 years Ohio Enhanced Service Reliability Plan 26.2 35.3 2 years Bad Debt Rider 13.7 0.7 2 years Ohio Distribution Investment Rider 11.0 35.3 2 years Other Regulatory Assets Approved for Recovery 5.6 10.9 various Total Regulatory Assets Currently Not Earning a Return 352.5 387.4 Total Regulatory Assets Approved for Recovery 378.6 431.4 Total Noncurrent Regulatory Assets $ 379.1 $ 455.0 PSO December 31, Remaining 2024 2023 Regulatory Assets: (in millions) Current Regulatory Assets Under-recovered Fuel Costs - earns a return $ 64.7 $ 118.3 1 year Total Current Regulatory Assets $ 64.7 $ 118.3 Noncurrent Regulatory Assets Regulatory assets pending final regulatory approval: Regulatory Assets Currently Not Earning a Return NOLC - Costs (a) $ 16.4 $ — Storm-Related Costs 4.9 88.5 Other Regulatory Assets Pending Final Regulatory Approval 9.0 0.2 Total Regulatory Assets Pending Final Regulatory Approval 30.3 88.7 Regulatory assets approved for recovery: Regulatory Assets Currently Earning a Return Plant Retirement Costs - Unrecovered Plant (b) 274.0 254.1 22 years Storm-Related Costs 106.7 26.2 7 years Environmental Control Projects 21.2 22.5 16 years Meter Replacement Costs 10.1 14.1 3 years Other Regulatory Assets Approved for Recovery 13.4 8.4 various Total Regulatory Assets Currently Earning a Return 425.4 325.3 Regulatory Assets Currently Not Earning a Return Pension and OPEB Funded Status 57.6 62.6 12 years Unrealized Loss on Forward Commitments 3.9 29.9 2 years Other Regulatory Assets Approved for Recovery 10.6 16.2 various Total Regulatory Assets Currently Not Earning a Return 72.1 108.7 Total Regulatory Assets Approved for Recovery 497.5 434.0 Total Noncurrent Regulatory Assets $ 527.8 $ 522.7 (a) In the second quarter of 2024, a request seeking to establish a recovery mechanism for these regulatory assets was filed in Oklahoma. Certain intervenors have challenged the recovery, or have proposed ratemaking treatment that would offset the recovery, of the regulatory assets. In the fourth quarter of 2024 and in January 2025 hearings on the merits were held. (b) Northeastern Plant, Unit 3 is approved for recovery through 2040, but expected to retire in 2026. PSO records a regulatory asset for accelerated depreciation. See “Regulated Generating Units to be Retired” section above for additional information. SWEPCo December 31, Remaining 2024 2023 Regulatory Assets: (in millions) Current Regulatory Assets Unrecovered Winter Storm Fuel Costs - earns a return (a) $ 84.2 $ 93.9 1 year Under-recovered Fuel Costs - earns a return (b) 22.4 76.9 1 year Total Current Regulatory Assets $ 106.6 $ 170.8 Noncurrent Regulatory Assets Regulatory assets pending final regulatory approval: Regulatory Assets Currently Earning a Return Welsh Plant, Units 1 and 3 Accelerated Depreciation $ 168.6 $ 125.6 Pirkey Plant Accelerated Depreciation 121.3 114.4 Unrecovered Winter Storm Fuel Costs (a) 33.5 60.1 Dolet Hills Power Station Accelerated Depreciation (c) 11.8 12.0 Other Regulatory Assets Pending Final Regulatory Approval 10.8 26.0 Total Regulatory Assets Currently Earning a Return 346.0 338.1 Regulatory Assets Currently Not Earning a Return NOLC - Costs (d) 49.6 — Storm-Related Costs - Louisiana, Texas 39.9 56.0 Other Regulatory Assets Pending Final Regulatory Approval 18.7 13.7 Total Regulatory Assets Currently Not Earning a Return 108.2 69.7 Total Regulatory Assets Pending Final Regulatory Approval 454.2 407.8 Regulatory assets approved for recovery: Regulatory Assets Currently Earning a Return Fuel Mine Closure Costs - Texas 70.6 74.3 11 years Pirkey Plant Accelerated Depreciation - Louisiana 66.4 65.8 8 years Unrecovered Winter Storm Fuel Costs (b) 62.8 99.3 3 years Plant Retirement Costs - Unrecovered Plant, Arkansas 40.2 44.4 18 years Dolet Hills Power Station Fuel Costs - Louisiana 21.7 — 3 years Plant Retirement Costs - Unrecovered Plant, Dolet Hills Power Station - Louisiana 19.0 40.8 8 years Storm-Related Costs - Louisiana (e) — 144.7 Other Regulatory Assets Approved for Recovery 12.6 13.8 various Total Regulatory Assets Currently Earning a Return 293.3 483.1 Regulatory Assets Currently Not Earning a Return Pension and OPEB Funded Status 93.2 109.2 12 years Plant Retirement Costs - Unrecovered Plant, Texas 44.5 48.7 22 years Plant Retirement Costs - Unrecovered Plant, Arkansas 12.8 17.3 3 years Unrealized Loss on Forward Commitments 1.2 15.4 3 years North Central Wind Rider — 20.2 Other Regulatory Assets Approved for Recovery 22.1 30.1 various Total Regulatory Assets Currently Not Earning a Return 173.8 240.9 Total Regulatory Assets Approved for Recovery 467.1 724.0 Total Noncurrent Regulatory Assets $ 921.3 $ 1,131.8 (a) See “February 2021 Severe Winter Weather Impacts in SPP” section of Note 4 for additional information. (b) 2024 amount related to Arkansas, Louisiana and Texas jurisdictions. 2023 amount related to Arkansas and Texas jurisdictions. (c) Amounts include the FERC jurisdiction. (d) In the second quarter of 2024, a request seeking to establish a recovery mechanism for the Texas jurisdictional share of these regulatory assets was filed in Texas. In the third quarter of 2024, PUCT Staff and certain intervenors in Texas requested a hearing and direct testimony was filed by SWEPCo in October 2024. A hearing is scheduled for the first quarter of 2025 in Texas. (e) In July 2024, the LPSC approved SWEPCo’s securitization of storm costs for Hurricanes Laura and Delta, as well as a storm reserve. See “2021 Louisiana Storm Cost Filing” section of Note 4 for additional information.
Regulatory Liabilities	AEP December 31, Remaining 2024 2023 Refund Period Current Regulatory Liabilities (in millions) Over-recovered Fuel Costs - pays a return $ 21.6 $ 3.3 1 year Over-recovered Fuel Costs - does not pay a return 31.9 23.2 1 year Total Current Regulatory Liabilities $ 53.5 $ 26.5 Noncurrent Regulatory Liabilities and Regulatory liabilities pending final regulatory determination: Regulatory Liabilities Currently Paying a Return Income Taxes, Net (a) $ 176.0 $ 103.1 Total Regulatory Liabilities Currently Paying a Return 176.0 103.1 Regulatory Liabilities Currently Not Paying a Return FERC 2021 Transmission Formula Rate Challenge Refunds 131.3 103.1 Other Regulatory Liabilities Pending Final Regulatory Determination 14.7 1.7 Total Regulatory Liabilities Currently Not Paying a Return 146.0 104.8 Total Regulatory Liabilities Pending Final Regulatory Determination 322.0 207.9 Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs 3,828.0 3,563.5 (b) Income Taxes, Net (a) 1,622.1 2,179.7 (c) Rockport Plant, Unit 2 Accelerated Depreciation for Leasehold Improvements 35.9 44.9 4 years Other Regulatory Liabilities Approved for Payment 40.4 35.0 various Total Regulatory Liabilities Currently Paying a Return 5,526.4 5,823.1 Regulatory Liabilities Currently Not Paying a Return Excess Nuclear Decommissioning Funding 2,137.3 1,721.9 (d) Deferred Investment Tax Credits 65.1 154.5 29 years Demand Side Management 52.6 31.3 2 years Spent Nuclear Fuel 50.4 47.6 (d) 2017-2019 Virginia Triennial Revenue Provision 35.2 37.1 25 years Peak Demand Reduction/Energy Efficiency 32.8 26.4 2 years Over-recovered Fuel Costs - Ohio 32.1 26.1 8 years Other Regulatory Liabilities Approved for Payment 90.1 106.5 various Total Regulatory Liabilities Currently Not Paying a Return 2,495.6 2,151.4 Total Regulatory Liabilities Approved for Payment 8,022.0 7,974.5 Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits $ 8,344.0 $ 8,182.4 (a) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (b) Relieved as removal costs are incurred. (c) Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $192 million and $228 million for the years ended December 31, 2024 and 2023, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2024 is to be refunded over 10 years. (d) Relieved when plant is decommissioned. AEP Texas December 31, Remaining Regulatory Liabilities: 2024 2023 (in millions) Noncurrent Regulatory Liabilities and Regulatory liabilities pending final regulatory determination: Regulatory Liabilities Currently Paying a Return Income Taxes, Net (a) $ — $ 13.0 Total Regulatory Liabilities Currently Paying a Return — 13.0 Regulatory Liabilities Currently Not Paying a Return Other Regulatory Liabilities Pending Final Regulatory Determination — 1.5 Total Regulatory Liabilities Currently Not Paying a Return — 1.5 Total Regulatory Liabilities Pending Final Regulatory Determination — 14.5 Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs 844.0 797.1 (b) Income Taxes, Net (a) 409.4 412.0 (c) Other Regulatory Liabilities Approved for Payment 4.8 3.8 various Total Regulatory Liabilities Currently Paying a Return 1,258.2 1,212.9 Regulatory Liabilities Currently Not Paying a Return Transition and Restoration Charges 21.6 26.6 5 years Other Regulatory Liabilities Approved for Payment 5.6 7.4 various Total Regulatory Liabilities Currently Not Paying a Return 27.2 34.0 Total Regulatory Liabilities Approved for Payment 1,285.4 1,246.9 Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits $ 1,285.4 $ 1,261.4 (a) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (b) Relieved as removal costs are incurred. (c) Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements was $22 million for the year ended December 31, 2024. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2024 is to be refunded over 5 years. AEPTCo December 31, Remaining Regulatory Liabilities: 2024 2023 (in millions) Noncurrent Regulatory Liabilities Regulatory liabilities pending final regulatory determination: Regulatory Liabilities Currently Paying a Return Income Taxes, Net (a) $ 8.8 $ 8.7 Total Regulatory Liabilities Pending Final Regulatory Determination 8.8 8.7 Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs 582.3 466.3 (b) Income Taxes, Net (a) 287.3 308.7 (c) Total Regulatory Liabilities Approved for Payment 869.6 775.0 Total Noncurrent Regulatory Liabilities $ 878.4 $ 783.7 (a) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (b) Relieved as removal costs are incurred. (c) Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $9 million and $13 million for the years ended December 31, 2024 and 2023, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2024 is to be refunded over 4 years. APCo December 31, Remaining Regulatory Liabilities: 2024 2023 (in millions) Current Regulatory Liabilities Over-recovered Fuel Costs, West Virginia - does not pay a return $ 21.6 $ — 1 year Total Current Regulatory Liabilities $ 21.6 $ — Noncurrent Regulatory Liabilities and Regulatory liabilities pending final regulatory determination: Regulatory Liabilities Currently Paying a Return Income Taxes, Net (a) $ (6.3) $ 7.9 Total Regulatory Liabilities Currently Paying a Return (6.3) 7.9 Regulatory Liabilities Currently Not Paying a Return FERC 2021 Transmission Formula Rate Challenge Refunds 24.9 19.7 Total Regulatory Liabilities Currently Not Paying a Return 24.9 19.7 Total Regulatory Liabilities Pending Final Regulatory Determination 18.6 27.6 Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs 805.6 759.6 (b) Income Taxes, Net (a) 219.3 240.1 (c) Deferred Investment Tax Credits — 0.3 Total Regulatory Liabilities Currently Paying a Return 1,024.9 1,000.0 Regulatory Liabilities Currently Not Paying a Return 2017-2019 Virginia Triennial Revenue Provision 35.2 37.1 25 years Virginia Transmission Rate Adjustment Clause 10.2 1.5 2 years Energy Efficiency Rate Adjustment Clause - Virginia 10.0 3.2 2 years Other Regulatory Liabilities Approved for Payment 16.9 12.5 various Total Regulatory Liabilities Currently Not Paying a Return 72.3 54.3 Total Regulatory Liabilities Approved for Payment 1,097.2 1,054.3 Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits $ 1,115.8 $ 1,081.9 (a) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (b) Relieved as removal costs are incurred. (c) Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $12 million and $35 million for the years ended December 31, 2024 and 2023, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2024 is to be refunded over 4 years. I&M December 31, Remaining Regulatory Liabilities: 2024 2023 (in millions) Current Regulatory Liabilities Over-recovered Fuel Costs, Indiana - does not pay a return $ 10.3 $ 23.2 1 year Total Current Regulatory Liabilities $ 10.3 $ 23.2 Noncurrent Regulatory Liabilities and Regulatory liabilities pending final regulatory determination: Regulatory Liabilities Currently Paying a Return Income Taxes, Net (a) (b) $ — $ (103.0) Total Regulatory Liabilities Currently Paying a Return — (103.0) Regulatory Liabilities Currently Not Paying a Return FERC 2021 Transmission Formula Rate Challenge Refunds 28.9 22.8 Cook Plant PTC Deferral - Michigan 14.5 — Total Regulatory Liabilities Currently Not Paying a Return 43.4 22.8 Total Regulatory Liabilities Pending Final Regulatory Determination 43.4 (80.2) Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs 174.2 168.1 (c) Renewable Energy Surcharge - Michigan 24.3 26.6 2 years Income Taxes, Net (a) — 116.8 (d) Other Regulatory Liabilities Approved for Payment 0.1 0.1 various Total Regulatory Liabilities Currently Paying a Return 198.6 311.6 Regulatory Liabilities Currently Not Paying a Return Excess Nuclear Decommissioning Funding 2,137.3 1,721.9 (e) Spent Nuclear Fuel 50.4 47.6 (e) Demand Side Management - Indiana 33.0 16.7 2 years Deferred Investment Tax Credits 13.8 15.8 26 years PJM Costs and Off-system Sales Margin Sharing - Indiana 2.0 14.1 1 year Other Regulatory Liabilities Approved for Payment 2.3 4.8 various Total Regulatory Liabilities Currently Not Paying a Return 2,238.8 1,820.9 Total Regulatory Liabilities Approved for Payment 2,437.4 2,132.5 Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits $ 2,480.8 $ 2,052.3 (a) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (b) Represents an income tax related regulatory asset, which is presented within net regulatory liabilities on the balance sheet. (c) Relieved as removal costs are incurred. (d) Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements was $25 million for the year ended December 31, 2023. (e) Relieved when plant is decommissioned. OPCo December 31, Remaining 2024 2023 Regulatory Liabilities: (in millions) Noncurrent Regulatory Liabilities Regulatory liabilities pending final regulatory determination: Regulatory Liabilities Currently Not Paying a Return FERC 2021 Transmission Formula Rate Challenge Refunds $ 72.7 $ 57.0 Other Regulatory Liabilities Pending Final Regulatory Determination 0.2 0.2 Total Regulatory Liabilities Pending Final Regulatory Determination 72.9 57.2 Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs 480.0 475.5 (a) Income Taxes, Net (b) 367.6 408.2 (c) Other Regulatory Liabilities Approved for Payment 4.0 — Total Regulatory Liabilities Currently Paying a Return 851.6 883.7 Regulatory Liabilities Currently Not Paying a Return Over-recovered Fuel Costs 32.1 26.1 8 years Peak Demand Reduction/Energy Efficiency 22.8 23.2 2 years Other Regulatory Liabilities Approved for Payment 8.3 13.4 various Total Regulatory Liabilities Currently Not Paying a Return 63.2 62.7 Total Regulatory Liabilities Approved for Payment 914.8 946.4 Total Noncurrent Regulatory Liabilities $ 987.7 $ 1,003.6 (a) Relieved as removal costs are incurred. (b) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (c) Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $100 million and $132 million for the years ended December 31, 2024 and 2023, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2024 is to be refunded over 4 years. PSO December 31, Remaining 2024 2023 Regulatory Liabilities: (in millions) Noncurrent Regulatory Liabilities and Regulatory liabilities pending final regulatory determination: Regulatory Liabilities Currently Not Paying a Return FERC 2021 Transmission Formula Rate Challenge Refunds $ 1.6 $ 1.2 Total Regulatory Liabilities Pending Final Regulatory Determination 1.6 1.2 Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs 323.6 317.5 (b) Income Taxes, Net (a) 318.0 395.7 (c) Total Regulatory Liabilities Currently Paying a Return 641.6 713.2 Regulatory Liabilities Currently Not Paying a Return Deferred Investment Tax Credits 46.2 47.2 12 years Other Regulatory Liabilities Approved for Payment 0.3 4.0 various Total Regulatory Liabilities Currently Not Paying a Return 46.5 51.2 Total Regulatory Liabilities Approved for Payment 688.1 764.4 Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits $ 689.7 $ 765.6 (a) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (b) Relieved as removal costs are incurred. (c) Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets. Excess ADIT that is Not Subject to Rate Normalization Requirements were $46 million and $51 million for the years ended December 31, 2024 and 2023, respectively. The remaining balance of Excess ADIT that is Not Subject to Rate Normalization Requirements as of December 31, 2024 is to be refunded over 10 year. SWEPCo December 31, Remaining 2024 2023 Regulatory Liabilities: (in millions) Current Regulatory Liabilities Over-recovered Fuel Costs - pays a return (a) $ 21.6 $ 3.3 1 year Total Current Regulatory Liabilities $ 21.6 $ 3.3 Noncurrent Regulatory Liabilities and Regulatory liabilities pending final regulatory determination: Regulatory Liabilities Currently Paying a Return Income Taxes, Net (b) $ 7.0 $ 7.0 Total Regulatory Liabilities Pending Final Regulatory Determination 7.0 7.0 Regulatory liabilities approved for payment: Regulatory Liabilities Currently Paying a Return Asset Removal Costs 456.6 443.2 (c) Income Taxes, Net (b) 127.5 292.4 (d) Other Regulatory Liabilities Approved for Payment 7.3 4.4 various Total Regulatory Liabilities Currently Paying a Return 591.4 740.0 Regulatory Liabilities Currently Not Paying a Return Other Regulatory Liabilities Approved for Payment 12.4 9.1 various Total Regulatory Liabilities Currently Not Paying a Return 12.4 9.1 Total Regulatory Liabilities Approved for Payment 603.8 749.1 Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits $ 610.8 $ 756.1 (a) 2024 amount related to Texas jurisdiction. 2023 amount related to Louisiana jurisdiction. (b) Predominately pays a return due to the inclusion of Excess ADIT in rate base. (c) Relieved as removal costs are incurred. (d) Refunded over the period for which the related deferred income tax reverse, which is generally based on the expected life for the underlying assets. Excess ADIT Associated with Certain Depreciable Property is refunded over the remaining depreciable life of the underlying assets.

COMMITMENTS, GUARANTEES AND C_2

COMMITMENTS, GUARANTEES AND CONTINGENCIES (Tables)	12 Months Ended
	Dec. 31, 2024
Commitments and Contingencies Disclosure [Abstract]
Schedule of Contractual Commitments	In accordance with the accounting guidance for “Commitments”, the following tables summarize the Registrants’ actual contractual commitments as of December 31, 2024: Contractual Commitments - AEP Less Than 2-3 Years 4-5 Years After Total (in millions) Fuel Purchase Contracts (a) $ 1,002.0 $ 942.0 $ 475.7 $ 368.3 $ 2,788.0 Energy and Capacity Purchase Contracts 192.8 384.0 334.3 464.0 1,375.1 Total $ 1,194.8 $ 1,326.0 $ 810.0 $ 832.3 $ 4,163.1 Contractual Commitments - APCo Less Than 2-3 Years 4-5 Years After Total (in millions) Fuel Purchase Contracts (a) $ 506.7 $ 328.6 $ 167.0 $ 96.0 $ 1,098.3 Energy and Capacity Purchase Contracts 40.4 79.9 48.0 52.2 220.5 Total $ 547.1 $ 408.5 $ 215.0 $ 148.2 $ 1,318.8 Contractual Commitments - I&M Less Than 2-3 Years 4-5 Years After Total (in millions) Fuel Purchase Contracts (a) $ 151.5 $ 346.6 $ 220.7 $ 263.9 $ 982.7 Energy and Capacity Purchase Contracts 119.9 236.2 231.7 321.5 909.3 Total $ 271.4 $ 582.8 $ 452.4 $ 585.4 $ 1,892.0 Contractual Commitments - OPCo Less Than 2-3 Years 4-5 Years After Total (in millions) Energy and Capacity Purchase Contracts $ 33.2 $ 64.2 $ 66.3 $ 69.5 $ 233.2 Contractual Commitments - PSO Less Than 2-3 Years 4-5 Years After Total (in millions) Fuel Purchase Contracts (a) $ 27.4 $ 17.0 $ — $ — $ 44.4 Energy and Capacity Purchase Contracts 62.9 123.6 62.4 19.7 268.6 Total $ 90.3 $ 140.6 $ 62.4 $ 19.7 $ 313.0 Contractual Commitments - SWEPCo Less Than 2-3 Years 4-5 Years After Total (in millions) Fuel Purchase Contracts (a) $ 89.4 $ 46.6 $ — $ — $ 136.0 Energy and Capacity Purchase Contracts 11.5 13.2 — — 24.7 Total $ 100.9 $ 59.8 $ — $ — $ 160.7 (a) Represents contractual commitments to purchase coal, natural gas, uranium and other consumables as fuel for electric generation along with related transportation of the fuel.
Maximum Future Payments for Letters of Credit Issued Under the Uncommitted Facilities	The Registrants’ maximum future payments for letters of credit issued under the uncommitted facilities as of December 31, 2024 were as follows: Company Amount Maturity (in millions) AEP $ 238.0 January 2025 to November 2025 AEP Texas 1.8 July 2025
Schedule of Asset Retirement Obligations	AEP evaluated the applicability of the rule to current and former plant sites and recorded incremental ARO in the second quarter of 2024, as shown in the table below, based on initial cost estimates primarily reflecting compliance with the rule through closure in place and future groundwater monitoring requirements pursuant to the revised CCR Rule. Registrant Increase in ARO Increase in Generation Property (a) Increase in Regulatory Assets (b) Charged to Operating Expenses (c) (in millions) APCo $ 312.2 $ 75.6 $ 236.6 $ — I&M 85.7 — 72.3 13.4 OPCo 52.9 — — 52.9 PSO 33.7 33.7 — — SWEPCo 23.8 23.8 — — Non-Registrants 166.1 43.8 46.1 76.2 Total $ 674.4 $ 176.9 $ 355.0 $ 142.5 (a) ARO is related to a legacy CCR surface impoundment or CCR management unit at an operating generation facility. (b) ARO is related to a legacy CCR surface impoundment or CCR management unit at a retired generation facility and recognition of a regulatory asset in accordance with the accounting guidance for “Regulated Operations” is supported. (c) ARO is related to a legacy CCR surface impoundment or CCR management unit and recognition of a regulatory asset in accordance with the accounting guidance for “Regulated Operations” is not yet supported.

BENEFIT PLANS (Tables)

BENEFIT PLANS (Tables)	12 Months Ended
	Dec. 31, 2024
Retirement Benefits [Abstract]
Actuarial Assumptions	The weighted-average assumptions used in the measurement of the Registrants’ benefit obligations are shown in the following tables: Pension Plans OPEB December 31, Assumption 2024 2023 2024 2023 Discount Rate 5.65 % 5.15 % 5.60 % 5.15 % Interest Crediting Rate 4.55 % 4.00 % NA NA NA Not applicable. Assumption – Rate of Compensation Increase (a) - Pension Plans AEP AEP Texas APCo I&M OPCo PSO SWEPCo December 31, 2024 5.55 % 5.70 % 5.55 % 5.50 % 6.00 % 5.70 % 5.55 % December 31, 2023 5.05 % 5.20 % 4.95 % 5.05 % 5.45 % 5.20 % 5.00 % (a) Rates are for base pay only. In addition, an amount is added to reflect target incentive compensation for exempt employees and overtime and incentive pay for nonexempt employees. The weighted-average assumptions used in the measurement of each Registrants’ benefit costs are shown in the following tables: Pension Plans OPEB Year Ended December 31, Assumption 2024 2023 2022 2024 2023 2022 Discount Rate 5.20 % 5.50 % 2.90 % 5.15 % 5.50 % 2.90 % Interest Crediting Rate 4.05 % 4.25 % 4.00 % NA NA NA Expected Return on Plan Assets 7.30 % 7.50 % 5.25 % 6.75 % 7.25 % 5.50 % NA Not applicable. Assumption – Rate of Compensation Increase (a) - Pension Plans AEP AEP Texas APCo I&M OPCo PSO SWEPCo December 31, 2024 5.10 % 5.25 % 5.10 % 5.10 % 5.50 % 5.20 % 5.10 % December 31, 2023 5.05 % 5.20 % 4.95 % 5.05 % 5.45 % 5.20 % 5.00 % December 31, 2022 5.05 % 5.15 % 4.90 % 5.00 % 5.35 % 5.15 % 5.00 % (a) Rates are for base pay only. In addition, an amount is added to reflect target incentive compensation for exempt employees and overtime and incentive pay for nonexempt employees .
Health Care Trend Rates	The health care trend rate assumptions used for OPEB plans measurement purposes are shown below: Health Care Trend Rates December 31, 2024 December 31, 2023 Initial 6.50 % 7.00 % Ultimate 4.50 % 4.50 % Year Ultimate Reached 2029 2030
Reconciliation of Changes in Benefit Obligations and Fair Value of Assets	2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Change in Benefit Obligation (in millions) Benefit Obligation as of January 1, $ 4,161.6 $ 343.1 $ 504.1 $ 477.0 $ 378.4 $ 202.2 $ 261.2 Service Cost 100.6 8.9 9.5 13.0 9.2 5.9 7.8 Interest Cost 207.4 17.3 24.7 23.9 18.8 10.1 12.5 Actuarial (Gain) Loss (44.6) 5.5 (12.9) (8.4) (8.3) 0.1 (11.2) Settlements (329.4) (34.8) (42.0) (33.1) (23.2) (18.5) (33.1) Benefit Payments (223.8) (17.3) (30.4) (22.6) (24.2) (9.6) (9.4) Benefit Obligation as of December 31, $ 3,871.8 $ 322.7 $ 453.0 $ 449.8 $ 350.7 $ 190.2 $ 227.8 Change in Fair Value of Plan Assets Fair Value of Plan Assets as of January 1, $ 4,118.2 $ 332.7 $ 549.8 $ 550.6 $ 419.5 $ 222.7 $ 227.5 Actual Gain on Plan Assets 87.2 7.1 10.4 11.6 8.6 5.0 3.6 Company Contributions (a) 14.0 0.4 — — — 0.1 0.2 Settlements (329.4) (34.8) (42.0) (33.1) (23.2) (18.5) (33.1) Benefit Payments (223.8) (17.3) (30.4) (22.6) (24.2) (9.6) (9.4) Fair Value of Plan Assets as of December 31, $ 3,666.2 $ 288.1 $ 487.8 $ 506.5 $ 380.7 $ 199.7 $ 188.8 Funded (Underfunded) Status as of December 31, $ (205.6) $ (34.6) $ 34.8 $ 56.7 $ 30.0 $ 9.5 $ (39.0) 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Change in Benefit Obligation (in millions) Benefit Obligation as of January 1, $ 4,072.7 $ 334.1 $ 485.7 $ 466.8 $ 363.6 $ 192.3 $ 250.7 Service Cost 94.3 8.2 9.1 11.9 8.4 5.5 7.7 Interest Cost 219.2 18.3 26.4 24.9 19.8 10.7 13.9 Actuarial Loss 144.0 20.1 23.2 8.5 17.5 13.6 16.8 Benefit Payments (368.6) (37.6) (40.3) (35.1) (30.9) (19.9) (27.9) Benefit Obligation as of December 31, $ 4,161.6 $ 343.1 $ 504.1 $ 477.0 $ 378.4 $ 202.2 $ 261.2 Change in Fair Value of Plan Assets Fair Value of Plan Assets as of January 1, $ 4,124.7 $ 335.1 $ 531.7 $ 533.7 $ 406.4 $ 218.5 $ 231.3 Actual Gain on Plan Assets 353.8 34.8 58.4 51.5 44.0 24.0 23.9 Company Contributions (a) 8.3 0.4 — 0.5 — 0.1 0.2 Benefit Payments (368.6) (37.6) (40.3) (35.1) (30.9) (19.9) (27.9) Fair Value of Plan Assets as of December 31, $ 4,118.2 $ 332.7 $ 549.8 $ 550.6 $ 419.5 $ 222.7 $ 227.5 Funded (Underfunded) Status as of December 31, $ (43.4) $ (10.4) $ 45.7 $ 73.6 $ 41.1 $ 20.5 $ (33.7) (a) No contributions were made to the qualified pension plan for the years ended December 31, 2024 and 2023, respectively. Contributions to the non-qualified pension plans were $14 million and $8 million for the years ended December 31, 2024 and 2023, respectively. OPEB 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Change in Benefit Obligation (in millions) Benefit Obligation as of January 1, $ 849.5 $ 66.4 $ 134.6 $ 98.8 $ 85.9 $ 43.7 $ 53.7 Service Cost 4.5 0.3 0.5 0.6 0.4 0.3 0.4 Interest Cost 42.0 3.3 6.6 4.8 4.2 2.1 2.7 Actuarial (Gain) Loss (192.3) (15.4) (30.4) (24.7) (20.7) (10.4) (11.5) Special/Contractual Termination Benefits 3.5 0.4 0.6 0.4 0.3 0.1 0.3 Benefit Payments (105.8) (8.3) (16.7) (13.4) (11.3) (5.8) (7.4) Participant Contributions 44.9 3.5 6.8 6.0 4.6 2.6 3.3 Medicare Subsidy 0.3 — 0.1 — — — — Benefit Obligation as of December 31, $ 646.6 $ 50.2 $ 102.1 $ 72.5 $ 63.4 $ 32.6 $ 41.5 Change in Fair Value of Plan Assets Fair Value of Plan Assets as of January 1, $ 1,673.3 $ 137.5 $ 243.0 $ 204.6 $ 177.8 $ 90.2 $ 111.1 Actual Gain on Plan Assets 159.2 14.0 22.5 14.7 14.1 8.3 14.2 Company Contributions 4.3 — 0.8 — — — — Participant Contributions 44.9 3.5 6.8 6.0 4.6 2.6 3.3 Benefit Payments (105.8) (8.3) (16.7) (13.4) (11.3) (5.8) (7.4) Fair Value of Plan Assets as of December 31, $ 1,775.9 $ 146.7 $ 256.4 $ 211.9 $ 185.2 $ 95.3 $ 121.2 Funded Status as of December 31, $ 1,129.3 $ 96.5 $ 154.3 $ 139.4 $ 121.8 $ 62.7 $ 79.7 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Change in Benefit Obligation (in millions) Benefit Obligation as of January 1, $ 872.6 $ 68.6 $ 140.7 $ 101.9 $ 88.9 $ 45.7 $ 55.1 Service Cost 4.6 0.3 0.5 0.6 0.4 0.3 0.4 Interest Cost 46.2 3.6 7.4 5.4 4.7 2.4 2.9 Actuarial Loss 19.8 1.2 0.9 3.2 2.2 0.4 1.2 Benefit Payments (137.8) (10.7) (21.6) (18.3) (15.0) (7.6) (8.8) Participant Contributions 43.6 3.4 6.6 6.0 4.7 2.5 2.9 Medicare Subsidy 0.5 — 0.1 — — — — Benefit Obligation as of December 31, $ 849.5 $ 66.4 $ 134.6 $ 98.8 $ 85.9 $ 43.7 $ 53.7 Change in Fair Value of Plan Assets Fair Value of Plan Assets as of January 1, $ 1,549.3 $ 128.3 $ 228.6 $ 190.5 $ 166.2 $ 85.4 $ 103.0 Actual Gain on Plan Assets 213.2 16.5 28.1 26.4 21.9 9.9 14.0 Company Contributions 5.0 — 1.3 — — — — Participant Contributions 43.6 3.4 6.6 6.0 4.7 2.5 2.9 Benefit Payments (137.8) (10.7) (21.6) (18.3) (15.0) (7.6) (8.8) Fair Value of Plan Assets as of December 31, $ 1,673.3 $ 137.5 $ 243.0 $ 204.6 $ 177.8 $ 90.2 $ 111.1 Funded Status as of December 31, $ 823.8 $ 71.1 $ 108.4 $ 105.8 $ 91.9 $ 46.5 $ 57.4
Benefit Amounts Recognized on the Balance Sheets	Amounts Included on the Balance Sheets Related to Funded Status Pension Plans December 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Other Noncurrent Assets - Employee Benefits and Pension Assets $ — $ — $ 35.2 $ 58.2 $ 30.3 $ 10.9 $ — Other Current Liabilities – Accrued Short-term Benefit Liability (5.2) (0.3) — — — (0.1) (0.1) Other Noncurrent Liabilities – Accrued Long-term Benefit Liability (200.4) (34.3) (0.4) (1.5) (0.3) (1.3) (38.9) Funded (Underfunded) Status $ (205.6) $ (34.6) $ 34.8 $ 56.7 $ 30.0 $ 9.5 $ (39.0) December 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Other Noncurrent Assets - Employee Benefits and Pension Assets $ 17.3 $ 0.1 $ 46.0 $ 74.8 $ 41.4 $ 21.8 $ — Other Current Liabilities – Accrued Short-term Benefit Liability (6.7) (0.3) — — — (0.1) (0.1) Other Noncurrent Liabilities – Accrued Long-term Benefit Liability (54.0) (10.2) (0.3) (1.2) (0.3) (1.2) (33.6) Funded (Underfunded) Status $ (43.4) $ (10.4) $ 45.7 $ 73.6 $ 41.1 $ 20.5 $ (33.7) OPEB December 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Other Noncurrent Assets - Employee Benefits and Pension Assets $ 1,130.8 $ 96.5 $ 168.7 $ 139.4 $ 121.8 $ 62.7 $ 79.7 Other Current Liabilities – Accrued Short-term Benefit Liability (2.2) — (1.4) — — — — Other Noncurrent Liabilities – Accrued Long-term Benefit Liability 0.7 — (13.0) — — — — Funded Status $ 1,129.3 $ 96.5 $ 154.3 $ 139.4 $ 121.8 $ 62.7 $ 79.7 December 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Other Noncurrent Assets - Employee Benefits and Pension Assets $ 838.0 $ 71.1 $ 125.6 $ 105.8 $ 91.9 $ 46.5 $ 57.4 Other Current Liabilities – Accrued Short-term Benefit Liability (2.4) — (1.6) — — — — Other Noncurrent Liabilities – Accrued Long-term Benefit Liability (11.8) — (15.6) — — — — Funded Status $ 823.8 $ 71.1 $ 108.4 $ 105.8 $ 91.9 $ 46.5 $ 57.4
Amounts Included in AOCI and Regulatory Assets	The following tables show the components of the plans included in Regulatory Assets, Deferred Income Taxes and AOCI and the items attributable to the change in these components: Pension Plans December 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Components (in millions) Net Actuarial Loss $ 1,153.5 $ 189.3 $ 112.1 $ 7.5 $ 140.9 $ 53.8 $ 82.9 Prior Service Cost 0.2 — — — — — — Recorded as Regulatory Assets $ 1,019.8 $ 176.7 $ 109.9 $ 17.5 $ 140.9 $ 53.8 $ 83.0 Deferred Income Taxes 28.2 2.8 0.4 (2.2) — — — Net of Tax AOCI 105.7 9.8 1.8 (7.8) — — (0.1) December 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Components (in millions) Net Actuarial (Gain) Loss $ 1,063.4 $ 175.2 $ 104.9 $ (5.8) $ 131.9 $ 46.7 $ 89.6 Prior Service Cost 0.2 — — — — — — Recorded as Regulatory Assets $ 938.6 $ 163.4 $ 102.6 $ 6.4 $ 131.9 $ 46.7 $ 89.7 Deferred Income Taxes 26.4 2.7 0.4 (2.6) — — — Net of Tax AOCI 98.6 9.1 1.9 (9.6) — — (0.1) December 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Components (in millions) Net Actuarial (Gain) Loss $ (41.6) $ 1.6 $ (9.9) $ 2.3 $ (5.3) $ 4.7 $ — Prior Service Credit (14.7) (1.3) (2.3) (2.0) (1.6) (0.9) (1.0) Recorded as Regulatory Assets $ (55.4) $ 0.8 $ (2.0) $ (2.9) $ (6.9) $ 3.8 $ 0.5 Deferred Income Taxes (0.1) — (2.2) 0.7 — — (0.3) Net of Tax AOCI (0.8) (0.5) (8.0) 2.5 — — (1.2) December 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Components (in millions) Net Actuarial Loss $ 201.5 $ 22.1 $ 27.1 $ 28.7 $ 18.1 $ 17.5 $ 18.4 Prior Service Credit (27.4) (2.3) (4.2) (3.7) (2.9) (1.6) (2.1) Recorded as Regulatory Assets $ 106.1 $ 19.8 $ 13.2 $ 19.0 $ 15.2 $ 15.9 $ 10.2 Deferred Income Taxes 14.3 — 2.0 1.3 — — 1.3 Net of Tax AOCI 53.7 — 7.7 4.7 — — 4.8
Components of Change in Amounts Included in AOCI and Regulatory Assets	December 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Components (in millions) Actuarial Loss During the Year $ 188.0 $ 24.2 $ 19.4 $ 23.0 $ 15.8 $ 12.5 $ 2.7 Amortization of Actuarial Loss (4.5) (0.3) (0.4) (0.4) (0.3) (0.2) (0.1) Amounts Recognized Due to Settlement (93.4) (9.8) (11.8) (9.3) (6.5) (5.2) (9.3) Change for the Year Ended December 31, $ 90.1 $ 14.1 $ 7.2 $ 13.3 $ 9.0 $ 7.1 $ (6.7) December 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Components (in millions) Actuarial Loss During the Year $ 129.2 $ 13.4 $ 9.3 $ 1.2 $ 7.6 $ 7.9 $ 12.1 Amortization of Actuarial Loss (1.4) (0.1) — (0.1) — — (0.1) Change for the Year Ended December 31, $ 127.8 $ 13.3 $ 9.3 $ 1.1 $ 7.6 $ 7.9 $ 12.0 December 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Components (in millions) Actuarial Gain During the Year $ (240.1) $ (20.3) $ (36.6) $ (25.9) $ (23.0) $ (12.6) $ (18.1) Amortization of Actuarial Loss (3.0) (0.2) (0.4) (0.5) (0.4) (0.2) (0.3) Amortization of Prior Service Credit 12.7 1.0 1.9 1.7 1.3 0.7 1.1 Change for the Year Ended December 31, $ (230.4) $ (19.5) $ (35.1) $ (24.7) $ (22.1) $ (12.1) $ (17.3) December 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Components (in millions) Actuarial Gain During the Year $ (83.7) $ (6.4) $ (11.1) $ (9.6) $ (7.9) $ (3.7) $ (5.6) Amortization of Actuarial Loss (14.8) (1.2) (2.3) (1.9) (1.6) (0.8) (1.0) Amortization of Prior Service Credit 63.1 5.3 9.2 8.7 6.3 4.0 4.9 Change for the Year Ended December 31, $ (35.4) $ (2.3) $ (4.2) $ (2.8) $ (3.2) $ (0.5) $ (1.7)
Allocated Assets of Investments	All Level 1, 2, 3 and Other amounts can be allocated to the Registrant Subsidiaries using the percentages in the table below: Pension Plan OPEB December 31, Company 2024 2023 2024 2023 AEP Texas 7.9 % 8.1 % 8.3 % 8.2 % APCo 13.3 % 13.4 % 14.4 % 14.5 % I&M 13.8 % 13.4 % 11.9 % 12.2 % OPCo 10.4 % 10.2 % 10.4 % 10.6 % PSO 5.5 % 5.4 % 5.4 % 5.4 % SWEPCo 5.2 % 5.5 % 6.8 % 6.6 %
Assets within Fair Value Hierarchy	The following table presents the classification of pension plan assets for AEP within the fair value hierarchy as of December 31, 2024: Asset Class Level 1 Level 2 Level 3 Other Total Year End (in millions) Equities (a): Domestic $ 327.0 $ — $ — $ — $ 327.0 8.9 % International 290.2 — — — 290.2 7.9 % Common Collective Trusts (b) 176.1 — — 472.6 648.7 17.7 % Subtotal – Equities 793.3 — — 472.6 1,265.9 34.5 % Fixed Income (a): United States Government and Agency Securities (2.3) 865.6 — — 863.3 23.6 % Corporate Debt — 719.2 — — 719.2 19.6 % Foreign Debt — 136.1 — — 136.1 3.7 % State and Local Government — 25.8 — — 25.8 0.7 % Other – Asset Backed — 0.9 — — 0.9 — % Subtotal – Fixed Income (2.3) 1,747.6 — — 1,745.3 47.6 % Infrastructure (b) — — — 112.9 112.9 3.1 % Real Estate (b) — — — 227.9 227.9 6.2 % Alternative Investments (b) — — — 223.8 223.8 6.1 % Cash and Cash Equivalents (b) — 41.3 — 27.2 68.5 1.9 % Other – Pending Transactions and Accrued Income (c) — — — 21.9 21.9 0.6 % Total $ 791.0 $ 1,788.9 $ — $ 1,086.3 $ 3,666.2 100.0 % (a) Includes investment securities loaned to borrowers under the securities lending program. See the “Investments Held in Trust for Future Liabilities” section of Note 1 for additional information. (b) Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share. (c) Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement. The following table presents the classification of OPEB plan assets for AEP within the fair value hierarchy as of December 31, 2024: Asset Class Level 1 Level 2 Level 3 Other Total Year End (in millions) Equities: Domestic $ 616.8 $ — $ — $ — $ 616.8 34.7 % International 267.2 — — — 267.2 15.0 % Common Collective Trusts (a) 64.2 — — 129.4 193.6 10.9 % Subtotal – Equities 948.2 — — 129.4 1,077.6 60.6 % Fixed Income: Common Collective Trust – Debt (a) — — — 132.9 132.9 7.5 % United States Government and Agency Securities (0.5) 157.6 — — 157.1 8.9 % Corporate Debt — 132.3 — — 132.3 7.5 % Foreign Debt — 27.1 — — 27.1 1.5 % State and Local Government 57.8 5.0 — — 62.8 3.5 % Other – Asset Backed — 0.2 — — 0.2 — % Subtotal – Fixed Income 57.3 322.2 — 132.9 512.4 28.9 % Trust Owned Life Insurance: International Equities — 23.1 — — 23.1 1.3 % United States Bonds — 118.2 — — 118.2 6.7 % Subtotal – Trust Owned Life Insurance — 141.3 — — 141.3 8.0 % Cash and Cash Equivalents (a) 27.6 — — 3.1 30.7 1.7 % Other – Pending Transactions and Accrued Income (b) — — — 13.9 13.9 0.8 % Total $ 1,033.1 $ 463.5 $ — $ 279.3 $ 1,775.9 100.0 % (a) Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share. (b) Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement. The following table presents the classification of pension plan assets for AEP within the fair value hierarchy as of December 31, 2023: Asset Class Level 1 Level 2 Level 3 Other Total Year End (in millions) Equities (a): Domestic $ 411.3 $ — $ — $ — $ 411.3 10.0 % International 389.8 — — — 389.8 9.5 % Common Collective Trusts (b) — — — 420.9 420.9 10.2 % Subtotal – Equities 801.1 — — 420.9 1,222.0 29.7 % Fixed Income (a): United States Government and Agency Securities 8.3 1,099.2 — — 1,107.5 26.9 % Corporate Debt — 894.8 — — 894.8 21.7 % Foreign Debt — 167.1 — — 167.1 4.1 % State and Local Government — 38.7 — — 38.7 0.9 % Other – Asset Backed — 1.3 — — 1.3 — % Subtotal – Fixed Income 8.3 2,201.1 — — 2,209.4 53.6 % Infrastructure (b) — — — 101.4 101.4 2.5 % Real Estate (b) — — — 239.3 239.3 5.8 % Alternative Investments (b) — — — 241.8 241.8 5.8 % Cash and Cash Equivalents (b) — 51.0 — 33.8 84.8 2.1 % Other – Pending Transactions and Accrued Income (c) — — 0.1 19.4 19.5 0.5 % Total $ 809.4 $ 2,252.1 $ 0.1 $ 1,056.6 $ 4,118.2 100.0 % (a) Includes investment securities loaned to borrowers under the securities lending program. See the “Investments Held in Trust for Future Liabilities” section of Note 1 for additional information. (b) Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share. (c) Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement. The following table presents the classification of OPEB plan assets for AEP within the fair value hierarchy as of December 31, 2023: Asset Class Level 1 Level 2 Level 3 Other Total Year End (in millions) Equities: Domestic $ 540.6 $ — $ — $ — $ 540.6 32.3 % International 288.4 — — — 288.4 17.2 % Common Collective Trusts (a) — — — 131.6 131.6 7.9 % Subtotal – Equities 829.0 — — 131.6 960.6 57.4 % Fixed Income: Common Collective Trust – Debt (a) — — — 146.7 146.7 8.8 % United States Government and Agency Securities 1.4 163.3 — — 164.7 9.8 % Corporate Debt — 149.0 — — 149.0 8.9 % Foreign Debt — 28.6 — — 28.6 1.7 % State and Local Government 41.5 7.8 — — 49.3 3.0 % Other – Asset Backed — 0.2 — — 0.2 — % Subtotal – Fixed Income 42.9 348.9 — 146.7 538.5 32.2 % Trust Owned Life Insurance: International Equities — 22.3 — — 22.3 1.3 % United States Bonds — 130.0 — — 130.0 7.8 % Subtotal – Trust Owned Life Insurance — 152.3 — — 152.3 9.1 % Cash and Cash Equivalents (a) 25.9 — — 2.9 28.8 1.7 % Other – Pending Transactions and Accrued Income (b) — — — (6.9) (6.9) (0.4) % Total $ 897.8 $ 501.2 $ — $ 274.3 $ 1,673.3 100.0 % (a) Amounts in “Other” column represent investments for which fair value is measured using net asset value per-share. (b) Amounts in “Other” column primarily represent accrued interest, dividend receivables and transactions pending settlement.
Accumulated Benefit Obligation	The accumulated benefit obligation for the pension plans is as follows: Accumulated Benefit Obligation AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Qualified Pension Plan $ 3,602.4 $ 300.6 $ 434.3 $ 422.3 $ 326.4 $ 174.6 $ 209.5 Nonqualified Pension Plans 46.9 2.1 0.2 0.9 0.1 1.1 1.0 Total as of December 31, 2024 $ 3,649.3 $ 302.7 $ 434.5 $ 423.2 $ 326.5 $ 175.7 $ 210.5 Accumulated Benefit Obligation AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Qualified Pension Plan $ 3,878.7 $ 321.1 $ 485.6 $ 450.3 $ 354.0 $ 186.6 $ 241.9 Nonqualified Pension Plans 54.8 2.1 0.1 0.7 0.1 1.2 1.0 Total as of December 31, 2023 $ 3,933.5 $ 323.2 $ 485.7 $ 451.0 $ 354.1 $ 187.8 $ 242.9
Underfunded Projected Benefit Obligation	The tables below show the underfunded pension plans that had obligations in excess of plan assets. Projected Benefit Obligation AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Projected Benefit Obligation $ 3,871.8 $ 322.7 $ 0.5 $ 1.5 $ 0.4 $ 1.4 $ 227.8 Fair Value of Plan Assets 3,666.2 288.1 — — — — 188.8 Underfunded Projected Benefit Obligation as of December 31, 2024 $ (205.6) $ (34.6) $ (0.5) $ (1.5) $ (0.4) $ (1.4) $ (39.0) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Projected Benefit Obligation $ 60.7 $ 343.1 $ 0.4 $ 1.2 $ 0.3 $ 1.4 $ 261.2 Fair Value of Plan Assets — 332.7 — — — — 227.5 Underfunded Projected Benefit Obligation as of December 31, 2023 $ (60.7) $ (10.4) $ (0.4) $ (1.2) $ (0.3) $ (1.4) $ (33.7)
Underfunded Accumulated Benefit Obligation	AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Accumulated Benefit Obligation $ 46.9 $ 302.7 $ 0.2 $ 0.9 $ 0.1 $ 1.1 $ 210.5 Fair Value of Plan Assets — 288.0 — — — — 188.9 Underfunded Accumulated Benefit Obligation as of December 31, 2024 $ (46.9) $ (14.7) $ (0.2) $ (0.9) $ (0.1) $ (1.1) $ (21.6) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Accumulated Benefit Obligation $ 54.8 $ 2.1 $ 0.1 $ 0.7 $ 0.1 $ 1.2 $ 242.9 Fair Value of Plan Assets — — — — — — 227.5 Underfunded Accumulated Benefit Obligation as of December 31, 2023 $ (54.8) $ (2.1) $ (0.1) $ (0.7) $ (0.1) $ (1.2) $ (15.4)
Estimated Contributions and Payments to the Pension and OPEB Plans	The following table provides the estimated contributions and payments by Registrant for 2025: AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Pension Plans $ 101.2 $ 11.8 $ 0.5 $ 2.6 $ — $ 2.0 $ 8.8 OPEB 2.7 — 1.4 — — — —
Estimated Payments Expected to be Made by the Pension and OPEB Plans	The estimated payments for the pension benefits and OPEB are as follows: Pension Plans AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) 2025 $ 341.5 $ 32.2 $ 42.3 $ 40.1 $ 31.6 $ 17.3 $ 20.7 2026 340.4 31.0 42.1 40.1 31.0 17.1 19.2 2027 334.8 28.8 40.0 39.0 30.8 17.1 20.4 2028 335.7 29.5 40.2 38.8 30.0 16.9 19.4 2029 322.7 27.8 38.6 37.1 29.5 15.1 19.0 Years 2030 to 2034, in Total 1,530.3 120.9 181.6 179.0 137.8 73.3 88.4 OPEB Benefit Payments AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) 2025 $ 117.6 $ 9.5 $ 18.8 $ 14.5 $ 12.0 $ 6.6 $ 8.6 2026 116.4 9.7 18.4 14.5 11.7 6.6 8.3 2027 114.6 9.7 18.1 14.2 11.5 6.3 8.0 2028 112.4 9.3 17.9 13.9 11.4 6.0 8.0 2029 109.7 8.9 17.4 13.6 11.0 5.9 7.8 Years 2030 to 2034, in Total 504.7 39.7 78.1 61.0 50.6 27.2 35.7 OPEB Medicare AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) 2025 $ 0.2 $ — $ 0.1 $ — $ — $ — $ — 2026 0.3 — 0.1 — — — — 2027 0.3 — 0.1 — — — — 2028 0.3 — 0.1 — — — — 2029 0.3 — 0.1 — — — — Years 2030 to 2034, in Total 1.4 — 0.4 — — — —
Components of Net Periodic Benefit Cost	The following tables provide the components of net periodic benefit cost (credit) by Registrant for the plans: Pension Plans 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 100.6 $ 8.9 $ 9.5 $ 13.0 $ 9.2 $ 5.9 $ 7.8 Interest Cost 207.4 17.3 24.7 23.9 18.8 10.1 12.5 Expected Return on Plan Assets (319.8) (25.7) (42.6) (42.9) (32.6) (17.3) (17.4) Amortization of Net Actuarial Loss 4.5 0.3 0.4 0.4 0.3 0.2 0.1 Settlements (a) 93.4 9.8 11.8 9.3 6.5 5.2 9.3 Net Periodic Benefit Cost 86.1 10.6 3.8 3.7 2.2 4.1 12.3 Capitalized Portion (46.6) (5.3) (4.4) (3.9) (5.5) (2.8) (3.1) Net Periodic Benefit Cost (Credit) Recognized in Expense $ 39.5 $ 5.3 $ (0.6) $ (0.2) $ (3.3) $ 1.3 $ 9.2 (a) AEP will seek recovery for the portion of pension settlement costs related to regulated operations. These costs were deferred as a regulatory asset for AEP, AEP Texas, APCo and PSO in the fourth quarter of 2024. 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 94.3 $ 8.2 $ 9.1 $ 11.9 $ 8.4 $ 5.5 $ 7.7 Interest Cost 219.2 18.3 26.4 24.9 19.8 10.7 13.9 Expected Return on Plan Assets (339.2) (28.1) (44.6) (44.2) (34.0) (18.3) (19.4) Amortization of Net Actuarial Loss 1.4 0.1 — 0.1 — — 0.1 Net Periodic Benefit Cost (Credit) (24.3) (1.5) (9.1) (7.3) (5.8) (2.1) 2.3 Capitalized Portion (43.6) (4.7) (4.2) (3.6) (4.7) (2.5) (3.0) Net Periodic Benefit Credit Recognized in Expense $ (67.9) $ (6.2) $ (13.3) $ (10.9) $ (10.5) $ (4.6) $ (0.7) 2022 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 123.1 $ 11.1 $ 11.4 $ 16.2 $ 11.2 $ 7.4 $ 10.6 Interest Cost 148.2 12.1 17.5 17.0 13.3 7.0 9.1 Expected Return on Plan Assets (253.4) (21.0) (32.3) (32.4) (24.8) (13.4) (14.6) Amortization of Net Actuarial Loss 63.0 5.2 7.4 7.1 5.5 2.9 3.8 Net Periodic Benefit Cost 80.9 7.4 4.0 7.9 5.2 3.9 8.9 Capitalized Portion (53.8) (6.2) (5.0) (4.6) (6.1) (3.2) (4.0) Net Periodic Benefit Cost (Credit) Recognized in Expense $ 27.1 $ 1.2 $ (1.0) $ 3.3 $ (0.9) $ 0.7 $ 4.9 OPEB 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 4.5 $ 0.3 $ 0.5 $ 0.6 $ 0.4 $ 0.3 $ 0.4 Interest Cost 42.0 3.3 6.6 4.8 4.2 2.1 2.7 Expected Return on Plan Assets (111.3) (9.1) (16.3) (13.5) (11.8) (6.0) (7.5) Amortization of Prior Service Credit (12.7) (1.0) (1.9) (1.7) (1.3) (0.7) (1.1) Amortization of Net Actuarial Loss 3.0 0.2 0.4 0.5 0.4 0.2 0.3 Special/Contractual Termination Benefits 3.5 0.3 0.6 0.3 0.2 0.2 0.3 Net Periodic Benefit Credit (71.0) (6.0) (10.1) (9.0) (7.9) (3.9) (4.9) Capitalized Portion (2.1) (0.2) (0.2) (0.2) (0.2) (0.1) (0.2) Net Periodic Benefit Credit Recognized in Expense $ (73.1) $ (6.2) $ (10.3) $ (9.2) $ (8.1) $ (4.0) $ (5.1) 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 4.6 $ 0.3 $ 0.5 $ 0.6 $ 0.4 $ 0.3 $ 0.4 Interest Cost 46.2 3.6 7.4 5.4 4.7 2.4 2.9 Expected Return on Plan Assets (109.6) (9.0) (16.1) (13.5) (11.8) (5.9) (7.2) Amortization of Prior Service Credit (63.1) (5.3) (9.2) (8.7) (6.3) (4.0) (4.9) Amortization of Net Actuarial Loss 14.8 1.2 2.3 1.9 1.6 0.8 1.0 Net Periodic Benefit Credit (107.1) (9.2) (15.1) (14.3) (11.4) (6.4) (7.8) Capitalized Portion (2.1) (0.2) (0.2) (0.2) (0.2) (0.1) (0.2) Net Periodic Benefit Credit Recognized in Expense $ (109.2) $ (9.4) $ (15.3) $ (14.5) $ (11.6) $ (6.5) $ (8.0) 2022 AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Service Cost $ 7.4 $ 0.5 $ 0.8 $ 0.9 $ 0.6 $ 0.4 $ 0.6 Interest Cost 29.2 2.2 4.7 3.4 3.0 1.5 1.8 Expected Return on Plan Assets (110.0) (9.1) (16.3) (13.7) (12.0) (6.1) (7.3) Amortization of Prior Service Credit (71.4) (6.1) (10.4) (9.7) (7.1) (4.4) (5.3) Net Periodic Benefit Credit (144.8) (12.5) (21.2) (19.1) (15.5) (8.6) (10.2) Capitalized Portion (3.2) (0.3) (0.4) (0.3) (0.3) (0.2) (0.2) Net Periodic Benefit Credit Recognized in Expense $ (148.0) $ (12.8) $ (21.6) $ (19.4) $ (15.8) $ (8.8) $ (10.4)
Cost for Matching Contributions to the Retirement Savings Plans	The following table provides the cost for matching contributions to the retirement savings plans by Registrant: Year Ended December 31, AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) 2024 $ 81.5 $ 6.8 $ 8.0 $ 10.7 $ 7.9 $ 5.3 $ 6.5 2023 87.9 7.1 8.4 11.0 8.2 5.3 6.7 2022 81.9 6.5 7.8 11.1 7.7 4.7 6.4

BUSINESS SEGMENTS (Tables)

BUSINESS SEGMENTS (Tables)	12 Months Ended
	Dec. 31, 2024
Segment Reporting [Abstract]
Reportable Segment Information	The tables below present AEP’s reportable segment income statement information for the years ended December 31, 2024, 2023 and 2022 and reportable segment balance sheet information as of December 31, 2024 and 2023. The significant expenses disclosed below align with the segment-level information that is regularly provided to the CODM. VIU T&D AEPTHCo G&M Total Reportable Segments Corporate and Other (a) Reconciling Adjustments Consolidated 2024 (in millions) Revenues from: External Customers $ 11,414.0 $ 5,879.6 $ 425.0 $ 1,944.7 $ 19,663.3 $ 58.0 $ — $ 19,721.3 Other Operating Segments 182.6 28.1 1,525.8 100.7 1,837.2 125.1 (1,962.3) (b) — Total Revenues 11,596.6 5,907.7 1,950.8 2,045.4 21,500.5 183.1 (1,962.3) 19,721.3 Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 3,796.2 909.1 — 1,542.4 6,247.7 — (311.4) 5,936.3 Other Operation and Maintenance 3,528.0 2,166.1 162.8 129.9 5,986.8 136.3 (1,670.4) 4,452.7 Asset Impairments and Other Related Charges 13.4 52.9 — 76.2 142.5 — — 142.5 Depreciation and Amortization 1,970.6 879.5 439.7 20.9 3,310.7 (20.8) — 3,289.9 Taxes Other Than Income Taxes 535.3 724.2 314.9 2.0 1,576.4 0.4 19.5 1,596.3 Allowance for Equity Funds Used During Construction 52.4 69.2 89.4 — 211.0 — — 211.0 Interest Expense 724.3 405.5 222.3 16.6 1,368.7 612.5 (118.4) 1,862.8 Income Tax Expense (Benefit) (282.2) 154.5 214.7 25.9 112.9 (152.1) — (39.2) Equity Earnings (Loss) of Unconsolidated Subsidiaries 1.4 (1.1) 98.9 0.9 100.1 (6.4) — 93.7 Other Segment Items (c) (88.4) (41.7) (5.5) (56.8) (192.4) (108.4) 118.4 (182.4) Earnings (Loss) Attributable to AEP Common Shareholders $ 1,453.2 $ 725.7 $ 790.2 $ 289.2 $ 3,258.3 $ (291.2) $ — $ 2,967.1 Gross Property Additions $ 3,643.5 $ 2,343.6 $ 1,572.5 $ 35.1 $ 7,594.7 $ 466.6 $ (31.1) $ 8,030.2 Total Assets $ 54,996.5 $ 26,864.3 $ 18,011.9 $ 1,633.9 $ 101,506.6 $ 5,550.8 (d) $ (3,979.4) (e) $ 103,078.0 Investments in Equity Method Investees $ 9.1 $ 2.0 $ 996.1 $ — $ 1,007.2 $ 48.7 $ — $ 1,055.9 VIU T&D AEPTHCo G&M Total Reportable Segments Corporate and Other (a) Reconciling Adjustments Consolidated 2023 (in millions) Revenues from: External Customers $ 11,303.7 $ 5,677.2 $ 397.4 $ 1,543.3 $ 18,921.6 $ 60.7 $ — $ 18,982.3 Other Operating Segments 145.8 36.1 1,331.1 88.9 1,601.9 107.3 (1,709.2) (b) — Total Revenues 11,449.5 5,713.3 1,728.5 1,632.2 20,523.5 168.0 (1,709.2) 18,982.3 Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 4,150.3 1,214.8 — 1,487.8 6,852.9 — (274.6) 6,578.3 Other Operation and Maintenance 3,211.1 1,947.8 141.6 132.9 5,433.4 103.1 (1,449.7) 4,086.8 Asset Impairments and Other Related Charges 85.6 — — — 85.6 — — 85.6 Loss on the Sale of the Competitive Contracted Renewables Portfolio — — — 92.7 92.7 — — 92.7 Depreciation and Amortization 1,876.4 784.7 402.6 42.7 3,106.4 (16.0) — 3,090.4 Taxes Other Than Income Taxes 512.5 668.0 290.1 6.6 1,477.2 0.2 14.9 1,492.3 Allowance for Equity Funds Used During Construction 46.3 45.5 83.1 — 174.9 — — 174.9 Interest Expense 764.5 363.6 202.6 76.0 1,406.7 594.7 (194.5) 1,806.9 Income Tax Expense (Benefit) (45.2) 140.2 166.0 (122.9) 138.1 (83.5) — 54.6 Equity Earnings (Loss) of Unconsolidated Subsidiaries 1.4 — 82.9 (16.5) 67.8 (9.3) — 58.5 Other Segment Items (c) (148.4) (59.0) (11.3) (73.8) (292.5) (182.2) 194.7 (280.0) Earnings (Loss) Attributable to AEP Common Shareholders $ 1,090.4 $ 698.7 $ 702.9 $ (26.3) $ 2,465.7 $ (257.6) $ — $ 2,208.1 Gross Property Additions $ 3,486.8 $ 2,467.4 $ 1,528.7 $ 12.6 $ 7,495.5 $ 36.6 $ 1.4 $ 7,533.5 Total Assets $ 51,802.1 $ 24,838.4 $ 16,575.6 $ 2,598.5 $ 95,814.6 $ 5,194.0 (d) $ (4,324.6) (e) $ 96,684.0 Investments in Equity Method Investees $ 10.0 $ 3.0 $ 905.8 $ 100.6 $ 1,019.4 $ 54.2 $ — $ 1,073.6 VIU T&D AEPTHCo G&M Total Reportable Segments Corporate and Other (a) Reconciling Adjustments Consolidated 2022 (in millions) Revenues from: External Customers $ 11,292.8 $ 5,489.6 $ 357.5 $ 2,448.9 $ 19,588.8 $ 50.7 $ — $ 19,639.5 Other Operating Segments 184.7 22.4 1,319.5 18.0 1,544.6 59.2 (1,603.8) (b) — Total Revenues 11,477.5 5,512.0 1,677.0 2,466.9 21,133.4 109.9 (1,603.8) 19,639.5 Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 4,007.9 1,287.3 — 1,984.3 7,279.5 — (181.6) 7,097.9 Other Operation and Maintenance 3,287.2 1,864.2 165.7 118.7 5,435.8 130.0 (1,438.3) 4,127.5 Loss on the Expected Sale of the Kentucky Operations — — — — — 363.3 — 363.3 Asset Impairments and Other Related Charges 24.9 — — — 24.9 23.9 — 48.8 Gain on Sale of Mineral Rights — — — (116.3) (116.3) — — (116.3) Depreciation and Amortization 2,007.2 746.7 355.0 93.0 3,201.9 0.9 — 3,202.8 Taxes Other Than Income Taxes 504.9 659.9 277.6 11.1 1,453.5 0.2 16.1 1,469.8 Allowance for Equity Funds Used During Construction 29.5 33.6 70.6 — 133.7 — — 133.7 Interest Expense 650.9 328.0 169.3 51.8 1,200.0 308.9 (112.8) 1,396.1 Income Tax Expense (Benefit) (93.8) 116.9 193.6 (83.1) 133.6 (128.2) — 5.4 Equity Earnings (Loss) of Unconsolidated Subsidiaries 1.4 0.6 83.4 (192.4) (107.0) (2.4) — (109.4) Other Segment Items (c) (172.8) (52.5) (3.7) (68.6) (297.6) (53.9) 112.8 (238.7) Earnings (Loss) Attributable to AEP Common Shareholders $ 1,292.0 $ 595.7 $ 673.5 $ 283.6 $ 2,844.8 $ (537.6) $ — $ 2,307.2 Gross Property Additions $ 4,164.6 $ 2,177.3 $ 1,470.8 $ 69.2 $ 7,881.9 $ 25.9 $ (28.8) $ 7,879.0 Investments in Equity Method Investees $ 10.1 $ 3.0 $ 858.3 $ 337.6 $ 1,209.0 $ 67.7 $ — $ 1,276.7 (a) Corporate and Other primarily includes the purchasing of receivables from certain AEP utility subsidiaries. This segment also includes Parent’s guarantee revenue received from affiliates, investment income, interest income and interest expense, income tax expense and other nonallocated costs. (b) Represents inter-segment revenues. (c) Other segment items included in segment earnings (loss) attributable to AEP common shareholders primarily includes Non-Service Cost Components of Net Period Benefit Cost, Net Income (Loss) Attributable to Noncontrolling Interests and Establishment of the VA Triennial Review Regulatory Asset (2022). (d) Includes elimination of AEP Parent’s investments in wholly-owned subsidiary companies. (e) Reconciling Adjustments for Total Assets primarily include elimination of intercompany advances to affiliates and intercompany accounts receivable. The tables below present AEPTCo’s reportable segment income statement information for the years ended December 31, 2024, 2023 and 2022 and reportable segment balance sheet information as of December 31, 2024 and 2023. The significant expenses disclosed below align with the segment-level information that is regularly provided to the CODM. State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo 2024 (in millions) Revenues from: External Customers $ 378.6 $ — $ — $ 378.6 Sales to AEP Affiliates 1,512.3 — — 1,512.3 Total Revenues 1,890.9 — — 1,890.9 Other Operation and Maintenance 156.6 1.7 — 158.3 Depreciation and Amortization 430.9 — — 430.9 Taxes Other Than Income Taxes 308.7 — — 308.7 Interest Income 7.9 241.1 (238.5) (a) 10.5 Allowance for Equity Funds Used During Construction 89.4 — — 89.4 Interest Expense 214.0 238.7 (238.5) (a) 214.2 Income Tax Expense 190.2 0.1 — 190.3 Net Income $ 687.8 $ 0.6 (b) $ — $ 688.4 Gross Property Additions $ 1,481.8 $ — $ — $ 1,481.8 Total Assets $ 16,887.7 $ 8,670.4 (c) $ (9,187.8) (d) $ 16,370.3 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo 2023 (in millions) Revenues from: External Customers $ 354.2 $ — $ — $ 354.2 Sales to AEP Affiliates 1,317.8 — — 1,317.8 Total Revenues 1,672.0 — — 1,672.0 Other Operation and Maintenance 129.2 0.2 — 129.4 Depreciation and Amortization 393.8 — — 393.8 Taxes Other Than Income Taxes 283.2 — — 283.2 Interest Income 3.8 218.0 (214.8) (a) 7.0 Allowance for Equity Funds Used During Construction 83.2 — — 83.2 Interest Expense 194.2 215.1 (214.8) (a) 194.5 Income Tax Expense 145.7 1.4 — 147.1 Net Income $ 612.9 $ 1.3 (b) $ — $ 614.2 Gross Property Additions $ 1,503.1 $ — $ — $ 1,503.1 Total Assets $ 15,120.6 $ 5,486.6 (c) $ (5,534.7) (d) $ 15,072.5 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo 2022 (in millions) Revenues from: External Customers $ 340.9 $ — $ — $ 340.9 Sales to AEP Affiliates 1,283.8 — — 1,283.8 Other Revenues (0.2) — — (0.2) Total Revenues 1,624.5 — — 1,624.5 Other Operation and Maintenance 152.8 0.7 — 153.5 Depreciation and Amortization 346.2 — — 346.2 Taxes Other Than Income Taxes 271.1 — — 271.1 Interest Income 0.7 177.8 (176.9) (a) 1.6 Allowance for Equity Funds Used During Construction 70.7 — — 70.7 Interest Expense 162.5 177.1 (176.9) (a) 162.7 Income Tax Expense 169.1 — — 169.1 Net Income $ 594.2 $ — (b) $ — $ 594.2 Gross Property Additions $ 1,468.3 $ — $ — $ 1,468.3 (a) Elimination of intercompany interest income/interest expense on affiliated debt arrangement. (b) Includes elimination of AEPTCo Parent’s equity earnings in the State Transcos. (c) Primarily relates to Notes Receivable from the State Transcos. (d) Primarily relates to elimination of Notes Receivable from the State Transcos.

DERIVATIVES AND HEDGING (Tables

DERIVATIVES AND HEDGING (Tables)	12 Months Ended
	Dec. 31, 2024
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Notional Volume of Derivative Instruments	The following table represents the gross notional volume of the Registrants’ outstanding derivative contracts: Notional Volume of Derivative Instruments December 31, 2024 December 31, 2023 Primary Risk AEP AEP Texas APCo I&M OPCo PSO SWEPCo AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power (MWhs) 282.4 — 23.6 7.7 2.0 5.0 4.6 246.8 — 16.8 5.9 2.2 4.1 2.9 Natural Gas (MMBtus) 152.8 — 42.2 — — 46.2 15.4 151.6 — 37.3 — — 34.9 17.9 Heating Oil and Gasoline (Gallons) 7.9 2.0 0.9 2.0 1.1 0.7 0.9 6.5 1.8 1.0 0.6 1.2 0.7 0.9 Interest Rate (USD) $ 59.3 $ — $ — $ — $ — $ — $ — $ 80.1 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt (USD) $ 950.0 $ — $ — $ — $ — $ — $ — $ 1,300.0 $ 150.0 $ — $ — $ — $ — $ —
Fair Value of Derivative Instruments	The following tables represent the gross fair value of the Registrants’ derivative activity on the balance sheets. The derivative instruments are disclosed as gross. They are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with the accounting guidance for “Derivatives and Hedging.” Unless shown as a separate line on the balance sheets due to materiality, Current Risk Management Assets are included in Prepayments and Other Current Assets, Long-term Risk Management Assets are included in Deferred Charges and Other Noncurrent Assets, Current Risk Management Liabilities are included in Other Current Liabilities and Long-term Risk Management Liabilities are included in Deferred Credits and Other Noncurrent Liabilities on the balance sheets. December 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Assets: (in millions) Current Risk Management Assets Risk Management Contracts - Commodity $ 425.0 $ — $ 40.2 $ 28.5 $ — $ 22.3 $ 19.1 Hedging Contracts - Commodity 54.1 — — — — — — Hedging Contracts - Interest Rate — — — — — — — Total Current Risk Management Assets 479.1 — 40.2 28.5 — 22.3 19.1 Long-term Risk Management Assets Risk Management Contracts - Commodity 475.4 — 2.0 1.2 — 1.6 — Hedging Contracts - Commodity 84.6 — — — — — — Hedging Contracts - Interest Rate — — — — — — — Total Long-term Risk Management Assets 560.0 — 2.0 1.2 — 1.6 — Total Assets $ 1,039.1 $ — $ 42.2 $ 29.7 $ — $ 23.9 $ 19.1 Liabilities: Current Risk Management Liabilities Risk Management Contracts - Commodity $ 304.1 $ 0.3 $ 6.6 $ 10.5 $ 7.5 $ 7.6 $ 3.4 Hedging Contracts - Commodity 11.3 — — — — — — Hedging Contracts - Interest Rate 36.3 — — — — — — Total Current Risk Management Liabilities 351.7 0.3 6.6 10.5 7.5 7.6 3.4 Long-term Risk Management Liabilities Risk Management Contracts - Commodity 390.7 — 0.8 2.1 40.2 0.2 — Hedging Contracts - Commodity 2.7 — — — — — — Hedging Contracts - Interest Rate 35.3 — — — — — — Total Long-term Risk Management Liabilities 428.7 — 0.8 2.1 40.2 0.2 — Total Liabilities $ 780.4 $ 0.3 $ 7.4 $ 12.6 $ 47.7 $ 7.8 $ 3.4 Total MTM Derivative Contract Net Assets (Liabilities) Recognized $ 258.7 $ (0.3) $ 34.8 $ 17.1 $ (47.7) $ 16.1 $ 15.7 December 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Assets: (in millions) Current Risk Management Assets Risk Management Contracts - Commodity $ 555.1 $ — $ 24.6 $ 30.1 $ — $ 19.7 $ 12.0 Hedging Contracts - Commodity 56.7 — — — — — — Hedging Contracts - Interest Rate — — — — — — — Total Current Risk Management Assets 611.8 — 24.6 30.1 — 19.7 12.0 Long-term Risk Management Assets Risk Management Contracts - Commodity 468.8 — 0.3 12.0 — — 0.5 Hedging Contracts - Commodity 86.8 — — — — — — Hedging Contracts - Interest Rate — — — — — — — Total Long-term Risk Management Assets 555.6 — 0.3 12.0 — — 0.5 Total Assets $ 1,167.4 $ — $ 24.9 $ 42.1 $ — $ 19.7 $ 12.5 Liabilities: Current Risk Management Liabilities Risk Management Contracts - Commodity $ 588.0 $ 0.2 $ 18.5 $ 5.4 $ 6.9 $ 29.7 $ 14.9 Hedging Contracts - Commodity 8.2 — — — — — — Hedging Contracts - Interest Rate 50.5 2.7 — — — — — Total Current Risk Management Liabilities 646.7 2.9 18.5 5.4 6.9 29.7 14.9 Long-term Risk Management Liabilities Risk Management Contracts - Commodity 377.6 — 6.9 0.2 43.9 1.0 1.7 Hedging Contracts - Commodity 2.2 — — — — — — Hedging Contracts - Interest Rate 56.9 — — — — — — Total Long-term Risk Management Liabilities 436.7 — 6.9 0.2 43.9 1.0 1.7 Total Liabilities $ 1,083.4 $ 2.9 $ 25.4 $ 5.6 $ 50.8 $ 30.7 $ 16.6 Total MTM Derivative Contract Net Assets (Liabilities) Recognized $ 84.0 $ (2.9) $ (0.5) $ 36.5 $ (50.8) $ (11.0) $ (4.1) The following tables show the net amounts of assets and liabilities presented on the balance sheets. The gross amounts offset include counterparty netting of risk management and hedging contracts and associated cash collateral in accordance with accounting guidance for “Derivatives and Hedging.” All derivative contracts subject to a master netting arrangement or similar agreement are offset on the balance sheets. December 31, 2024 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Assets: (in millions) Current Risk Management Assets Gross Amounts Recognized $ 479.1 $ — $ 40.2 $ 28.5 $ — $ 22.3 $ 19.1 Gross Amounts Offset (268.7) — (4.5) (10.1) — (1.7) (1.0) Net Amounts Presented 210.4 — 35.7 18.4 — 20.6 18.1 Long-term Risk Management Assets Gross Amounts Recognized 560.0 — 2.0 1.2 — 1.6 — Gross Amounts Offset (270.9) — (0.6) (1.2) — (0.2) — Net Amounts Presented 289.1 — 1.4 — — 1.4 — Total Assets $ 499.5 $ — $ 37.1 $ 18.4 $ — $ 22.0 $ 18.1 Liabilities: Current Risk Management Liabilities Gross Amounts Recognized $ 351.7 $ 0.3 $ 6.6 $ 10.5 $ 7.5 $ 7.6 $ 3.4 Gross Amounts Offset (251.7) (0.3) (4.6) (10.2) (0.2) (1.8) (1.1) Net Amounts Presented 100.0 — 2.0 0.3 7.3 5.8 2.3 Long-term Risk Management Liabilities Gross Amounts Recognized 428.7 — 0.8 2.1 40.2 0.2 — Gross Amounts Offset (204.3) — (0.6) (1.7) — (0.2) — Net Amounts Presented 224.4 — 0.2 0.4 40.2 — — Total Liabilities $ 324.4 $ — $ 2.2 $ 0.7 $ 47.5 $ 5.8 $ 2.3 Total MTM Derivative Contract Net Assets (Liabilities) $ 175.1 $ — $ 34.9 $ 17.7 $ (47.5) $ 16.2 $ 15.8 December 31, 2023 AEP AEP Texas APCo I&M OPCo PSO SWEPCo Assets: (in millions) Current Risk Management Assets Gross Amounts Recognized $ 611.8 $ — $ 24.6 $ 30.1 $ — $ 19.7 $ 12.0 Gross Amounts Offset (394.3) — (2.2) (2.3) — (0.7) (0.4) Net Amounts Presented 217.5 — 22.4 27.8 — 19.0 11.6 Long-term Risk Management Assets Gross Amounts Recognized 555.6 — 0.3 12.0 — — 0.5 Gross Amounts Offset (234.4) — (0.3) (0.2) — — (0.5) Net Amounts Presented 321.2 — — 11.8 — — — Total Assets $ 538.7 $ — $ 22.4 $ 39.6 $ — $ 19.0 $ 11.6 Liabilities: Current Risk Management Liabilities Gross Amounts Recognized $ 646.7 $ 2.9 $ 18.5 $ 5.4 $ 6.9 $ 29.7 $ 14.9 Gross Amounts Offset (417.1) (0.2) (2.6) (3.4) (0.1) (0.8) (0.5) Net Amounts Presented 229.6 2.7 15.9 2.0 6.8 28.9 14.4 Long-term Risk Management Liabilities Gross Amounts Recognized 436.7 — 6.9 0.2 43.9 1.0 1.7 Gross Amounts Offset (194.9) — (0.3) (0.2) — — (0.5) Net Amounts Presented 241.8 — 6.6 — 43.9 1.0 1.2 Total Liabilities $ 471.4 $ 2.7 $ 22.5 $ 2.0 $ 50.7 $ 29.9 $ 15.6 Total MTM Derivative Contract Net Assets (Liabilities) $ 67.3 $ (2.7) $ (0.1) $ 37.6 $ (50.7) $ (10.9) $ (4.0)
Amount of Gain (Loss) Recognized on Risk Management Contracts	The tables below present the Registrants’ amount of gain (loss) recognized on risk management contracts: Amount of Gain (Loss) Recognized on Risk Management Contracts Year Ended December 31, 2024 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ (23.7) $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues (171.5) — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.2 (23.9) — — — Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 3.0 — 2.7 0.2 — — — Other Operation (0.2) — — — — — (0.1) Maintenance (0.2) (0.1) — — — — — Regulatory Assets (a) 73.0 (0.1) 21.7 2.8 (1.8) 26.0 14.2 Regulatory Liabilities (a) 270.7 — 53.4 13.4 — 93.6 95.0 Total Gain (Loss) on Risk Management Contracts $ 151.1 $ (0.2) $ 78.0 $ (7.5) $ (1.8) $ 119.6 $ 109.1 Year Ended December 31, 2023 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 24.6 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues (423.8) — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.1 24.5 — — — Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 2.5 — 2.3 0.1 — — — Other Operation (0.2) (0.1) — — — — — Maintenance (0.8) (0.3) (0.1) (0.1) (0.1) (0.1) (0.2) Regulatory Assets (a) (94.8) (0.2) (21.9) (3.1) (14.0) (29.8) (15.5) Regulatory Liabilities (a) 169.7 — 1.0 7.8 — 88.7 70.7 Total Gain (Loss) on Risk Management Contracts $ (322.8) $ (0.6) $ (18.6) $ 29.2 $ (14.1) $ 58.8 $ 55.0 Year Ended December 31, 2022 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 11.1 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 313.8 — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.5 10.6 — — — Purchased Electricity, Fuel and Other Consumables Used for Electric Generation 5.0 — 4.5 0.1 — 0.2 — Other Operation 4.8 1.5 0.4 0.5 0.8 0.6 0.8 Maintenance 6.7 1.8 0.9 0.6 1.2 0.8 1.1 Regulatory Assets (a) 52.6 0.1 (0.1) (0.8) 52.1 3.6 (2.1) Regulatory Liabilities (a) 299.7 (0.6) 82.4 8.6 3.7 98.5 77.9 Total Gain on Risk Management Contracts $ 693.7 $ 2.8 $ 88.6 $ 19.6 $ 57.8 $ 103.7 $ 77.7 (a) Represents realized and unrealized gains and losses subject to regulatory accounting treatment recorded as either current or noncurrent on the balance sheets.
Impact of Fair Value Hedges on Balance Sheet	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 December 31, 2024 December 31, 2023 December 31, 2024 December 31, 2023 (in millions) Long-term Debt (a) (b) $ (898.6) $ (878.2) $ 49.3 $ 68.4 (a) Amounts included within Noncurrent Liabilities line item Long-term Debt and Current Liabilities line item Long-term Debt Due Within One Year on the balance sheet. (b) Amounts include $(22) million and $(30) million as of December 31, 2024 and 2023, respectively, for the fair value hedge adjustment of hedged debt obligations for which hedge accounting has been discontinued.
Gain (Loss) on Hedging Instruments	The pretax effects of fair value hedge accounting on income were as follows: Years Ended December 31, 2024 2023 2022 (in millions) Gain (Loss) on Interest Rate Contracts: Fair Value Hedging Instruments (a) $ 26.8 $ 29.0 $ (90.4) Fair Value Portion of Long-term Debt (a) (26.8) (29.0) 90.4 (a) Gain (Loss) is included in Interest Expense on the statements of income.
Impact of Cash Flow Hedges on the Balance Sheet	Cash flow hedges included in Accumulated Other Comprehensive Income (Loss) on the balance sheets were: Impact of Cash Flow Hedges on the Registrants’ Balance Sheets December 31, 2024 December 31, 2023 Portion Expected to Portion Expected to AOCI be Reclassed to AOCI be Reclassed to Gain (Loss) Net Income During Gain (Loss) Net Income During Net of Tax the Next Twelve Months Net of Tax the Next Twelve Months Commodity Interest Rate Commodity Interest Rate Commodity Interest Rate Commodity Interest Rate (in millions) AEP $ 98.5 $ 3.3 $ 33.9 $ 2.8 $ 104.9 $ (8.1) $ 38.3 $ 3.2 AEP Texas — 6.3 — 0.7 — 0.5 — 0.2 APCo — 5.1 — 0.8 — 5.9 — 0.8 I&M — (5.1) — (0.4) — (5.5) — (0.4) PSO — 3.6 — 0.2 — (0.2) — — SWEPCo — 1.0 — 0.3 — 1.3 — 0.3

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	12 Months Ended
	Dec. 31, 2024
Fair Value Disclosures [Abstract]
Schedule of Book Values and Fair Values of Long-term Debt	The book values and fair values of Long-term Debt are summarized in the following table: December 31, 2024 2023 Company Book Value Fair Value Book Value Fair Value (in millions) AEP $ 42,642.8 $ 38,964.7 $ 40,143.2 $ 37,325.7 AEP Texas 6,441.6 5,831.4 5,889.8 5,400.7 AEPTCo 5,768.1 4,853.1 5,414.4 4,796.9 APCo 5,660.3 5,346.0 5,588.3 5,390.1 I&M 3,494.3 3,153.8 3,499.4 3,291.6 OPCo 3,715.7 3,203.4 3,366.8 2,992.1 PSO 2,855.6 2,562.1 2,384.6 2,154.3 SWEPCo 3,980.8 3,431.5 3,646.9 3,209.7
Schedule of Available-For-Sale Securities	The following is a summary of Other Temporary Investments and Restricted Cash: December 31, 2024 Gross Gross Unrealized Unrealized Fair Other Temporary Investments and Restricted Cash Cost Gains Losses Value (in millions) Restricted Cash (a) $ 43.1 $ — $ — $ 43.1 Other Cash Deposits 13.9 — — 13.9 Fixed Income Securities – Mutual Funds (b) 167.2 — (5.3) 161.9 Equity Securities – Mutual Funds 12.7 26.9 — 39.6 Total Other Temporary Investments and Restricted Cash $ 236.9 $ 26.9 $ (5.3) $ 258.5 December 31, 2023 Gross Gross Unrealized Unrealized Fair Other Temporary Investments and Restricted Cash Cost Gains Losses Value (in millions) Restricted Cash (a) $ 48.9 $ — $ — $ 48.9 Other Cash Deposits 13.9 — — 13.9 Fixed Income Securities – Mutual Funds (b) 165.9 — (6.2) 159.7 Equity Securities – Mutual Funds 14.8 25.9 — 40.7 Total Other Temporary Investments and Restricted Cash $ 243.5 $ 25.9 $ (6.2) $ 263.2 (a) Primarily represents amounts held for the repayment of debt. (b) Primarily short and intermediate maturities which may be sold and do not contain maturity dates. The following is a summary of nuclear trust fund investments: December 31, 2024 2023 Gross Gross Other-Than- Gross Gross Other-Than- Fair Unrealized Unrealized Temporary Fair Unrealized Unrealized Temporary Value Gains Losses Impairments Value Gains Losses Impairments (in millions) Cash and Cash Equivalents $ 23.3 $ — $ — $ — $ 16.8 $ — $ — $ — Fixed Income Securities: United States Government 1,322.8 8.2 (5.3) (20.2) 1,273.0 28.6 (3.9) (33.2) Corporate Debt 211.3 0.7 (9.8) (5.8) 132.1 4.8 (5.2) (8.6) State and Local Government — — — — 1.7 — — — Subtotal Fixed Income Securities 1,534.1 8.9 (15.1) (26.0) 1,406.8 33.4 (9.1) (41.8) Equity Securities - Domestic 2,837.7 2,288.9 (0.4) — 2,436.6 1,869.5 (0.9) — Spent Nuclear Fuel and Decommissioning Trusts $ 4,395.1 $ 2,297.8 $ (15.5) $ (26.0) $ 3,860.2 $ 1,902.9 $ (10.0) $ (41.8)
Schedule of Fixed Income And Equity Securities Activity	The following table provides the activity for fixed income and equity securities within Other Temporary Investments: Years Ended December 31, 2024 2023 2022 (in millions) Proceeds from Investment Sales $ 26.8 $ 7.6 $ 30.2 Purchases of Investments 20.1 18.5 18.8 Gross Realized Gains on Investment Sales 6.3 1.1 6.1 Gross Realized Losses on Investment Sales 0.8 0.3 1.3
Schedule of Securities Activity	The following table provides the securities activity within the decommissioning and SNF trusts: Years Ended December 31, 2024 2023 2022 (in millions) Proceeds from Investment Sales $ 2,851.2 $ 2,787.5 $ 2,713.6 Purchases of Investments 2,902.4 2,845.1 2,765.4 Gross Realized Gains on Investment Sales 125.5 99.0 52.4 Gross Realized Losses on Investment Sales 11.5 26.6 42.6
Schedule of Contractual Maturities, Fair Value of Debt Securities	The fair value of fixed income securities held in the nuclear trust funds, summarized by contractual maturities, as of December 31, 2024 was as follows: Fair Value of Fixed Income Securities (in millions) Within 1 year $ 376.4 After 1 year through 5 years 598.8 After 5 years through 10 years 236.2 After 10 years 322.7 Total $ 1,534.1
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	The following tables set forth, by level within the fair value hierarchy, the Registrants’ financial assets and liabilities that were accounted for at fair value on a recurring basis. As required by the accounting guidance for “Fair Value Measurements and Disclosures,” financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. Management’s assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. There have not been any significant changes in management’s valuation techniques. AEP December 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments and Restricted Cash Restricted Cash $ 43.1 $ — $ — $ — $ 43.1 Other Cash Deposits (a) — — — 13.9 13.9 Fixed Income Securities – Mutual Funds 161.9 — — — 161.9 Equity Securities – Mutual Funds (b) 39.6 — — — 39.6 Total Other Temporary Investments and Restricted Cash 244.6 — — 13.9 258.5 Risk Management Assets Risk Management Commodity Contracts (c) (d) 2.9 597.3 291.6 (517.2) 374.6 Cash Flow Hedges: Commodity Hedges (c) — 115.6 21.9 (12.6) 124.9 Total Risk Management Assets 2.9 712.9 313.5 (529.8) 499.5 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 9.6 — — 13.7 23.3 Fixed Income Securities: United States Government — 1,322.8 — — 1,322.8 Corporate Debt — 211.3 — — 211.3 State and Local Government — — — — — Subtotal Fixed Income Securities — 1,534.1 — — 1,534.1 Equity Securities – Domestic (b) 2,837.7 — — — 2,837.7 Total Spent Nuclear Fuel and Decommissioning Trusts 2,847.3 1,534.1 — 13.7 4,395.1 Total Assets $ 3,094.8 $ 2,247.0 $ 313.5 $ (502.2) $ 5,153.1 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (d) $ 4.4 $ 534.1 $ 147.7 $ (433.6) $ 252.6 Cash Flow Hedges: Commodity Hedges (c) — 12.6 0.2 (12.6) 0.2 Fair Value Hedges — 71.6 — — 71.6 Total Risk Management Liabilities $ 4.4 $ 618.3 $ 147.9 $ (446.2) $ 324.4 December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments and Restricted Cash Restricted Cash $ 48.9 $ — $ — $ — $ 48.9 Other Cash Deposits (a) — — — 13.9 13.9 Fixed Income Securities – Mutual Funds 159.7 — — — 159.7 Equity Securities – Mutual Funds (b) 40.7 — — — 40.7 Total Other Temporary Investments and Restricted Cash 249.3 — — 13.9 263.2 Risk Management Assets Risk Management Commodity Contracts (c) (f) 9.7 736.9 274.3 (617.0) 403.9 Cash Flow Hedges: Commodity Hedges (c) — 123.5 19.8 (8.5) 134.8 Total Risk Management Assets 9.7 860.4 294.1 (625.5) 538.7 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 7.8 — — 9.0 16.8 Fixed Income Securities: United States Government — 1,273.0 — — 1,273.0 Corporate Debt — 132.1 — — 132.1 State and Local Government — 1.7 — — 1.7 Subtotal Fixed Income Securities — 1,406.8 — — 1,406.8 Equity Securities – Domestic (b) 2,436.6 — — — 2,436.6 Total Spent Nuclear Fuel and Decommissioning Trusts 2,444.4 1,406.8 — 9.0 3,860.2 Total Assets $ 2,703.4 $ 2,267.2 $ 294.1 $ (602.6) $ 4,662.1 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (f) $ 24.7 $ 783.8 $ 154.1 $ (600.3) $ 362.3 Cash Flow Hedges: Commodity Hedges (c) — 9.6 0.6 (8.5) 1.7 Interest Rate Hedges — 9.0 — — 9.0 Fair Value Hedges — 98.4 — — 98.4 Total Risk Management Liabilities $ 24.7 $ 900.8 $ 154.7 $ (608.8) $ 471.4 AEP Texas December 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 23.5 $ — $ — $ — $ 23.5 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 0.3 $ — $ (0.3) $ — December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 34.0 $ — $ — $ — $ 34.0 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 0.2 $ — $ (0.2) $ — Cash Flow Hedges: Interest Rate Hedges — 2.7 — — 2.7 Total Risk Management Liabilities $ — $ 2.9 $ — $ (0.2) $ 2.7 APCo December 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 16.2 $ — $ — $ — $ 16.2 Risk Management Assets Risk Management Commodity Contracts (c) — 6.5 35.2 (4.6) 37.1 Total Assets $ 16.2 $ 6.5 $ 35.2 $ (4.6) $ 53.3 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 6.9 $ — $ (4.7) $ 2.2 December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 14.9 $ — $ — $ — $ 14.9 Risk Management Assets Risk Management Commodity Contracts (c) — 1.1 23.5 (2.2) 22.4 Total Assets $ 14.9 $ 1.1 $ 23.5 $ (2.2) $ 37.3 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 24.0 $ 1.1 $ (2.6) $ 22.5 I&M December 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ 19.9 $ 6.9 $ (8.4) $ 18.4 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 9.6 — — 13.7 23.3 Fixed Income Securities: United States Government — 1,322.8 — — 1,322.8 Corporate Debt — 211.3 — — 211.3 State and Local Government — — — — — Subtotal Fixed Income Securities — 1,534.1 — — 1,534.1 Equity Securities - Domestic (b) 2,837.7 — — — 2,837.7 Total Spent Nuclear Fuel and Decommissioning Trusts 2,847.3 1,534.1 — 13.7 4,395.1 Total Assets $ 2,847.3 $ 1,554.0 $ 6.9 $ 5.3 $ 4,413.5 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 9.2 $ 0.5 $ (9.0) $ 0.7 December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ 37.4 $ 4.5 $ (2.3) $ 39.6 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 7.8 — — 9.0 16.8 Fixed Income Securities: United States Government — 1,273.0 — — 1,273.0 Corporate Debt — 132.1 — — 132.1 State and Local Government — 1.7 — — 1.7 Subtotal Fixed Income Securities — 1,406.8 — — 1,406.8 Equity Securities - Domestic (b) 2,436.6 — — — 2,436.6 Total Spent Nuclear Fuel and Decommissioning Trusts 2,444.4 1,406.8 — 9.0 3,860.2 Total Assets $ 2,444.4 $ 1,444.2 $ 4.5 $ 6.7 $ 3,899.8 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 3.7 $ 1.7 $ (3.4) $ 2.0 OPCo December 31, 2024 Level 1 Level 2 Level 3 Other Total Liabilities: (in millions) Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 0.2 $ 47.5 $ (0.2) $ 47.5 December 31, 2023 Level 1 Level 2 Level 3 Other Total Liabilities: (in millions) Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 0.2 $ 50.6 $ (0.1) $ 50.7 PSO December 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ 3.1 $ 20.8 $ (1.9) $ 22.0 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 7.0 $ 0.8 $ (2.0) $ 5.8 December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ — $ 19.7 $ (0.7) $ 19.0 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 29.6 $ 1.1 $ (0.8) $ 29.9 SWEPCo December 31, 2024 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 3.4 $ — $ — $ — $ 3.4 Risk Management Assets Risk Management Commodity Contracts (c) — 1.0 18.1 (1.0) 18.1 Total Assets $ 3.4 $ 1.0 $ 18.1 $ (1.0) $ 21.5 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 2.8 $ 0.6 $ (1.1) $ 2.3 December 31, 2023 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) $ — $ 0.5 $ 12.0 $ (0.9) $ 11.6 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) $ — $ 15.7 $ 0.9 $ (1.0) $ 15.6 (a) Amounts in “Other” column primarily represent cash deposits in bank accounts with financial institutions or third-parties. Level 1 and Level 2 amounts primarily represent investments in money market funds. (b) Amounts represent publicly-traded equity securities and equity-based mutual funds. (c) Amounts in “Other” column primarily represent counterparty netting of risk management and hedging contracts and associated cash collateral under the accounting guidance for “Derivatives and Hedging.” (d) The December 31, 2024 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $(1) million in 2025; Level 2 matures $16 million in 2025, $43 million in periods 2026-2028, $4 million in periods 2029-2030; Level 3 matures $106 million in 2025, $45 million in periods 2026-2028, $9 million in periods 2029-2030 and $(16) million in periods 2031-2034. Risk management commodity contracts are substantially comprised of energy contracts. (e) Amounts in “Other” column primarily represent accrued interest receivables from financial institutions. Level 1 amounts primarily represent investments in money market funds. (f) The December 31, 2023 maturities of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $(11) million in 2024 and $(4) million in 2025-2027; Level 2 matures $(99) million in 2024, $(44) million in periods 2025-2027; $7 million in periods 2028-2029 and $2 million in periods 2030-2033; Level 3 matures $74 million in 2024, $43 million in periods 2025-2027, $18 million in periods 2028-2029 and $(16) million in periods 2030-2033. Risk management commodity contracts are substantially comprised of energy contracts.
Schedule of Changes in Fair Value of Net Trading Derivatives Classified as Level 3	The following tables set forth a reconciliation of changes in the fair value of net trading derivatives classified as Level 3 in the fair value hierarchy: Year Ended December 31, 2024 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of December 31, 2023 $ 139.4 $ 22.4 $ 2.8 $ (50.6) $ 18.6 $ 11.1 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 90.3 24.1 7.3 (1.1) 26.2 23.6 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) 3.9 — — — — — Settlements (167.6) (46.5) (10.0) 7.9 (44.8) (36.0) Transfers into Level 3 (d) (e) 6.8 — — — — — Transfers out of Level 3 (e) (6.4) — — — — 0.5 Changes in Fair Value Allocated to Regulated Jurisdictions (f) 84.4 35.2 6.3 (3.7) 20.0 18.3 Balance as of December 31, 2024 $ 165.6 $ 35.2 $ 6.4 $ (47.5) $ 20.0 $ 17.5 Year Ended December 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) 52.1 (11.7) 4.2 (3.6) 29.8 20.0 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) 71.1 — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) (17.4) — — — — — Settlements (172.2) (57.3) (8.8) 5.6 (53.4) (34.2) Transfers into Level 3 (d) (e) (6.1) — — — — — Transfers out of Level 3 (e) 3.8 — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 47.7 22.3 2.8 (12.6) 18.5 11.1 Balance as of December 31, 2023 $ 139.4 $ 22.4 $ 2.8 $ (50.6) $ 18.6 $ 11.1 Year Ended December 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) 69.5 3.0 3.7 6.5 24.2 35.8 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (34.9) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 9.6 — — — — — Settlements (154.6) (44.7) (3.0) 0.3 (36.3) (45.0) Transfers into Level 3 (d) (e) 1.7 — — — — — Transfers out of Level 3 (e) 0.1 — — — — 6.9 Changes in Fair Value Allocated to Regulated Jurisdictions (f) 165.9 69.1 4.6 45.7 23.7 5.6 Balance as of December 31, 2022 $ 160.4 $ 69.1 $ 4.6 $ (40.0) $ 23.7 $ 14.2 (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.
Schedule of Significant Unobservable Inputs for Level 3	The following tables quantify the significant unobservable inputs used in developing the fair value of Level 3 positions: Significant Unobservable Inputs December 31, 2024 Significant Input/Range Type of Fair Value Valuation Unobservable Weighted Company Input Assets Liabilities Technique Input (a) Low High Average (c) (in millions) AEP Energy Contracts $ 221.2 $ 144.6 Discounted Cash Flow Forward Market Price $ 2.75 $ 149.30 $ 49.34 AEP FTRs 92.3 3.3 Discounted Cash Flow Forward Market Price (29.48) 19.70 0.24 APCo FTRs 35.2 — Discounted Cash Flow Forward Market Price (0.25) 9.32 1.56 I&M FTRs 6.9 0.5 Discounted Cash Flow Forward Market Price (4.07) 9.32 1.34 OPCo Energy Contracts — 47.5 Discounted Cash Flow Forward Market Price 14.53 72.40 42.44 PSO FTRs 20.8 0.8 Discounted Cash Flow Forward Market Price (29.48) 10.54 (3.88) SWEPCo FTRs 18.1 0.6 Discounted Cash Flow Forward Market Price (29.48) 10.54 (3.88) December 31, 2023 Significant Input/Range Type of Fair Value Valuation Unobservable Weighted Company Input Assets Liabilities Technique Input Low High Average (c) (in millions) AEP Energy Contracts $ 225.5 $ 144.9 Discounted Cash Flow Forward Market Price (a) $ 5.21 $ 153.77 $ 45.05 AEP Natural Gas Contracts — 0.5 Discounted Cash Flow Forward Market Price (b) 3.11 3.11 3.11 AEP FTRs 68.6 9.3 Discounted Cash Flow Forward Market Price (a) (25.45) 17.07 — APCo FTRs 23.5 1.1 Discounted Cash Flow Forward Market Price (a) (1.04) 6.45 1.36 I&M FTRs 4.5 1.7 Discounted Cash Flow Forward Market Price (a) (1.48) 8.40 0.85 OPCo Energy Contracts — 50.6 Discounted Cash Flow Forward Market Price (a) 22.92 67.53 42.85 PSO FTRs 19.7 1.1 Discounted Cash Flow Forward Market Price (a) (25.45) 4.80 (4.33) SWEPCo Natural Gas Contracts — 0.5 Discounted Cash Flow Forward Market Price (b) 3.11 3.11 3.11 SWEPCo FTRs 12.0 0.4 Discounted Cash Flow Forward Market Price (a) (25.45) 4.80 (4.33) (a) Represents market prices in dollars per MWh. (b) Represents market prices in dollars per MMBtu. (c) The weighted-average is the product of the forward market price of the underlying commodity and volume weighted by term.
Schedule of Sensitivity of Fair Value Measurements	The following table provides the measurement uncertainty of fair value measurements to increases (decreases) in significant unobservable inputs related to Energy Contracts, Natural Gas Contracts, FTRs and Other Investments for the Registrants as of December 31, 2024 and 2023: 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)	12 Months Ended
	Dec. 31, 2024
Income Tax Disclosure [Abstract]
Schedule of Details of Income Taxes as Reported	The details of the Registrants’ Income Tax Expense (Benefit) as reported are as follows: Year Ended December 31, 2024 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Federal: Current $ (2.8) $ 22.1 $ 75.1 $ 79.9 $ 16.6 $ 41.5 $ (119.0) $ (111.4) Deferred (57.9) 77.1 89.1 (17.8) (118.8) (2.7) 20.1 (86.1) Total Federal (60.7) 99.2 164.2 62.1 (102.2) 38.8 (98.9) (197.5) State and Local: Current (5.2) 2.9 5.6 12.6 7.0 3.1 (0.2) 1.8 Deferred 26.7 — 20.5 0.4 — 10.5 (0.5) 11.7 Total State and Local 21.5 2.9 26.1 13.0 7.0 13.6 (0.7) 13.5 Income Tax Expense (Benefit) $ (39.2) $ 102.1 $ 190.3 $ 75.1 $ (95.2) $ 52.4 $ (99.6) $ (184.0) Year Ended December 31, 2023 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Federal: Current $ (116.7) $ 19.8 $ 93.9 $ 62.2 $ 93.2 $ 46.6 $ (60.8) $ (88.1) Deferred 115.9 63.5 52.3 (60.5) (56.9) 2.8 2.9 59.9 Total Federal (0.8) 83.3 146.2 1.7 36.3 49.4 (57.9) (28.2) State and Local: Current 69.0 2.7 9.1 6.3 21.1 (0.3) 0.3 1.0 Deferred (13.6) (0.1) (8.2) 6.2 1.2 5.2 4.0 (6.1) Total State and Local 55.4 2.6 0.9 12.5 22.3 4.9 4.3 (5.1) Income Tax Expense (Benefit) $ 54.6 $ 85.9 $ 147.1 $ 14.2 $ 58.6 $ 54.3 $ (53.6) $ (33.3) Year Ended December 31, 2022 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Federal: Current $ 113.1 $ 29.0 $ 98.0 $ (61.0) $ 43.4 $ (27.0) $ (3.3) $ (32.3) Deferred (88.8) 41.4 46.0 86.6 (51.3) 73.3 (50.5) 13.4 Total Federal 24.3 70.4 144.0 25.6 (7.9) 46.3 (53.8) (18.9) State and Local: Current 26.6 2.2 8.8 (0.4) 10.9 (0.3) — (1.8) Deferred (45.5) — 16.3 (7.0) 1.2 (1.8) 4.6 (4.5) Total State and Local (18.9) 2.2 25.1 (7.4) 12.1 (2.1) 4.6 (6.3) Income Tax Expense (Benefit) $ 5.4 $ 72.6 $ 169.1 $ 18.2 $ 4.2 $ 44.2 $ (49.2) $ (25.2)
Schedule of Reconciliation of Federal Statutory Tax Rate to Reported Tax Rate	The following are reconciliations for the Registrants between the federal income taxes computed by multiplying pretax income by the federal statutory tax rate and the income taxes reported: Year Ended December 31, 2024 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Net Income $ 2,975.8 $ 420.1 $ 688.4 $ 421.7 $ 391.4 $ 305.6 $ 249.3 $ 325.7 Less: Equity Earnings (1.4) — — — — — — (1.4) Income Tax Expense (Benefit) (39.2) 102.1 190.3 75.1 (95.2) 52.4 (99.6) (184.0) Pretax Income $ 2,935.2 $ 522.2 $ 878.7 $ 496.8 $ 296.2 $ 358.0 $ 149.7 $ 140.3 Income Taxes on Pretax Income at Statutory Rate (21%) $ 616.5 $ 109.7 $ 184.5 $ 104.3 $ 62.2 $ 75.2 $ 31.4 $ 29.5 Increase (Decrease) in Income Taxes Resulting from the Following Items: Reversal of Origination Flow-Through 20.5 0.8 2.7 6.6 4.0 2.7 0.4 2.1 Investment Tax Credit Amortization (58.4) (0.9) — 0.1 (2.0) 0.1 (1.4) (0.1) Production Tax Credits (214.2) — — (0.3) (69.0) — (73.8) (70.7) State and Local Income Taxes, Net 16.7 2.3 20.5 10.3 5.5 10.7 (0.6) 10.6 Removal Costs (14.6) — — (11.2) (3.7) — — — AFUDC Equity (46.5) (9.6) (18.8) (5.3) (2.8) (4.9) (1.6) (2.8) Tax Reform Excess ADIT Reversal (91.6) (5.1) 1.6 (30.1) (15.5) (31.1) (5.5) (4.0) Remeasurement of Excess ADIT (262.2) 6.4 — — (73.3) — (48.6) (146.8) Other (5.4) (1.5) (0.2) 0.7 (0.6) (0.3) 0.1 (1.8) Income Tax Expense (Benefit) $ (39.2) $ 102.1 $ 190.3 $ 75.1 $ (95.2) $ 52.4 $ (99.6) $ (184.0) Effective Income Tax Rate (1.3) % 19.6 % 21.7 % 15.1 % (32.1) % 14.6 % (66.5) % (131.1) % . Year Ended December 31, 2023 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Net Income $ 2,212.6 $ 370.4 $ 614.2 $ 294.4 $ 335.9 $ 328.2 $ 208.8 $ 223.8 Less: Equity Earnings (1.4) — — — — — — (1.4) Income Tax Expense (Benefit) 54.6 85.9 147.1 14.2 58.6 54.3 (53.6) (33.3) Pretax Income $ 2,265.8 $ 456.3 $ 761.3 $ 308.6 $ 394.5 $ 382.5 $ 155.2 $ 189.1 Income Taxes on Pretax Income at Statutory Rate (21%) $ 475.8 $ 95.8 $ 159.9 $ 64.8 $ 82.8 $ 80.3 $ 32.6 $ 39.7 Increase (Decrease) in Income Taxes Resulting from the Following Items: Reversal of Origination Flow-Through 26.0 0.6 2.4 9.9 6.4 2.6 0.4 2.1 Investment Tax Credit Amortization (50.3) (0.7) — — (1.6) — (1.4) (0.2) Production Tax Credits (175.2) — — (0.1) — — (64.3) (67.1) State and Local Income Taxes, Net 43.7 2.1 0.7 9.9 17.5 3.9 3.5 (4.0) Removal Costs (22.0) — — (5.1) (11.8) — — — AFUDC Equity (39.8) (6.0) (17.5) (5.5) (2.3) (3.6) (1.8) (2.4) Tax Reform Excess ADIT Reversal (151.1) (6.0) 1.7 (17.3) (30.0) (28.9) (23.3) (12.6) Remeasurement of Excess ADIT (46.0) — — (46.0) — — — — Federal Return to Provision — (0.1) — 3.4 (2.5) (0.4) 0.6 1.0 Disallowance Cost — — — — — — — 12.0 Other (6.5) 0.2 (0.1) 0.2 0.1 0.4 0.1 (1.8) Income Tax Expense (Benefit) $ 54.6 $ 85.9 $ 147.1 $ 14.2 $ 58.6 $ 54.3 $ (53.6) $ (33.3) Effective Income Tax Rate 2.4 % 18.8 % 19.3 % 4.6 % 14.9 % 14.2 % (34.5) % (17.6) % Year Ended December 31, 2022 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Net Income $ 2,305.6 $ 307.9 $ 594.2 $ 394.2 $ 324.7 $ 287.8 $ 167.6 $ 294.3 Less: Equity Earnings (1.4) — — — — (0.6) — (1.4) Income Tax Expense (Benefit) 5.4 72.6 169.1 18.2 4.2 44.2 (49.2) (25.2) Pretax Income $ 2,309.6 $ 380.5 $ 763.3 $ 412.4 $ 328.9 $ 331.4 $ 118.4 $ 267.7 Income Taxes on Pretax Income at Statutory Rate (21%) $ 485.0 $ 79.9 $ 160.3 $ 86.6 $ 69.1 $ 69.6 $ 24.9 $ 56.2 Increase (Decrease) in Income Taxes Resulting from the Following Items: Reversal of Origination Flow-Through 17.1 — — 4.7 2.9 3.0 — 2.3 Investment Tax Credit Amortization (14.3) — — — (3.1) — (1.6) — Production Tax Credits (197.1) — — — — — (47.7) (57.1) State and Local Income Taxes, Net (14.0) 1.7 19.8 (5.9) 9.6 (1.6) 4.3 (4.9) Removal Costs (26.5) — — (9.8) (12.4) — — — AFUDC Equity (29.3) (4.1) (14.8) (3.7) (2.1) (2.9) — — Tax Reform Excess ADIT Reversal (214.5) (5.5) — (50.9) (54.0) (27.5) (25.4) (14.8) Federal Return to Provision (17.4) — — (2.8) (6.2) 3.5 (3.7) — Other 16.4 0.6 3.8 — 0.4 0.1 — (6.9) Income Tax Expense (Benefit) $ 5.4 $ 72.6 $ 169.1 $ 18.2 $ 4.2 $ 44.2 $ (49.2) $ (25.2) Effective Income Tax Rate 0.2 % 19.1 % 22.2 % 4.4 % 1.3 % 13.3 % (41.6) % (9.4)
Schedule of Deferred Tax Assets and Liabilities	The following tables show elements of the net deferred tax liability and significant temporary differences for each Registrant. Amounts presented for 2023 were recast to allocate “Deferred State Income Taxes”, and other miscellaneous temporary differences, amongst other categories to substantively reflect the elements of the net deferred tax liability. Year Ended December 31, 2024 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Deferred Tax Assets $ 2,651.9 $ 139.1 $ 172.6 $ 379.1 $ 1,072.2 $ 186.5 $ 266.9 $ 292.8 Deferred Tax Liabilities (12,624.3) (1,461.8) (1,451.2) (2,412.6) (2,248.0) (1,387.6) (1,197.5) (1,564.1) Net Deferred Tax Liabilities $ (9,972.4) $ (1,322.7) $ (1,278.6) $ (2,033.5) $ (1,175.8) $ (1,201.1) $ (930.6) $ (1,271.3) Property Related Temporary Differences $ (8,939.7) $ (1,364.0) $ (1,416.6) $ (1,784.8) $ (189.9) $ (1,290.9) $ (1,009.8) $ (1,353.1) Amounts Due to Customers for Future Income Taxes 779.6 109.3 121.4 119.0 73.1 95.6 80.7 90.2 Securitized Assets (133.4) (26.5) — (25.7) — — — (81.1) Regulatory Assets (966.2) (63.2) (0.2) (302.4) (49.2) (45.3) (53.1) (87.0) Accrued Nuclear Decommissioning (1,052.2) — — — (1,052.2) — — — Net Operating Loss Carryforward 110.3 — 2.5 0.4 — 2.9 27.8 36.5 Valuation Allowance (35.0) — (0.1) — — — — — Tax Credit Carryforward 197.5 4.3 — 0.1 39.6 38.5 26.5 31.7 Operating Lease Liability 145.3 12.3 0.3 16.2 13.5 13.3 27.1 35.7 Investment in Partnership (302.1) — — (0.1) — (0.8) — (1.5) All Other, Net 223.5 5.1 14.1 (56.2) (10.7) (14.4) (29.8) 57.3 Net Deferred Tax Liabilities $ (9,972.4) $ (1,322.7) $ (1,278.6) $ (2,033.5) $ (1,175.8) $ (1,201.1) $ (930.6) $ (1,271.3) Year Ended December 31, 2023 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Deferred Tax Assets $ 3,216.1 $ 173.6 $ 188.0 $ 472.9 $ 1,014.0 $ 271.5 $ 282.4 $ 441.5 Deferred Tax Liabilities (12,631.8) (1,401.4) (1,335.7) (2,484.8) (2,183.9) (1,424.2) (1,113.6) (1,620.8) Net Deferred Tax Liabilities $ (9,415.7) $ (1,227.8) $ (1,147.7) $ (2,011.9) $ (1,169.9) $ (1,152.7) $ (831.2) $ (1,179.3) Property Related Temporary Differences $ (8,809.0) $ (1,274.0) $ (1,304.2) $ (1,805.9) $ (315.6) $ (1,243.2) $ (941.9) $ (1,306.0) Amounts Due to Customers for Future Income Taxes 898.1 109.3 120.8 128.0 103.2 104.6 99.0 142.5 Securitized Assets (81.8) (46.7) — (32.6) — (5.3) — 2.8 Regulatory Assets (825.9) (56.2) (0.7) (284.3) (27.7) (50.1) (67.2) (146.9) Accrued Nuclear Decommissioning (923.5) — — — (923.5) — — — Net Operating Loss Carryforward 155.6 — 3.9 0.2 — 2.6 25.3 47.5 Valuation Allowance (37.4) — (0.1) — — — — (1.8) Tax Credit Carryforward 321.4 13.7 — 0.1 7.2 41.0 53.8 68.6 Operating Lease Liability 154.7 17.3 0.4 18.0 14.1 15.4 28.2 33.3 Investment in Partnership (296.3) — — (0.1) — (0.7) — (1.5) All Other, Net 28.4 8.8 32.2 (35.3) (27.6) (17.0) (28.4) (17.8) Net Deferred Tax Liabilities $ (9,415.7) $ (1,227.8) $ (1,147.7) $ (2,011.9) $ (1,169.9) $ (1,152.7) $ (831.2) $ (1,179.3)
Schedule of State Net Income Tax Operating Loss Carryforwards	As of December 31, 2024, AEP, OPCo, PSO, and SWEPCo have pretax state NOLC as indicated in the table below. Net of tax, the NOLCs for AEP and subsidiaries amount to $110.3 million of future tax benefit. Additionally, the amounts presented below for OPCo, PSO, and SWEPCo amount to $2.7 million, $27.8 million, and $36.1 million, respectively.: State Net Income Tax Operating Loss Years of Company State/Municipality Carryforward Expiration (in millions) AEP Arkansas $ 273.9 2031 - 2034 AEP Colorado 70.5 2041 AEP Illinois 53.9 2039 - 2041 AEP Kentucky 186.7 2030 - 2037 AEP Louisiana 644.8 NA AEP Michigan 30.9 2029 - 2032 AEP Ohio Municipal 2,155.8 2025 - 2029 AEP Oklahoma 889.8 2037 AEP Pennsylvania 61.2 2030 - 2044 AEP Tennessee 46.1 2032 - 2039 OPCo Ohio Municipal 93.7 2025 - 2029 PSO Oklahoma 1,010.0 2037 SWEPCo Arkansas 273.5 2031 - 2034 SWEPCo Louisiana 634.5 NA NA Not applicable.
Summary of Tax Credit Carryforwards	As of December 31, 2024, the Registrants have federal tax credit carryforwards and AEP and PSO have state tax credit carryforwards as indicated in the table below. If these credits are not utilized, federal general business tax credits will expire in the years 2036 through 2041 and state tax credits will remain available indefinitely. Total Federal Total State Tax Credit Tax Credit Company Carryforward Carryforward (in millions) AEP $ 197.9 40.2 I&M 37.5 — PSO 26.5 40.2 SWEPCo 31.7 —

LEASES (Tables)

LEASES (Tables)	12 Months Ended
	Dec. 31, 2024
Leases [Abstract]
Schedule of Lease Rental Costs and Supplemental Lease Information	The components of rental costs were as follows: Year Ended December 31, 2024 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Cost $ 145.9 $ 32.3 $ 1.3 $ 18.4 $ 19.6 $ 16.8 $ 13.5 $ 17.8 Finance Lease Cost: Amortization of Right-of-Use Assets 63.7 7.5 — 8.7 7.2 5.3 3.3 13.0 Interest on Lease Liabilities 11.9 1.4 — 1.5 2.2 0.9 0.7 1.6 Total Lease Rental Costs (a) $ 221.5 $ 41.2 $ 1.3 $ 28.6 $ 29.0 $ 23.0 $ 17.5 $ 32.4 Year Ended December 31, 2023 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Cost $ 149.9 $ 34.0 $ 1.3 $ 18.5 $ 19.6 $ 17.3 $ 13.5 $ 17.5 Finance Lease Cost: Amortization of Right-of-Use Assets 69.1 7.4 — 8.3 7.3 5.0 3.3 19.9 Interest on Lease Liabilities 11.9 1.4 — 1.8 2.5 0.9 0.7 1.4 Total Lease Rental Costs (a) $ 230.9 $ 42.8 $ 1.3 $ 28.6 $ 29.4 $ 23.2 $ 17.5 $ 38.8 Year Ended December 31, 2022 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Cost $ 157.5 $ 18.4 $ 1.1 $ 17.9 $ 29.5 $ 16.9 $ 11.8 $ 15.3 Finance Lease Cost: Amortization of Right-of-Use Assets 205.5 6.8 — 7.9 78.7 4.9 3.2 10.8 Interest on Lease Liabilities 13.4 1.3 — 2.0 3.1 0.8 0.6 2.1 Total Lease Rental Costs (a) $ 376.4 $ 26.5 $ 1.1 $ 27.8 $ 111.3 $ 22.6 $ 15.6 $ 28.2 (a) Excludes variable and short-term lease costs, which were immaterial. Supplemental information related to leases are shown in the tables below: December 31, 2024 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo Weighted-Average Remaining Lease Term (years): Operating Leases 12.80 4.45 2.29 5.39 4.43 4.64 23.68 21.97 Finance Leases 4.81 5.04 0.00 4.09 4.83 4.58 5.44 6.14 Weighted-Average Discount Rate: Operating Leases 3.89 % 4.29 % 4.55 % 4.20 % 4.11 % 4.17 % 3.76 % 3.60 % Finance Leases 6.43 % 5.73 % — % 6.69 % 9.07 % 5.59 % 5.48 % 5.73 % December 31, 2023 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo Weighted-Average Remaining Lease Term (years): Operating Leases 12.58 3.99 2.76 6.01 4.53 5.36 23.85 22.50 Finance Leases 4.63 5.13 0.00 4.16 4.95 4.97 5.76 4.78 Weighted-Average Discount Rate: Operating Leases 3.73 % 4.23 % 3.61 % 3.50 % 3.89 % 3.93 % 3.72 % 3.53 % Finance Leases 6.19 % 5.27 % — % 7.04 % 8.62 % 5.32 % 5.14 % 5.22 % Year Ended December 31, 2024 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Cash paid for amounts included in the measurement of lease liabilities: Operating Cash Flows Used for Operating Leases $ 143.9 $ 32.2 $ 1.3 $ 18.4 $ 19.6 $ 16.8 $ 12.5 $ 16.8 Operating Cash Flows Used for Finance Leases 12.0 1.4 — 1.5 2.2 0.9 0.7 1.7 Financing Cash Flows Used for Finance Leases 64.8 7.5 — 8.7 7.1 5.3 3.3 14.0 Non-cash Acquisitions Under Operating Leases $ 82.3 $ 6.0 $ 1.0 $ 9.3 $ 15.0 $ 4.6 $ 2.5 $ 26.9 Year Ended December 31, 2023 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Cash paid for amounts included in the measurement of lease liabilities: Operating Cash Flows Used for Operating Leases $ 146.8 $ 33.6 $ 1.3 $ 18.3 $ 19.5 $ 17.0 $ 12.5 $ 16.5 Operating Cash Flows Used for Finance Leases 11.9 1.4 — 1.8 2.5 0.9 0.7 1.4 Financing Cash Flows Used for Finance Leases 68.3 7.4 — 8.3 7.4 5.0 3.3 19.1 Non-cash Acquisitions Under Operating Leases $ 99.8 $ 12.4 $ 1.2 $ 15.7 $ 7.9 $ 10.2 $ 15.5 $ 14.3
Schedule of Property, Plant, and Equipment Under Finance Leases and Noncurrent Assets Under Operating Leases	The following tables show property, plant and equipment under finance leases and noncurrent assets under operating leases and related obligations recorded on the balance sheets. Unless shown as a separate line on the balance sheets due to materiality, net operating lease assets are included in Deferred Charges and Other Noncurrent Assets, current finance lease obligations are included in Other Current Liabilities Deferred Credits and Other Noncurrent Liabilities balance sheets December 31, 2024 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Property, Plant and Equipment Under Finance Leases: Generation $ 73.8 $ — $ — $ 41.6 $ 16.6 $ — $ 0.6 $ 2.0 Other Property, Plant and Equipment 283.7 52.4 — 19.4 38.8 30.4 23.0 29.8 Total Property, Plant and Equipment 357.5 52.4 — 61.0 55.4 30.4 23.6 31.8 Accumulated Amortization 193.9 27.7 — 42.0 33.4 16.1 11.3 13.3 Net Property, Plant and Equipment Under Finance Leases $ 163.6 $ 24.7 $ — $ 19.0 $ 22.0 $ 14.3 $ 12.3 $ 18.5 Obligations Under Finance Leases: Noncurrent Liability $ 117.1 $ 18.2 $ — $ 11.2 $ 15.9 $ 10.2 $ 9.5 $ 14.8 Liability Due Within One Year 46.5 6.5 — 7.8 6.1 4.1 2.8 3.7 Total Obligations Under Finance Leases $ 163.6 $ 24.7 $ — $ 19.0 $ 22.0 $ 14.3 $ 12.3 $ 18.5 December 31, 2023 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Property, Plant and Equipment Under Finance Leases: Generation $ 120.1 $ — $ — $ 41.0 $ 28.2 $ — $ 0.6 $ 25.3 Other Property, Plant and Equipment 305.9 53.9 — 22.1 42.3 33.7 25.5 32.0 Total Property, Plant and Equipment 426.0 53.9 — 63.1 70.5 33.7 26.1 57.3 Accumulated Amortization 221.5 26.3 — 37.1 39.0 15.5 12.3 28.3 Net Property, Plant and Equipment Under Finance Leases $ 204.5 $ 27.6 $ — $ 26.0 $ 31.5 $ 18.2 $ 13.8 $ 29.0 Obligations Under Finance Leases: Noncurrent Liability $ 139.9 $ 20.6 $ — $ 17.8 $ 20.8 $ 13.2 $ 10.7 $ 18.8 Liability Due Within One Year 65.7 7.0 — 8.2 10.7 5.0 3.1 11.3 Total Obligations Under Finance Leases $ 205.6 $ 27.6 $ — $ 26.0 $ 31.5 $ 18.2 $ 13.8 $ 30.1 December 31, 2024 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Assets $ 580.1 $ 54.4 $ 2.3 $ 67.0 $ 51.5 $ 60.4 $ 106.2 $ 141.0 Obligations Under Operating Leases: Noncurrent Liability $ 504.3 $ 43.4 $ 1.2 $ 54.0 $ 40.1 $ 48.4 $ 101.9 $ 137.5 Liability Due Within One Year 91.9 13.1 1.3 13.7 12.3 12.3 10.4 8.2 Total Obligations Under Operating Leases $ 596.2 $ 56.5 $ 2.5 $ 67.7 $ 52.4 $ 60.7 $ 112.3 $ 145.7 December 31, 2023 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Operating Lease Assets $ 620.2 $ 77.6 $ 2.6 $ 73.7 $ 53.8 $ 69.9 $ 112.8 $ 126.3 Obligations Under Operating Leases: Noncurrent Liability $ 519.4 $ 50.9 $ 1.4 $ 59.8 $ 37.7 $ 56.7 $ 106.8 $ 122.5 Liability Due Within One Year 115.7 28.7 1.3 14.6 16.8 13.5 10.1 9.0 Total Obligations Under Operating Leases $ 635.1 $ 79.6 $ 2.7 $ 74.4 $ 54.5 $ 70.2 $ 116.9 $ 131.5
Schedule of Finance Lease Liabilities Rolling Future Minimum Lease Payments	Future minimum lease payments consisted of the following as of December 31, 2024: Finance Leases AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) 2025 $ 55.6 $ 7.8 $ — $ 8.9 $ 7.7 $ 4.8 $ 3.4 $ 4.7 2026 39.8 6.2 — 4.0 4.9 3.6 2.9 4.0 2027 30.5 4.5 — 2.5 4.1 2.6 2.3 3.3 2028 23.1 3.1 — 2.0 3.4 2.0 1.8 2.7 2029 15.5 2.4 — 1.6 2.8 1.4 1.3 2.4 After 2029 26.4 4.7 — 2.5 4.7 1.9 2.6 5.0 Total Future Minimum Lease Payments 190.9 28.7 — 21.5 27.6 16.3 14.3 22.1 Less: Imputed Interest 27.3 4.0 — 2.5 5.6 2.0 2.0 3.6 Estimated Present Value of Future Minimum Lease Payments $ 163.6 $ 24.7 $ — $ 19.0 $ 22.0 $ 14.3 $ 12.3 $ 18.5 Operating Leases AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) 2025 $ 123.0 $ 16.7 $ 1.3 $ 17.3 $ 15.9 $ 16.3 $ 11.6 $ 17.6 2026 107.8 14.5 0.7 15.3 15.0 15.1 10.8 15.5 2027 94.0 11.9 0.3 13.6 11.0 13.5 9.8 14.1 2028 78.5 8.9 0.3 11.4 9.0 11.3 8.4 12.1 2029 52.3 4.9 — 8.2 4.4 6.6 6.5 9.0 After 2029 340.0 6.5 — 10.2 2.4 4.9 123.7 178.1 Total Future Minimum Lease Payments 795.6 63.4 2.6 76.0 57.7 67.7 170.8 246.4 Less: Imputed Interest 199.4 6.9 0.1 8.3 5.3 7.0 58.5 100.7 Estimated Present Value of Future Minimum Lease Payments $ 596.2 $ 56.5 $ 2.5 $ 67.7 $ 52.4 $ 60.7 $ 112.3 $ 145.7
Schedule of Operating Lease Liabilities Rolling Future Minimum Lease Payments	Future minimum lease payments consisted of the following as of December 31, 2024: Finance Leases AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) 2025 $ 55.6 $ 7.8 $ — $ 8.9 $ 7.7 $ 4.8 $ 3.4 $ 4.7 2026 39.8 6.2 — 4.0 4.9 3.6 2.9 4.0 2027 30.5 4.5 — 2.5 4.1 2.6 2.3 3.3 2028 23.1 3.1 — 2.0 3.4 2.0 1.8 2.7 2029 15.5 2.4 — 1.6 2.8 1.4 1.3 2.4 After 2029 26.4 4.7 — 2.5 4.7 1.9 2.6 5.0 Total Future Minimum Lease Payments 190.9 28.7 — 21.5 27.6 16.3 14.3 22.1 Less: Imputed Interest 27.3 4.0 — 2.5 5.6 2.0 2.0 3.6 Estimated Present Value of Future Minimum Lease Payments $ 163.6 $ 24.7 $ — $ 19.0 $ 22.0 $ 14.3 $ 12.3 $ 18.5 Operating Leases AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) 2025 $ 123.0 $ 16.7 $ 1.3 $ 17.3 $ 15.9 $ 16.3 $ 11.6 $ 17.6 2026 107.8 14.5 0.7 15.3 15.0 15.1 10.8 15.5 2027 94.0 11.9 0.3 13.6 11.0 13.5 9.8 14.1 2028 78.5 8.9 0.3 11.4 9.0 11.3 8.4 12.1 2029 52.3 4.9 — 8.2 4.4 6.6 6.5 9.0 After 2029 340.0 6.5 — 10.2 2.4 4.9 123.7 178.1 Total Future Minimum Lease Payments 795.6 63.4 2.6 76.0 57.7 67.7 170.8 246.4 Less: Imputed Interest 199.4 6.9 0.1 8.3 5.3 7.0 58.5 100.7 Estimated Present Value of Future Minimum Lease Payments $ 596.2 $ 56.5 $ 2.5 $ 67.7 $ 52.4 $ 60.7 $ 112.3 $ 145.7
Schedule of Maximum Potential Loss	As of December 31, 2024, the maximum potential loss by the Registrants for these lease agreements assuming the fair value of the equipment is zero at the end of the lease term was as follows: Company Maximum (in millions) AEP $ 41.3 AEP Texas 9.4 APCo 5.4 I&M 3.9 OPCo 6.8 PSO 3.9 SWEPCo 4.7

VOLUNTARY SEVERANCE PROGRAM (Ta

VOLUNTARY SEVERANCE PROGRAM (Tables)	12 Months Ended
	Dec. 31, 2024
Restructuring and Related Activities [Abstract]
Schedule of Voluntary Severance Program Expenses	AEP recorded a charge to expense in the second quarter of 2024 related to this voluntary severance program. AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Severance Expense Incurred $ 122.0 $ 19.8 $ 10.7 $ 26.5 $ 14.8 $ 14.8 $ 10.1 $ 16.9 Settled 117.6 19.8 10.7 26.3 14.6 14.6 10.1 16.3 Remaining Balance as of December 31, 2024 $ 4.4 $ — $ — $ 0.2 $ 0.2 $ 0.2 $ — $ 0.6

FINANCING ACTIVITIES (Tables)

FINANCING ACTIVITIES (Tables)	12 Months Ended
	Dec. 31, 2024
Debt Disclosure [Abstract]
Reconciliation of Common Stock Share Activity	The following table is a reconciliation of common stock share activity: Shares of AEP Common Stock Issued Held in Treasury Balance, December 31, 2021 524,416,175 20,204,160 Issued 683,146 — Treasury Stock Reissued — (8,970,920) (a) Balance, December 31, 2022 525,099,321 11,233,240 Issued 2,269,836 — Treasury Stock Reissued — (10,048,668) (a) Balance, December 31, 2023 527,369,157 1,184,572 Issued 6,725,373 — Treasury Stock Reacquired — 2,243 Balance, December 31, 2024 534,094,530 1,186,815 (a)
Schedule of Long-term Debt	The following table details long-term debt outstanding: Weighted-Average Interest Rate Ranges as of Outstanding as of Interest Rate as of December 31, December 31, Company Maturity December 31, 2024 2024 2023 2024 2023 AEP (in millions) Senior Unsecured Notes 2025-2054 4.32% 1.00%-8.13% 1.00%-8.13% $ 36,410.9 $ 33,779.4 Pollution Control Bonds (a) 2025-2036 (b) 3.26% 0.63%-4.70% 0.63%-4.90% 1,771.3 1,771.6 Notes Payable – Nonaffiliated (c) 2025-2034 6.49% 0.93%-6.89% 0.93%-6.59% 609.9 193.3 Securitization Bonds 2025-2039 (d) 4.08% 2.06%-4.88% 2.06%-3.77% 578.0 368.9 Spent Nuclear Fuel Obligation (e) 316.3 300.4 Junior Subordinated Notes 2025-2054 5.67% 3.88%-7.05% 2.03%-5.70% 2,579.1 2,388.1 Other Long-term Debt 2025-2059 5.60% 3.00%-13.72% 3.00%-13.72% 377.3 1,341.5 Total Long-term Debt Outstanding $ 42,642.8 $ 40,143.2 AEP Texas Senior Unsecured Notes 2025-2052 4.39% 2.10%-6.76% 2.10%-6.76% $ 5,873.8 $ 5,027.2 Pollution Control Bonds (a) 2029-2030 (b) 3.88% 2.60%-4.55% 2.60%-4.55% 440.3 440.3 Securitization Bonds 2025-2029 (d) 2.27% 2.06%-2.29% 2.06%-2.84% 126.8 221.8 Other Long-term Debt 2059 4.50% 4.50% 4.50%-6.71% 0.7 200.5 Total Long-term Debt Outstanding $ 6,441.6 $ 5,889.8 AEPTCo Senior Unsecured Notes 2025-2053 4.12% 2.75%-5.52% 2.75%-5.52% $ 5,768.1 $ 5,414.4 Total Long-term Debt Outstanding $ 5,768.1 $ 5,414.4 APCo Senior Unsecured Notes 2025-2050 4.75% 2.70%-7.00% 2.70%-7.00% $ 4,984.1 $ 4,584.9 Pollution Control Bonds (a) 2025-2036 (b) 2.95% 0.63%-4.22% 0.63%-4.90% 429.9 430.0 Securitization Bonds 2028 (d) 3.77% 3.77% 3.77% 119.8 147.0 Other Long-term Debt 2025-2026 5.84% 5.75%-13.72% 6.46%-13.72% 126.5 426.4 Total Long-term Debt Outstanding $ 5,660.3 $ 5,588.3 I&M Senior Unsecured Notes 2028-2053 4.52% 3.25%-6.05% 3.25%-6.05% $ 2,845.2 $ 2,843.6 Pollution Control Bonds (a) 2025 (b) 2.49% 0.75%-3.05% 0.75%-3.05% 189.9 189.4 Notes Payable – Nonaffiliated (c) 2025-2028 5.78% 0.93%-6.41% 0.93%-6.59% 142.7 163.3 Spent Nuclear Fuel Obligation (e) 316.3 300.4 Other Long-term Debt 2025 6.00% 6.00% 6.00% 0.2 2.7 Total Long-term Debt Outstanding $ 3,494.3 $ 3,499.4 OPCo Senior Unsecured Notes 2030-2051 4.16% 1.63%-6.60% 1.63%-6.60% $ 3,715.7 $ 3,366.8 Total Long-term Debt Outstanding $ 3,715.7 $ 3,366.8 PSO Senior Unsecured Notes 2025-2051 4.29% 2.20%-6.63% 2.20%-6.63% $ 2,854.2 $ 2,257.8 Other Long-term Debt 2027 3.00% 3.00% 3.00%-6.71% 1.4 126.8 Total Long-term Debt Outstanding $ 2,855.6 $ 2,384.6 SWEPCo Senior Unsecured Notes 2026-2051 3.73% 1.65%-6.20% 1.65%-6.20% $ 3,649.4 $ 3,646.9 Securitization Bonds 2039 (d) 4.88% 4.88% —% 331.4 — Total Long-term Debt Outstanding $ 3,980.8 $ 3,646.9 (a) For certain series of Pollution Control Bonds, interest rates are subject to periodic adjustment. Certain series may be purchased on demand at periodic interest adjustment dates. Letters of credit from banks and insurance policies support certain series. Consequently, these bonds have been classified for maturity purposes as Long-term Debt Due Within One Year - Nonaffiliated on the balance sheets. (b) Certain Pollution Control Bonds are subject to redemption earlier than the maturity date. (c) Notes payable represent outstanding promissory notes issued under term loan agreements and credit agreements with a number of banks and other financial institutions. At expiration, all notes then issued and outstanding are due and payable. Interest rates are both fixed and variable. Variable rates generally relate to specified short-term interest rates. (d) Dates represent the scheduled final payment dates for the securitization bonds. The legal maturity date is one to two years later. These bonds have been classified for maturity and repayment purposes based on the scheduled final payment date. (e) Spent Nuclear Fuel Obligation consists of a liability along with accrued interest for disposal of SNF. See “Spent Nuclear Fuel Disposal” section of Note 6 for additional information. The following details long-term debt outstanding as of December 31, 2024 and 2023: Long-term Debt Weighted-Average Interest Rate Ranges as of Outstanding as of Interest Rate as of December 31, December 31, Type of Debt Maturity December 31, 2024 2024 2023 2024 2023 (in millions) Senior Unsecured Notes 2025-2050 4.29% 1.00%-5.95% 1.00%-5.95% $ 5,290.0 $ 5,265.0 Pollution Control Bonds 2026-2029 (a) 3.12% 2.40%-3.75% 1.90%-2.60% 536.8 537.8 Junior Subordinated Notes 2025-2027 5.67% 3.88%-7.05% 2.03%-5.70% 2,579.0 2,388.1 Total Long-term Debt Outstanding 8,405.8 8,190.9 Long-term Debt Due Within One Year 1,281.5 1,104.0 Long-term Debt $ 7,124.3 $ 7,086.9 (a) Certain Pollution Control Bonds are subject to redemption earlier than the maturity date. Long-term debt outstanding as of December 31, 2024 is payable as follows: 2025 2026 2027 2028 2029 After 2029 Total (in millions) Principal Amount (a) $ 1,281.5 $ 50.0 $ 1,758.3 $ 930.4 $ 1,694.5 $ 2,750.0 $ 8,464.7 Unamortized Discount, Net and Debt Issuance Costs (58.9) Total Long-term Debt Outstanding $ 8,405.8 (a) Amounts reflect the impact of fair value hedge accounting. See “Accounting for Fair Value Hedging Strategies” section of Note 10 included in the 2024 Annual Report for additional information.
Schedule of Maturities of Long-term Debt	As of December 31, 2024, outstanding long-term debt was payable as follows: AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) 2025 $ 3,335.0 $ 324.5 $ 90.0 $ 798.6 $ 269.2 $ — $ 125.6 $ 22.7 2026 1,864.4 75.0 425.0 30.9 43.6 — 50.6 916.6 2027 2,283.6 25.6 — 355.6 13.7 — 0.3 17.4 2028 2,592.0 526.2 60.0 117.8 356.5 — — 593.3 2029 2,694.0 627.4 55.0 — — — 100.0 19.2 After 2029 30,212.8 4,912.8 5,201.0 4,400.0 2,841.3 3,750.0 2,600.0 2,442.4 Principal Amount 42,981.8 6,491.5 5,831.0 5,702.9 3,524.3 3,750.0 2,876.5 4,011.6 Unamortized Discount, Net and Debt Issuance Costs (339.0) (49.9) (62.9) (42.6) (30.0) (34.3) (20.9) (30.8) Total Long-term Debt Outstanding $ 42,642.8 $ 6,441.6 $ 5,768.1 $ 5,660.3 $ 3,494.3 $ 3,715.7 $ 2,855.6 $ 3,980.8
Schedule of Dividend Repayment Restrictions	As of December 31, 2024, the amount of any such restrictions were as follows: AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Restricted Retained Earnings $ 3,247.9 (a) $ 1,109.2 $ — $ 539.2 $ 707.0 $ — $ 267.7 $ 366.5 (a) Includes the restrictions of consolidated and non-consolidated subsidiaries.
Schedule of Short-term Debt	AEP’s outstanding short-term debt was as follows: December 31, 2024 2023 Company Type of Debt Outstanding Interest Outstanding Interest (in millions) (in millions) AEP Securitized Debt for Receivables (b) $ 900.0 4.73 % $ 888.0 5.65 % AEP Commercial Paper 1,618.3 4.70 % 1,937.9 5.69 % SWEPCo Notes Payable 5.5 6.69 % 4.3 7.71 % Total Short-term Debt $ 2,523.8 $ 2,830.2 (a) Weighted-average rate of all borrowings outstanding as of December 31, 2024 and 2023, respectively. (b) Amount of securitized debt for receivables as accounted for under the “Transfers and Servicing” accounting guidance . Parent’s outstanding short-term debt was as follows: December 31, 2024 December 31, 2023 Type of Debt Outstanding Weighted-Average Outstanding Weighted-Average (in millions) (in millions) Commercial Paper $ 1,618.3 4.70 % $ 1,937.9 5.69 % Total Short-term Debt $ 1,618.3 $ 1,937.9
Schedule of Utility Money Pool Participants' Money Pool Activity and Authorized Borrowing Limits	The Utility Money Pool participants’ money pool activity and corresponding authorized borrowing limits are described in the following tables: Year Ended December 31, 2024: Maximum Average Net Loans to Borrowings Maximum Borrowings Average (Borrowings from) Authorized from the Loans to the from the Loans to the the Utility Money Short-term Utility Utility Utility Utility Pool as of Borrowing Company Money Pool Money Pool Money Pool Money Pool December 31, 2024 Limit (in millions) AEP Texas $ 374.6 $ 274.3 $ 233.8 $ 165.1 $ (284.9) $ 600.0 AEPTCo 313.3 332.0 71.8 138.4 (72.9) 820.0 (a) APCo 399.5 132.3 102.6 29.7 (77.3) 750.0 I&M 135.8 8.4 58.8 3.9 (126.8) 500.0 OPCo 310.0 183.4 180.5 94.2 114.9 600.0 PSO 308.9 314.5 171.4 287.7 232.0 750.0 SWEPCo 362.2 59.3 249.5 57.3 (275.0) 750.0 Year Ended December 31, 2023: Maximum Average Net Loans to Borrowings Maximum Borrowings Average (Borrowings from) Authorized from the Loans to the from the Loans to the the Utility Money Short-term Utility Utility Utility Utility Pool as of Borrowing Company Money Pool Money Pool Money Pool Money Pool December 31, 2023 Limit (in millions) AEP Texas $ 477.5 $ 42.0 $ 216.8 $ 12.9 $ (103.7) $ 600.0 AEPTCo 471.3 309.4 135.6 70.5 (62.8) 820.0 (a) APCo 388.6 19.8 283.5 19.0 (320.7) 750.0 I&M 475.3 112.2 84.0 44.2 (63.3) 500.0 OPCo 485.7 64.7 183.0 40.2 (110.5) 500.0 PSO 375.0 121.5 92.5 49.6 (54.4) 750.0 SWEPCo 401.6 25.8 150.7 16.5 (88.7) 750.0 (a) Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions.
Schedule of Nonutility Money Pool Activity	The Nonutility Money Pool participants’ money pool activity is described in the following tables: Year Ended December 31, 2024: Maximum Loans Average Loans Loans to the Nonutility to the Nonutility to the Nonutility Money Pool as of Company Money Pool Money Pool December 31, 2024 (in millions) AEP Texas $ 7.2 $ 7.1 $ 7.2 SWEPCo 2.9 2.6 2.3 Year Ended December 31, 2023: Maximum Loans Average Loans Loans to the Nonutility to the Nonutility to the Nonutility Money Pool as of Company Money Pool Money Pool December 31, 2023 (in millions) AEP Texas $ 7.1 $ 6.9 $ 7.1 SWEPCo 2.8 2.4 2.2
Schedule of Direct Borrowing Activity	AEPTCo’s direct financing activities with AEP and corresponding authorized borrowing limits are described in the following tables: Year Ended December 31, 2024: Borrowings Authorized Maximum Maximum Average Average from AEP Loans to Short-term Borrowings Loans Borrowings Loans as of AEP as of Borrowing Company from AEP to AEP from AEP to AEP December 31, 2024 December 31, 2024 Limit (a) (in millions) AEPTCo Parent $ 49.4 $ 148.5 $ 14.9 $ 57.0 $ — $ 20.4 $ — SWTCo 1.9 — 1.8 — 1.8 — 50.0 Year Ended December 31, 2023: Borrowings Authorized Maximum Maximum Average Average from AEP Loans to Short-term Borrowings Loans Borrowings Loans as of AEP as of Borrowing Company from AEP to AEP from AEP to AEP December 31, 2023 December 31, 2023 Limit (a) (in millions) AEPTCo Parent $ 42.7 $ 158.1 $ 18.0 $ 64.2 $ 42.7 $ — $ — SWTCo 1.6 — 1.6 — 1.7 — 50.0 (a) Amount represents the authorized short-term borrowing limit from FERC or state regulatory agencies not otherwise included in the utility money pool above. AEPTCo Parent has no short-term borrowing limit.
Schedule of Maximum and Minimum Interest Rates for Funds Either Borrowed from or Loaned to Utility Money Pool	The maximum and minimum interest rates for funds either borrowed from or loaned to the Utility Money Pool are summarized in the following table: Years Ended December 31, 2024 2023 2022 Maximum Interest Rate 5.79 % 5.81 % 5.28 % Minimum Interest Rate 4.74 % 4.66 % 0.10 %
Schedule of Average Interest Rates for Funds Borrowed from and Loaned to Utility Money Pool	The average interest rates for funds borrowed from and loaned to the Utility Money Pool are summarized in the following table: Average Interest Rate for Funds Borrowed Average Interest Rate for Funds Loaned Company 2024 2023 2022 2024 2023 2022 AEP Texas 5.48 % 5.46 % 1.08 % 5.45 % 5.71 % 1.99 % AEPTCo 5.51 % 5.41 % 1.81 % 5.50 % 5.56 % 2.47 % APCo 5.51 % 5.54 % 2.34 % 5.41 % 5.54 % 2.39 % I&M 5.40 % 5.14 % 2.57 % 5.44 % 5.57 % 2.20 % OPCo 5.70 % 5.43 % 3.51 % 5.20 % 5.60 % 1.22 % PSO 5.50 % 5.51 % 2.65 % 4.79 % 5.35 % 0.75 % SWEPCo 5.41 % 5.34 % 2.80 % 4.78 % 5.72 % 0.55 %
Schedule of Maximum, Minimum and Average Interest Rates for Funds Borrowed from and Loaned to the Nonutility Money Pool	Maximum, minimum and average interest rates for funds loaned to the Nonutility Money Pool are summarized in the following table: Maximum Interest Rate Minimum Interest Rate Average Interest Rate Year Ended for Funds Loaned to for Funds Loaned to for Funds Loaned to December 31, Company the Nonutility Money Pool the Nonutility Money Pool the Nonutility Money Pool 2024 AEP Texas 5.79 % 4.74 % 5.46 % 2024 SWEPCo 5.79 % 4.74 % 5.45 % 2023 AEP Texas 5.81 % 4.66 % 5.54 % 2023 SWEPCo 5.81 % 4.66 % 5.56 % 2022 AEP Texas 5.28 % 0.46 % 2.23 % 2022 SWEPCo 5.28 % 0.46 % 2.23 %
Schedule of Maximum Minimum and Average Interest Rates for Funds Borrowed from and Loaned to AEP	AEPTCo Parent’s and SWTCo’s maximum, minimum and average interest rates for funds either borrowed from or loaned to AEP are summarized in the following table: Maximum Minimum Maximum Minimum Average Average Interest Rate Interest Rate Interest Rate Interest Rate Interest Rate Interest Rate for Funds for Funds for Funds for Funds for Funds for Funds Year Ended Borrowed from Borrowed from Loaned to Loaned to Borrowed from Loaned to December 31, AEP AEP AEP AEP AEP AEP 2024 5.79 % 4.66 % 5.79 % 4.66 % 5.53 % 5.56 % 2023 5.81 % 4.53 % 5.81 % 4.53 % 5.56 % 5.51 % 2022 5.28 % 0.46 % 5.28 % 0.46 % 2.08 % 2.07 %
Schedule of Interest Expense Incurred For Funds Borrowed from Utility Money Pool	The Registrant Subsidiaries incurred interest expense for all short-term borrowing activities as follows: Years Ended December 31, Company 2024 2023 2022 (in millions) AEP Texas $ 6.7 $ 10.8 $ 0.9 AEPTCo 4.3 7.6 3.5 APCo 6.1 16.8 5.6 I&M 4.3 3.2 2.9 OPCo 3.7 9.7 2.3 PSO 8.9 2.3 5.5 SWEPCo 13.6 7.9 4.9
Schedule of Interest Income Earned for Funds Loaned to Utility Money Pool	The Registrant Subsidiaries earned interest income for all short-term lending activities as follows: Years Ended December 31, Company 2024 2023 2022 (in millions) AEP Texas $ 4.4 $ 0.1 $ 2.6 AEPTCo 10.5 7.0 1.6 APCo 1.6 1.1 2.8 I&M — 2.4 0.5 OPCo 3.2 0.1 0.4 PSO 1.0 1.5 0.3 SWEPCo 0.2 0.2 0.2
Schedule of Comparative Accounts Receivable Information	Accounts receivable information for AEP Credit was as follows: Years Ended December 31, 2024 2023 2022 (dollars in millions) Effective Interest Rates on Securitization of Accounts Receivable 5.39 % 5.33 % 1.84 % Net Uncollectible Accounts Receivable Written Off $ 29.4 $ 30.7 $ 29.5
Schedule of Customer Accounts Receivable Managed Portfolio	December 31, 2024 2023 (in millions) Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts $ 1,117.0 $ 1,207.4 Short-term – Securitized Debt of Receivables 900.0 888.0 Delinquent Securitized Accounts Receivable 56.2 52.2 Bad Debt Reserves Related to Securitization 44.5 42.0 Unbilled Receivables Related to Securitization 335.5 409.8
Schedule of Accounts Receivable and Accrued Unbilled Revenues	The amount of accounts receivable and accrued unbilled revenues under the sale of receivables agreement were: December 31, Company 2024 2023 (in millions) APCo $ 192.7 $ 184.6 I&M 160.5 156.4 OPCo 470.7 541.7 PSO 111.4 134.6 SWEPCo 153.5 168.3
Schedule of Fees Paid to AEP Credit for Customer Accounts Receivable Sold	The fees paid to AEP Credit for customer accounts receivable sold were: Years Ended December 31, Company 2024 2023 2022 (in millions) APCo $ 15.5 $ 16.9 $ 9.4 I&M 15.4 16.3 9.7 OPCo 29.7 29.5 29.8 PSO 14.2 15.3 7.4 SWEPCo 17.6 18.5 9.4
Schedule of Proceeds on Sale of Receivables to AEP Credit	The proceeds on the sale of receivables to AEP Credit were: Years Ended December 31, Company 2024 2023 2022 (in millions) APCo $ 1,953.7 $ 1,819.8 $ 1,552.9 I&M 2,105.3 2,054.8 2,045.6 OPCo 3,197.8 3,339.3 3,101.3 PSO 1,781.3 1,944.5 1,809.5 SWEPCo 1,838.1 1,866.4 1,858.4

STOCK-BASED COMPENSATION (Table

STOCK-BASED COMPENSATION (Tables)	12 Months Ended
	Dec. 31, 2024
Share-Based Payment Arrangement, Noncash Expense [Abstract]
Share-Based Payment Arrangement, Activity	The HR Committee awarded performance shares and reinvested dividends on outstanding performance shares and AEP career shares as follows: Years Ended December 31, Performance Shares 2024 2023 2022 Awarded Shares (in thousands) 440.7 486.7 530.3 Weighted-Average Share Fair Value at Grant Date $ 99.76 $ 98.63 $ 97.61 Vesting Period (in years) 3 3 3 Performance Shares and AEP Career Shares Years Ended December 31, 2024 2023 2022 Awarded Shares (in thousands) 66.0 81.3 63.3 Weighted-Average Fair Value at Grant Date $ 91.75 $ 82.02 $ 98.73 Vesting Period (in years) (a) (a) (a) (a) The vesting period for the reinvested dividends on performance shares is equal to the remaining life of the related performance shares. Dividends on AEP career shares vest immediately when the dividend is awarded but are not settled in AEP common stock until after the participant’s AEP employment ends. The performance scores and shares earned for the three-year periods were as follows: Years Ended December 31, Performance Shares 2024 (b) 2023 2022 Performance Score 109.8 % 106.1 % 131.1 % Performance Shares Earned 477,487 540,863 512,660 Performance Shares Mandatorily Deferred as AEP Career Shares 39,172 70,377 28,282 Performance Shares Voluntarily Deferred into the Incentive Compensation Deferral Program 21,245 22,716 23,609 Performance Shares to be Settled (a) 417,070 447,770 460,769 (a) Performance shares settled in AEP common stock in the quarter following the end of the year shown. (b) Performance shares earned, deferred and settled were calculated based on the estimated performance score. The settlements were as follows: Years Ended December 31, Performance Shares and AEP Career Shares 2024 2023 2022 (in millions) AEP Common Stock Settlements for Performance Shares $ 38.1 $ 41.8 $ 43.2 AEP Common Stock Settlements for Career Share Distributions 8.4 8.3 5.1 The HR Committee awarded RSUs, including additional units awarded as dividends, as follows: Years Ended December 31, Restricted Stock Units 2024 2023 2022 Awarded Units (in thousands) 417.0 268.4 290.4 Weighted-Average Grant Date Fair Value $ 87.85 $ 88.52 $ 90.48 The total fair value and total intrinsic value of restricted stock units vested were as follows: Years Ended December 31, Restricted Stock Units 2024 2023 2022 (in millions) Fair Value of Restricted Stock Units Vested $ 25.9 $ 18.8 $ 17.8 Intrinsic Value of Restricted Stock Units Vested (a) 27.3 19.0 20.3 (a) Intrinsic value is calculated as market price at the vesting date. The Board of Directors awarded stock units, including units awarded for dividends, as follows: Years Ended December 31, Stock Unit Accumulation Plan for Non-Employee Directors 2024 2023 2022 Awarded Units (in thousands) 18.9 19.8 14.5 Weighted-Average Grant Date Fair Value $ 91.42 $ 82.14 $ 95.16
Share-Based Payment Arrangement, Outstanding Award, Activity, Excluding Option	A summary of the status of AEP’s nonvested Performance Shares as of December 31, 2024 and changes during the year ended December 31, 2024 were as follows: Nonvested Performance Shares Shares Weighted Average (in thousands) Nonvested as of January 1, 2024 889.9 $ 99.49 Awarded 440.7 99.76 Dividends 49.4 91.82 Vested (a) (440.6) 100.52 Forfeited (161.8) 87.94 Nonvested as of December 31, 2024 777.6 100.97 (a) The vested Performance Shares will be converted to an estimated 417 thousand shares based on the closing share price on the day before settlement.
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Valuation Assumptions	The assumptions used in the Monte Carlo valuations were as follows: Years Ended December 31, Assumptions 2024 2023 2022 Valuation Period (in years) (a) 2.85 2.87 2.86 Expected Volatility Minimum 18.79 % 21.23 % 25.92 % Expected Volatility Maximum 33.29 % 39.00 % 40.82 % Expected Volatility Average 22.34 % 25.35 % 31.09 % Dividend Rate (b) — % — % — % Risk Free Rate 4.43 % 4.32 % 1.64 % (a) Period from award date to vesting date. (b) Equivalent to reinvesting dividends.
Share-Based Payment Arrangement, Restricted Stock Unit, Activity	A summary of the status of AEP’s nonvested RSUs as of December 31, 2024 and changes during the year ended December 31, 2024 were as follows: Nonvested Restricted Stock Units Shares/Units Weighted Average (in thousands) Nonvested as of January 1, 2024 431.1 $ 88.57 Awarded 417.0 87.85 Vested (296.8) 87.26 Forfeited (74.0) 89.97 Nonvested as of December 31, 2024 477.3 88.37
Share-Based Payment Arrangement, Cost by Plan	The compensation cost for share-based payment arrangements, the actual tax benefit from the tax deductions for compensation cost recognized in income and the total compensation cost capitalized were as follows: Years Ended December 31, Share-based Compensation Plans 2024 2023 2022 (in millions) Compensation Cost for Share-based Payment Arrangements (a) $ 52.9 $ 50.9 $ 63.3 Actual Tax Benefit 7.4 6.4 8.0 Total Compensation Cost Capitalized 13.9 15.3 16.0 (a) Compensation cost for share-based payment arrangements is included in Other Operation and Maintenance expenses on the statements of income.

RELATED PARTY TRANSACTIONS (Tab

RELATED PARTY TRANSACTIONS (Tables)	12 Months Ended
	Dec. 31, 2024
Related Party Transactions [Abstract]
Schedule of Related Party Transactions	Charitable contributions were recorded in Other Operation expenses on the statements of income as follows for the year ended December 31, 2022: AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Contributions to AEP Foundation $ 75.0 $ 9.9 $ 11.1 $ 12.5 $ 11.0 $ 8.1 $ 5.8 $ 8.8 Years Ended December 31, Company 2024 2023 2022 (in millions) AEGCo $ 10.0 $ 9.3 $ 11.3 APCo 47.0 39.2 36.1 KPCo — — 2.0 WPCo 7.5 10.6 4.7 Years Ended December 31, Company 2023 2022 (in millions) I&M $ 8.0 $ 11.8 OPCo 16.1 23.6 SWEPCo — 13.7 The following table shows the net transmission service charges recorded by the Registrant Subsidiaries: Years Ended December 31, Company 2024 2023 2022 (in millions) AEP Texas $ 30.6 $ 28.7 $ 28.5 APCo 380.7 365.1 345.1 I&M 252.7 226.2 220.8 OPCo 696.1 665.3 608.2 PSO 127.1 100.1 110.8 SWEPCo 64.5 49.2 62.1
Affiliated Revenues	The tables below represent revenues from affiliates, net of respective provisions for refund, by type of revenue for the Registrant Subsidiaries. Related party revenues are shown in Sales to AEP Affiliates, Provision for Refund - Affiliated and Other Revenues - Affiliated, respectively, on the Registrant Subsidiaries’ statements of income. Related Party Revenues AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Year Ended December 31, 2024 Direct Sales to East Affiliates $ — $ — $ 159.0 $ — $ — $ — $ — Transmission Revenues — 1,491.1 78.8 (8.8) (6.9) 0.1 60.6 Other Revenues 5.4 21.2 9.6 75.0 29.6 6.8 1.5 Total Affiliated Revenues $ 5.4 $ 1,512.3 $ 247.4 $ 66.2 $ 22.7 $ 6.9 $ 62.1 Related Party Revenues AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Year Ended December 31, 2023 Direct Sales to East Affiliates $ — $ — $ 158.7 $ — $ — $ — $ — Transmission Revenues — 1,304.0 70.9 (11.1) 3.2 — 45.3 Barging, Urea Transloading and Other Transportation Services — — — 59.0 — — — Other Revenues 4.9 13.8 9.7 9.9 27.9 1.2 1.5 Total Affiliated Revenues $ 4.9 $ 1,317.8 $ 239.3 $ 57.8 $ 31.1 $ 1.2 $ 46.8 Related Party Revenues AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Year Ended December 31, 2022 Direct Sales to East Affiliates $ — $ — $ 169.7 $ — $ — $ — $ — Direct Sales to West Affiliates — — — — — — 1.3 Transmission Revenues — 1,276.4 77.5 7.7 (3.6) — 51.5 Barging, Urea Transloading and Other Transportation Services — — — 54.1 — — — Other Revenues 3.5 7.4 8.9 7.8 22.4 2.9 1.1 Total Affiliated Revenues $ 3.5 $ 1,283.8 $ 256.1 $ 69.6 $ 18.8 $ 2.9 $ 53.9

VARIABLE INTEREST ENTITIES AN_2

VARIABLE INTEREST ENTITIES AND EQUITY METHOD INVESTMENTS (Tables)	12 Months Ended
	Dec. 31, 2024
Variable Interest Entities [Abstract]
Consolidated Assets And Liabilities Of Variable Interest Entities	The balances below represent the assets and liabilities of AEP’s consolidated VIEs. These balances include intercompany transactions that are eliminated upon consolidation. December 31, 2024 Consolidated VIEs SWEPCo I&M AEP Texas Restoration Funding APCo SWEPCo Storm Recovery Funding AEP Credit Protected Transource Energy (in millions) ASSETS Current Assets $ 6.0 $ 79.3 $ 21.3 $ 14.2 $ 3.4 $ 1,118.3 $ 218.5 $ 40.2 Net Property, Plant and Equipment — 132.3 — — — — — 598.3 Other Noncurrent Assets 110.8 63.6 121.9 (a) 109.6 (b) 331.4 10.5 — 3.5 Total Assets $ 116.8 $ 275.2 $ 143.2 $ 123.8 $ 334.8 $ 1,128.8 $ 218.5 $ 642.0 LIABILITIES AND EQUITY Current Liabilities $ 20.1 $ 79.2 $ 30.7 $ 30.5 $ 24.4 $ 1,068.8 $ 54.7 $ 57.2 Noncurrent Liabilities 96.3 196.0 111.2 91.4 308.7 1.0 96.0 274.3 Equity 0.4 — 1.3 1.9 1.7 59.0 67.8 310.5 Total Liabilities and Equity $ 116.8 $ 275.2 $ 143.2 $ 123.8 $ 334.8 $ 1,128.8 $ 218.5 $ 642.0 (a) Includes an intercompany item eliminated in consolidation of $5 million . (b) Includes an intercompany item eliminated in consolidation of $1 million . December 31, 2023 Consolidated VIEs SWEPCo I&M AEP Texas Transition Funding AEP Texas Restoration Funding APCo AEP Credit Protected Cell of EIS Transource Energy (in millions) ASSETS Current Assets $ 4.2 $ 81.9 $ 25.5 $ 27.5 $ 13.3 $ 1,208.8 $ 205.3 $ 36.9 Net Property, Plant and Equipment — 153.8 — — — — — 533.4 Other Noncurrent Assets 150.7 81.7 71.4 (a) 145.6 (b) 138.2 (c) 9.6 — 5.1 Total Assets $ 154.9 $ 317.4 $ 96.9 $ 173.1 $ 151.5 $ 1,218.4 $ 205.3 $ 575.4 LIABILITIES AND EQUITY Current Liabilities $ 19.9 $ 81.7 $ 75.5 $ 36.8 $ 29.9 $ 1,155.0 $ 49.2 $ 45.3 Noncurrent Liabilities 134.8 235.7 17.0 135.1 119.7 0.9 91.7 241.5 Equity 0.2 — 4.4 1.2 1.9 62.5 64.4 288.6 Total Liabilities and Equity $ 154.9 $ 317.4 $ 96.9 $ 173.1 $ 151.5 $ 1,218.4 $ 205.3 $ 575.4 (a) Includes an intercompany item eliminated in consolidation of $8 million. (b) Includes an intercompany item eliminated in consolidation of $6 million. (c) Includes an intercompany item eliminated in consolidation of $2 million.
Billings from Significant Variable Interest	Total AEPSC billings to the Registrant Subsidiaries were as follows: Years Ended December 31, Company 2024 2023 2022 (in millions) AEP Texas $ 242.6 $ 228.5 $ 236.8 AEPTCo 289.7 269.9 286.6 APCo 335.3 324.9 347.5 I&M 187.6 178.4 192.4 OPCo 283.4 269.5 272.5 PSO 157.4 138.6 142.3 SWEPCo 194.4 185.1 192.5
Carrying Amount and Classification of Variable Interest in Accounts Payable	The carrying amount and classification of variable interest in AEPSC’s accounts payable were as follows: December 31, 2024 2023 Company As Reported on Maximum As Reported on Maximum (in millions) AEP Texas $ 26.1 $ 26.1 $ 15.1 $ 15.1 AEPTCo 29.3 29.3 17.9 17.9 APCo 36.4 36.4 21.1 21.1 I&M 25.1 25.1 14.3 14.3 OPCo 34.5 34.5 19.0 19.0 PSO 19.2 19.2 10.6 10.6 SWEPCo 22.0 22.0 12.7 12.7
SWEPCo's Investment In DHLC	SWEPCo’s investment in DHLC was: December 31, 2024 2023 As Reported on Maximum As Reported on Maximum (in millions) Capital Contribution from SWEPCo $ 7.6 $ 7.6 $ 7.6 $ 7.6 Retained Earnings 0.3 0.3 0.4 0.4 SWEPCo’s Share of Obligations — 15.6 — 19.2 Total Investment in DHLC $ 7.9 $ 23.5 $ 8.0 $ 27.2
AEP's Investment In OVEC	AEP’s investment in OVEC was: December 31, 2024 2023 As Reported on Maximum As Reported on Maximum Exposure (in millions) Capital Contribution from AEP $ 4.4 $ 4.4 $ 4.4 $ 4.4 AEP’s Share of OVEC Debt (a) — 433.2 — 465.3 Total Investment in OVEC $ 4.4 $ 437.6 $ 4.4 $ 469.7 (a) Based on the Registrants’ power participation ratios, APCo, I&M and OPCo’s share of OVEC debt was $156 million, $78 million and $199 million as of December 31, 2024, respectively, and $168 million, $84 million and $213 million as of December 31, 2023, respectively.
Purchased Power from OVEC	Power purchased by the Registrant Subsidiaries from OVEC is included in Purchased Electricity, Fuel and Other Consumables Used for Electric Generation and Purchased Electricity for Resale on the statements of income and is shown in the table below: Years Ended December 31, Company 2024 2023 2022 (in millions) APCo $ 133.6 $ 121.8 $ 119.3 I&M 66.8 60.9 59.7 OPCo 169.7 154.7 151.8

PROPERTY, PLANT, AND EQUIPMENT

PROPERTY, PLANT, AND EQUIPMENT (Tables)	12 Months Ended
	Dec. 31, 2024
Property, Plant and Equipment [Abstract]
Schedule of Property, Plant and Equipment	Property, Plant and Equipment is shown functionally on the face of the balance sheets. The following tables include the total plant balances as of December 31, 2024 and 2023: December 31, 2024 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Regulated Property, Plant and Equipment Generation $ 24,694.5 (a) $ — $ — $ 7,272.6 $ 5,438.5 $ — $ 2,772.4 $ 5,287.5 (a) Transmission 38,871.9 7,546.2 14,913.4 5,001.5 1,957.8 3,663.9 1,345.3 2,863.8 Distribution 31,061.9 6,250.5 — 5,568.5 3,535.0 7,244.0 3,698.8 3,007.1 Other 6,544.9 1,172.9 515.9 1,023.9 948.3 1,245.3 546.8 682.7 CWIP 6,321.5 (a) 1,118.0 1,965.4 742.6 330.1 691.1 378.8 627.3 (a) Less: Accumulated Depreciation 25,794.0 2,045.7 1,578.5 6,030.9 4,607.0 2,883.0 2,214.7 3,048.5 Total Regulated Property, Plant and Equipment - Net 81,700.7 14,041.9 15,816.2 13,578.2 7,602.7 9,961.3 6,527.4 9,419.9 Nonregulated Property, Plant and Equipment - Net 714.9 1.6 0.3 34.3 76.6 9.8 4.9 26.2 Total Property, Plant and Equipment - Net $ 82,415.6 $ 14,043.5 $ 15,816.5 $ 13,612.5 $ 7,679.3 $ 9,971.1 $ 6,532.3 $ 9,446.1 December 31, 2023 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Regulated Property, Plant and Equipment Generation $ 23,862.7 (a) $ — $ — $ 7,041.3 $ 5,588.7 $ — $ 2,695.5 $ 4,790.7 (a) Transmission 35,903.6 6,812.6 13,723.9 4,711.8 1,906.4 3,395.1 1,228.3 2,660.6 Distribution 28,989.9 5,798.8 — 5,176.6 3,254.0 6,839.4 3,450.8 2,824.1 Other 5,986.1 1,142.9 501.2 943.7 856.8 1,114.4 502.7 544.1 CWIP 5,480.6 (a) 904.6 1,563.7 709.2 294.1 654.0 313.7 555.8 (a) Less: Accumulated Depreciation 24,093.8 1,886.7 1,291.4 5,684.0 4,353.7 2,712.7 2,083.6 2,840.8 Total Regulated Property, Plant and Equipment - Net 76,129.1 12,772.2 14,497.4 12,898.6 7,546.3 9,290.2 6,107.4 8,534.5 Nonregulated Property, Plant and Equipment - Net 564.3 1.8 0.3 32.9 82.7 9.7 4.9 23.9 Total Property, Plant and Equipment - Net $ 76,693.4 $ 12,774.0 $ 14,497.7 $ 12,931.5 $ 7,629.0 $ 9,299.9 $ 6,112.3 $ 8,558.4 (a) AEP and SWEPCo’s regulated generation and regulated CWIP include amounts related to SWEPCo’s Arkansas jurisdictional share of the Turk Plant.
Schedule of Depreciation, Depletion and Amortization - Regulated	The following tables provide total regulated annual composite depreciation rates and depreciable lives for the Registrants: AEP 2024 2023 2022 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 2.7% - 4.9% 20 - 162 2.7% - 4.7% 20 - 162 2.7% - 7.6% 20 - 132 Transmission 2.1% - 2.7% 15 - 79 2.0% - 2.7% 15 - 78 2.0% - 2.7% 24 - 75 Distribution 2.8% - 3.5% 7 - 85 2.9% - 3.6% 7 - 85 2.7% - 3.6% 7 - 78 Other 3.0% - 8.9% 5 - 75 3.8% - 9.1% 5 - 75 3.1% - 14.4% 5 - 75 AEP Texas 2024 2023 2022 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Transmission 2.2% 50 - 79 2.2% 50 - 75 2.2% 50 - 75 Distribution 2.8% 15 - 74 2.9% 7 - 70 2.9% 7 - 70 Other 5.9% 5 - 54 6.0% 5 - 50 6.2% 5 - 50 AEPTCo 2024 2023 2022 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Transmission 2.7% 24 - 78 2.6% 24 - 78 2.6% 24 - 75 Other 7.1% 5 - 58 7.0% 5 - 58 6.6% 5 - 56 APCo 2024 2023 2022 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 3.2% 35 - 162 3.3% 35 - 162 3.6% 35 - 118 Transmission 2.3% 15 - 78 2.3% 15 - 78 2.2% 24 - 75 Distribution 3.5% 12 - 60 3.6% 12 - 60 3.6% 12 - 57 Other 6.8% 5 - 55 7.4% 5 - 55 7.3% 5 - 55 I&M 2024 2023 2022 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 4.9% 20 - 132 4.7% 20 - 132 4.9% 20 - 132 Transmission 2.6% 44 - 67 2.5% 44 - 67 2.5% 44 - 67 Distribution 2.8% 15 - 76 2.9% 14 - 71 3.1% 14 - 71 Other 8.9% 5 - 45 9.1% 5 - 45 10.1% 5 - 45 OPCo 2024 2023 2022 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Transmission 2.3% 39 - 60 2.3% 39 - 60 2.3% 39 - 60 Distribution 3.1% 11 - 70 3.1% 11 - 70 2.7% 11 - 70 Other 5.9% 5 - 50 6.4% 5 - 50 6.1% 5 - 50 PSO 2024 2023 2022 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 3.3% 30 - 78 3.0% 25 - 75 3.1% 30 - 75 Transmission 2.6% 41 - 75 2.6% 41 - 75 2.5% 42 - 75 Distribution 2.8% 15 - 85 2.9% 15 - 85 2.9% 15 - 78 Other 6.6% 5 - 58 6.8% 5 - 58 6.8% 5 - 56 SWEPCo 2024 2023 2022 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 3.7% 30 - 65 2.9% 30 - 65 2.7% 30 - 65 Transmission 2.2% 46 - 70 2.2% 46 - 70 2.3% 44 - 70 Distribution 2.9% 7 - 75 2.9% 7 - 75 2.9% 15 - 75 Other 6.7% 5 - 58 8.5% 5 - 58 9.0% 5 - 57
Schedule of Depreciation, Depletion and Amortization - Unregulated	The following table includes the nonregulated annual composite depreciation rate ranges and nonregulated depreciable life ranges for AEP. With the exception of I&M, the Registrants' depreciation rate ranges and depreciable life ranges are not meaningful for nonregulated property for 2024, 2023 and 2022. 2024 2023 2022 Functional Class of Property Annual Composite Depreciable Annual Composite Depreciable Annual Composite Depreciable (in years) (in years) (in years) Generation 1.8% - 6.0% 39 - 61 4.8% - 6.7% 10 - 61 3.8% - 8.7% 3 - 61 Transmission NA NA 2.5% 62 2.8% 10 - 62 Distribution NA NA NA NA NA NA Other 9.7% 5 - 35 10.6% 5 - 35 25.2% 5 - 35 (a) I&M's annual composite depreciation rate for Generation property is 1.8% and the depreciable life is 39 years. NA Not applicable.
Schedule of Asset Retirement Obligation (ARO)	The following is a reconciliation of the 2024 and 2023 aggregate carrying amounts of ARO by Registrant: Company ARO as of December 31, 2023 Accretion Liabilities Liabilities Revisions in ARO as of December 31, 2024 (in millions) AEP(b)(c)(d)(e)(f) $ 3,031.2 $ 140.1 $ 612.4 $ (102.4) $ (69.6) $ 3,611.7 AEP Texas (e) 4.5 0.2 — (0.8) — 3.9 APCo (b)(e)(f) 464.0 27.7 247.1 (18.1) 81.0 801.7 I&M (b)(c)(e) 2,106.0 80.2 85.7 (2.2) (175.9) 2,093.8 OPCo (b)(e) 2.1 1.4 52.9 (0.1) — 56.3 PSO (b)(e)(f) 84.2 5.8 33.7 (1.9) — 121.8 SWEPCo (b)(d)(e)(f) 281.6 16.2 30.2 (69.2) 19.9 278.7 Company ARO as of December 31, 2022 Accretion Liabilities Liabilities Revisions in ARO as of December 31, 2023 (in millions) AEP (b)(c)(d)(e)(f) $ 2,943.6 $ 116.3 $ 38.9 $ (130.6) $ 63.0 $ 3,031.2 AEP Texas (e) 4.5 0.2 — (0.3) 0.1 4.5 APCo (b)(e)(f) 427.7 16.8 16.1 (23.1) 26.5 464.0 I&M (b)(c)(e) 2,028.1 74.8 4.8 (3.7) 2.0 2,106.0 OPCo (e) 5.0 0.2 — (3.1) — 2.1 PSO (b)(e)(f) 75.7 4.7 5.8 (1.2) (0.8) 84.2 SWEPCo (b)(d)(e)(f) 280.9 13.7 7.5 (55.0) 34.5 281.6 (a) Unless discussed above, primarily related to ash ponds, landfills and mine reclamation, generally due to changes in estimated closure area, volumes and/or unit costs. (b) Includes ARO related to ash disposal facilities. (c) Includes ARO related to nuclear decommissioning costs for the Cook Plant. (d) Includes ARO related to Sabine and DHLC. (e) Includes ARO related to asbestos removal. (f) Includes ARO related to renewables.
Schedule of Allowance For Equity Funds Used During Construction	The Registrants’ amounts of Allowance for Equity Funds Used During Construction are summarized in the following table: Years Ended December 31, Company 2024 2023 2022 (in millions) AEP $ 211.0 $ 174.9 $ 133.7 AEP Texas 45.9 28.4 19.7 AEPTCo 89.4 83.2 70.7 APCo 16.1 11.9 11.7 I&M 13.3 10.9 9.8 OPCo 23.4 17.1 13.9 PSO 7.4 8.4 1.5 SWEPCo 13.5 11.5 4.9
Schedule of Allowance For Borrowed Funds Used During Construction	The Registrants’ amounts of allowance for borrowed funds used during construction, including capitalized interest, are summarized in the following table: Years Ended December 31, Company 2024 2023 2022 (in millions) AEP $ 129.8 $ 117.3 $ 63.0 AEP Texas 30.7 23.4 11.5 AEPTCo 33.7 31.4 22.4 APCo 10.5 14.1 6.5 I&M 9.2 7.7 5.7 OPCo 12.8 14.0 6.7 PSO 9.7 5.2 2.7 SWEPCo 15.1 9.8 4.3
Schedule of Jointly-owned Electric Facilities	Each Registrant’s proportionate share of the operating costs associated with these facilities is included in its statements of income and the investments and accumulated depreciation are reflected in its balance sheets under Property, Plant and Equipment as follows: Registrant’s Share as of December 31, 2024 Fuel Percent of Utility Plant Construction Accumulated (in millions) AEP Flint Creek Generating Station, Unit 1 (a) Coal 50.0 % $ 404.1 $ 3.4 $ 188.8 Turk Generating Plant (a) Coal 73.3 % 1,517.0 1.2 350.2 Total $ 1,921.1 $ 4.6 $ 539.0 I&M Rockport Generating Plant (b)(c) Coal 50.0 % $ 1,345.0 $ 10.9 $ 1,181.8 PSO North Central Wind Energy Facilities (d)(e) Wind 45.5 % $ 912.3 $ 1.0 $ 77.6 SWEPCo Flint Creek Generating Station, Unit 1 (a) Coal 50.0 % $ 404.1 $ 3.4 $ 188.8 Turk Generating Plant (a) Coal 73.3 % 1,517.0 1.2 350.2 North Central Wind Energy Facilities (d)(e) Wind 54.5 % 1,093.5 1.2 98.1 Total $ 3,014.6 $ 5.8 $ 637.1 Registrant’s Share as of December 31, 2023 Fuel Percent of Utility Plant Construction Accumulated (in millions) AEP Flint Creek Generating Station, Unit 1 (a) Coal 50.0 % $ 402.8 $ 1.6 $ 167.5 Turk Generating Plant (a) Coal 73.3 % 1,504.0 10.1 323.3 Total $ 1,906.8 $ 11.7 $ 490.8 I&M Rockport Generating Plant (b)(c) Coal 50.0 % $ 1,341.4 $ 7.9 $ 1,018.9 PSO North Central Wind Energy Facilities (d)(e) Wind 45.5 % $ 906.3 $ 2.4 $ 54.1 SWEPCo Flint Creek Generating Station, Unit 1 (a) Coal 50.0 % $ 402.8 $ 1.6 $ 167.5 Turk Generating Plant (a) Coal 73.3 % 1,504.0 10.1 323.3 North Central Wind Energy Facilities (d)(e) Wind 54.5 % 1,086.3 2.9 67.9 Total $ 2,993.1 $ 14.6 $ 558.7 (a) Operated by SWEPCo. (b) Operated by I&M. (c) AEGCo owns 50%. (d) Operated by PSO. (e)

REVENUE FROM CONTRACTS WITH C_2

REVENUE FROM CONTRACTS WITH CUSTOMERS (Tables)	12 Months Ended
	Dec. 31, 2024
Revenue from Contract with Customer [Abstract]
Schedule of Disaggregated Revenues from Contracts with Customers	The table below represents AEP’s reportable segment revenues from contracts with customers, net of respective provisions for refund, by type of revenue: Year Ended December 31, 2024 VIU T&D AEPTHCo G&M Corporate and Other Reconciling Adjustments AEP Consolidated (in millions) Retail Revenues: Residential Revenues $ 4,561.9 $ 2,755.7 $ — $ — $ — $ — $ 7,317.6 Commercial Revenues 2,731.4 1,567.4 — — — — 4,298.8 Industrial Revenues (a) 2,659.0 515.2 — — — (0.9) 3,173.3 Other Retail Revenues 231.5 56.4 — — — — 287.9 Total Retail Revenues 10,183.8 4,894.7 — — — (0.9) 15,077.6 Wholesale and Competitive Retail Revenues: Generation Revenues 747.8 — — 103.2 — — 851.0 Transmission Revenues (b) 483.3 769.5 1,978.3 — — (1,620.1) 1,611.0 Renewable Generation Revenues (a) — — — 23.2 — (4.4) 18.8 Retail, Trading and Marketing Revenues (c) — — — 2,080.5 1.3 (96.4) 1,985.4 Total Wholesale and Competitive Retail Revenues 1,231.1 769.5 1,978.3 2,206.9 1.3 (1,720.9) 4,466.2 Other Revenues from Contracts with Customers (d) 227.3 197.5 25.8 4.1 184.7 (213.5) 425.9 Total Revenues from Contracts with Customers 11,642.2 5,861.7 2,004.1 2,211.0 186.0 (1,935.3) 19,969.7 Other Revenues: Alternative Revenue Programs (e) (22.0) 26.0 (53.3) — — (29.8) (79.1) Other Revenues (a) (f) (23.6) 20.0 — (165.6) (2.9) 2.8 (169.3) Total Other Revenues (45.6) 46.0 (53.3) (165.6) (2.9) (27.0) (248.4) Total Revenues $ 11,596.6 $ 5,907.7 $ 1,950.8 $ 2,045.4 $ 183.1 $ (1,962.3) $ 19,721.3 (a) Amounts include affiliated and nonaffiliated revenues. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $1.6 billion and Vertically Integrated Utilities was $177 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $96 million. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $137 million. The remaining affiliated amounts were immaterial. (e) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. (f) Generation & Marketing includes economic hedge activity. Year Ended December 31, 2023 VIU T&D AEPTHCo G&M Corporate and Other Reconciling Adjustments AEP Consolidated (in millions) Retail Revenues: Residential Revenues $ 4,479.3 $ 2,609.1 $ — $ — $ — $ — $ 7,088.4 Commercial Revenues 2,678.8 1,497.2 — — — — 4,176.0 Industrial Revenues (a) 2,748.2 642.1 — — — (0.9) 3,389.4 Other Retail Revenues 242.7 50.7 — — — — 293.4 Total Retail Revenues 10,149.0 4,799.1 — — — (0.9) 14,947.2 Wholesale and Competitive Retail Revenues: Generation Revenues 662.5 — — 111.3 — — 773.8 Transmission Revenues (b) 444.0 701.6 1,748.9 — — (1,418.3) 1,476.2 Renewable Generation Revenues (a) — — — 80.6 — (6.7) 73.9 Retail, Trading and Marketing Revenues (c) — — — 1,836.2 0.6 (82.2) 1,754.6 Total Wholesale and Competitive Retail Revenues 1,106.5 701.6 1,748.9 2,028.1 0.6 (1,507.2) 4,078.5 Other Revenues from Contracts with Customers (d) 204.4 208.1 16.8 8.6 151.5 (160.3) 429.1 Total Revenues from Contracts with Customers 11,459.9 5,708.8 1,765.7 2,036.7 152.1 (1,668.4) 19,454.8 Other Revenues: Alternative Revenue Programs (e) (35.0) (19.5) (37.1) — — (25.5) (117.1) Other Revenues (a) (f) 24.6 24.0 (0.1) (404.5) 15.9 (15.3) (355.4) Total Other Revenues (10.4) 4.5 (37.2) (404.5) 15.9 (40.8) (472.5) Total Revenues $ 11,449.5 $ 5,713.3 $ 1,728.5 $ 1,632.2 $ 168.0 $ (1,709.2) $ 18,982.3 (a) Amounts include affiliated and nonaffiliated revenues. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $1.5 billion and Vertically Integrated Utilities was $205 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $82 million. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $100 million. The remaining affiliated amounts were immaterial. (e) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. (f) Generation & Marketing includes economic hedge activity. Year Ended December 31, 2022 VIU T&D AEPTHCo G&M Corporate and Other Reconciling Adjustments AEP Consolidated (in millions) Retail Revenues: Residential Revenues $ 4,498.6 $ 2,497.3 $ — $ — $ — $ — $ 6,995.9 Commercial Revenues 2,576.5 1,365.2 — — — — 3,941.7 Industrial Revenues (a) 2,543.8 711.3 — — — (0.9) 3,254.2 Other Retail Revenues 212.2 49.1 — — — — 261.3 Total Retail Revenues 9,831.1 4,622.9 — — — (0.9) 14,453.1 Wholesale and Competitive Retail Revenues: Generation Revenues 958.3 — — 271.2 — — 1,229.5 Transmission Revenues (b) 442.8 650.0 1,700.6 — — (1,413.2) 1,380.2 Renewable Generation Revenues (a) — — — 129.1 — (8.0) 121.1 Retail, Trading and Marketing Revenues (a) — — — 1,713.2 6.9 (10.1) 1,710.0 Total Wholesale and Competitive Retail Revenues 1,401.1 650.0 1,700.6 2,113.5 6.9 (1,431.3) 4,440.8 Other Revenues from Contracts with Customers (c) 241.1 247.3 8.2 12.1 93.9 (104.8) 497.8 Total Revenues from Contracts with Customers 11,473.3 5,520.2 1,708.8 2,125.6 100.8 (1,537.0) 19,391.7 Other Revenues: Alternative Revenue Programs (d) 3.8 (26.8) (31.8) — — (57.7) (112.5) Other Revenues (a) (e) 0.4 18.6 — 341.3 9.1 (9.1) 360.3 Total Other Revenues 4.2 (8.2) (31.8) 341.3 9.1 (66.8) 247.8 Total Revenues $ 11,477.5 $ 5,512.0 $ 1,677.0 $ 2,466.9 $ 109.9 $ (1,603.8) $ 19,639.5 (a) Amounts include affiliated and nonaffiliated revenues. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $1.3 billion. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Corporate and Other was $59 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. Year Ended December 31, 2024 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 724.8 $ — $ 1,772.0 $ 847.2 $ 2,030.8 $ 799.6 $ 726.4 Commercial Revenues 466.6 — 764.4 605.1 1,100.7 509.5 558.1 Industrial Revenues (a) 141.5 — 813.1 595.6 373.7 349.1 367.9 Other Retail Revenues 38.9 — 113.0 5.1 17.4 100.5 9.2 Total Retail Revenues 1,371.8 — 3,462.5 2,053.0 3,522.6 1,758.7 1,661.6 Wholesale Revenues: Generation Revenues (b) — — 304.5 393.9 — 9.4 176.9 Transmission Revenues (c) 673.2 1,924.6 184.6 40.6 96.3 42.1 172.1 Total Wholesale Revenues 673.2 1,924.6 489.1 434.5 96.3 51.5 349.0 Other Revenues from Contracts with Customers (d) 35.8 25.9 87.2 116.0 162.0 39.3 32.7 Total Revenues from Contracts with Customers 2,080.8 1,950.5 4,038.8 2,603.5 3,780.9 1,849.5 2,043.3 Other Revenues: Alternative Revenue Programs (e) (0.9) (59.6) (6.4) (7.6) 26.9 (3.1) (7.0) Other Revenues (a) — — 0.2 (23.9) 20.0 — — Total Other Revenues (0.9) (59.6) (6.2) (31.5) 46.9 (3.1) (7.0) Total Revenues $ 2,079.9 $ 1,890.9 $ 4,032.6 $ 2,572.0 $ 3,827.8 $ 1,846.4 $ 2,036.3 (a) Amounts include affiliated and nonaffiliated revenues. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $159 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $1.6 billion, APCo was $87 million and SWEPCo was $65 million. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $75 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (e) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. Year Ended December 31, 2023 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 655.5 $ — $ 1,612.9 $ 841.9 $ 1,953.7 $ 831.2 $ 799.5 Commercial Revenues 415.2 — 699.6 575.2 1,082.0 538.8 609.4 Industrial Revenues (a) 145.0 — 778.4 614.2 497.1 423.1 415.9 Other Retail Revenues 35.5 — 106.3 5.0 15.1 112.8 10.1 Total Retail Revenues 1,251.2 — 3,197.2 2,036.3 3,547.9 1,905.9 1,834.9 Wholesale Revenues: Generation Revenues (b) — — 288.2 327.1 — 11.7 176.9 Transmission Revenues (c) 619.0 1,703.9 181.0 38.6 82.6 37.5 150.8 Total Wholesale Revenues 619.0 1,703.9 469.2 365.7 82.6 49.2 327.7 Other Revenues from Contracts with Customers (d) 35.9 16.7 74.2 120.3 172.3 21.5 29.5 Total Revenues from Contracts with Customers 1,906.1 1,720.6 3,740.6 2,522.3 3,802.8 1,976.6 2,192.1 Other Revenues: Alternative Revenue Programs (e) (4.2) (48.6) (20.1) (10.9) (15.3) 0.5 (9.4) Other Revenues (a) — — 0.2 24.5 23.9 (0.1) 0.1 Total Other Revenues (4.2) (48.6) (19.9) 13.6 8.6 0.4 (9.3) Total Revenues $ 1,901.9 $ 1,672.0 $ 3,720.7 $ 2,535.9 $ 3,811.4 $ 1,977.0 $ 2,182.8 (a) Amounts include affiliated and nonaffiliated revenues. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $159 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $1.4 billion, APCo was $93 million and SWEPCo was $73 million. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $68 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (e) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues. Year Ended December 31, 2022 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 667.2 $ — $ 1,558.7 $ 852.4 $ 1,830.2 $ 816.3 $ 820.7 Commercial Revenues 417.5 — 643.4 550.2 947.7 489.2 612.3 Industrial Revenues (a) 139.6 — 664.0 602.9 571.7 372.5 393.5 Other Retail Revenues 35.3 — 87.1 5.0 13.9 102.9 10.1 Total Retail Revenues 1,259.6 — 2,953.2 2,010.5 3,363.5 1,780.9 1,836.6 Wholesale Revenues: Generation Revenues (b) — — 299.9 490.0 — 26.5 273.2 Transmission Revenues (c) 563.8 1,643.5 167.0 36.8 86.2 39.2 148.7 Total Wholesale Revenues 563.8 1,643.5 466.9 526.8 86.2 65.7 421.9 Other Revenues from Contracts with Customers (d) 24.6 8.2 100.6 122.4 222.4 29.1 24.7 Total Revenues from Contracts with Customers 1,848.0 1,651.7 3,520.7 2,659.7 3,672.1 1,875.7 2,283.2 Other Revenues: Alternative Revenue Programs (e) (1.2) (27.2) (1.3) 10.0 (25.6) (1.0) 1.2 Other Revenues (a) — — 0.5 (0.1) 18.6 — — Total Other Revenues (1.2) (27.2) (0.8) 9.9 (7.0) (1.0) 1.2 Total Revenues $ 1,846.8 $ 1,624.5 $ 3,519.9 $ 2,669.6 $ 3,665.1 $ 1,874.7 $ 2,284.4 (a) Amounts include affiliated and nonaffiliated revenues. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $170 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $1.3 billion, APCo was $78 million and SWEPCo was $51 million. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $62 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (e) Alternative revenue programs in certain jurisdictions include regulatory mechanisms that periodically adjust for over/under collection of related revenues.
Schedule of Fixed Performance Obligations	The following table represents the Registrants’ remaining fixed performance obligations satisfied over time as of December 31, 2024. Fixed performance obligations primarily include electricity sales for fixed amounts of energy and stand ready services into PJM’s RPM market. The Registrants elected to apply the exemption to not disclose the value of unsatisfied performance obligations for contracts with an original expected term of one year or less. Due to the annual establishment of revenue requirements, transmission revenues are excluded from the table below. The Registrant Subsidiaries amounts shown in the table below include affiliated and nonaffiliated revenues. Company 2025 2026-2027 2028-2029 After 2029 Total (in millions) AEP $ 93.7 $ 143.0 $ 48.8 $ 16.1 $ 301.6 APCo 16.1 32.1 23.1 11.6 82.9 I&M 4.4 8.8 6.8 2.4 22.4
Schedule of Affiliated Accounts Receivable Contracts with Customers	The following table represents the amount of affiliated accounts receivable from contracts with customers included in Accounts Receivable - Affiliated Companies on the Registrant Subsidiaries’ balance sheets: Years Ended December 31, AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) 2024 $ — $ 131.6 $ 83.7 $ 55.0 $ 63.6 $ 13.0 $ 21.4 2023 — 123.2 71.7 44.0 70.1 12.4 27.4

SCHEDULE I - CONDENSED FINANC_3

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY (Tables)	12 Months Ended
	Dec. 31, 2024
Condensed Financial Information Disclosure [Abstract]
CONDENSED STATEMENTS OF INCOME	CONDENSED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME For the Years Ended December 31, 2024, 2023 and 2022 (in millions, except per-share and share amounts) Years Ended December 31, 2024 2023 2022 REVENUES Revenues $ 5.5 $ 5.1 $ 5.1 TOTAL REVENUES 5.5 5.1 5.1 EXPENSES Other Operation 66.0 16.7 84.9 Loss on the Expected Sale of the Kentucky Operations — — 363.3 Depreciation and Amortization 0.6 0.5 0.4 Amortization of KPCo Basis Difference (21.4) (16.5) — TOTAL EXPENSES 45.2 0.7 448.6 OPERATING INCOME (LOSS) (39.7) 4.4 (443.5) Other Income (Expense): Interest Income 107.9 181.0 80.3 Interest Expense (531.8) (526.3) (275.5) LOSS BEFORE INCOME TAX BENEFIT AND EQUITY EARNINGS (463.6) (340.9) (638.7) Income Tax Benefit (150.5) (80.8) (136.3) Equity Earnings of Unconsolidated Subsidiaries 3,280.2 2,468.2 2,809.6 NET INCOME 2,967.1 2,208.1 2,307.2 Other Comprehensive Income (Loss) 52.4 (139.2) (101.1) TOTAL COMPREHENSIVE INCOME $ 3,019.5 $ 2,068.9 $ 2,206.1 WEIGHTED AVERAGE NUMBER OF BASIC AEP COMMON SHARES OUTSTANDING 530,092,672 518,903,682 511,841,946 TOTAL BASIC EARNINGS PER SHARE ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS $ 5.60 $ 4.26 $ 4.51 WEIGHTED AVERAGE NUMBER OF DILUTED AEP COMMON SHARES OUTSTANDING 531,337,703 520,206,258 513,484,609 TOTAL DILUTED EARNINGS PER SHARE ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS $ 5.58 $ 4.24 $ 4.49 See Condensed Notes to Condensed Financial Information beginning on page S- 6 .
CONDENSED BALANCE SHEETS	CONDENSED BALANCE SHEETS ASSETS December 31, 2024 and 2023 (in millions) December 31, 2024 2023 CURRENT ASSETS Cash and Cash Equivalents $ 87.5 $ 197.8 Other Temporary Investments 2.9 2.6 Advances to Affiliates 1,944.6 2,004.5 Accounts Receivable: Affiliated Companies 32.5 47.7 General — 2.7 Total Accounts Receivable 32.5 50.4 Accrued Tax Benefits 93.7 77.7 Prepayments and Other Current Assets 11.6 11.6 TOTAL CURRENT ASSETS 2,172.8 2,344.6 PROPERTY, PLANT AND EQUIPMENT General 3.2 3.1 Total Property, Plant and Equipment 3.2 3.1 Accumulated Depreciation, Depletion and Amortization 1.7 1.4 TOTAL PROPERTY, PLANT AND EQUIPMENT – NET 1.5 1.7 OTHER NONCURRENT ASSETS Investments in Unconsolidated Subsidiaries 35,306.2 33,598.6 Affiliated Notes Receivable 105.0 295.0 Deferred Charges and Other Noncurrent Assets 184.6 137.0 TOTAL OTHER NONCURRENT ASSETS 35,595.8 34,030.6 TOTAL ASSETS $ 37,770.1 $ 36,376.9 See Condensed Notes to Condensed Financial Information beginning on page S- 6 . CONDENSED BALANCE SHEETS LIABILITIES AND EQUITY December 31, 2024 and 2023 (dollars in millions) December 31, 2024 2023 CURRENT LIABILITIES Advances from Affiliates $ 506.6 $ 728.3 Accounts Payable: General 4.7 11.1 Affiliated Companies 2.2 12.3 Short-term Debt 1,618.3 1,937.9 Long-term Debt Due Within One Year – Nonaffiliated 1,281.5 1,104.0 Other Current Liabilities 202.4 137.7 TOTAL CURRENT LIABILITIES 3,615.7 3,931.3 NONCURRENT LIABILITIES Long-term Debt – Nonaffiliated 7,124.3 7,086.9 Deferred Credits and Other Noncurrent Liabilities 48.5 69.5 TOTAL NONCURRENT LIABILITIES 7,172.8 7,156.4 TOTAL LIABILITIES 10,788.5 11,087.7 MEZZANINE EQUITY Contingently Redeemable Performance Share Awards 37.8 42.5 COMMON SHAREHOLDERS’ EQUITY Common Stock – Par Value – $6.50 Per Share: 2024 2023 Shares Authorized 600,000,000 600,000,000 Shares Issued 534,094,530 527,369,157 (1,186,815 and 1,184,572 Shares were Held in Treasury as of December 31, 2024 and 2023, Respectively) 3,471.6 3,427.9 Paid-in Capital 9,606.1 9,073.9 Retained Earnings 13,869.2 12,800.4 Accumulated Other Comprehensive Income (Loss) (3.1) (55.5) TOTAL AEP COMMON SHAREHOLDERS’ EQUITY 26,943.8 25,246.7 TOTAL LIABILITIES, MEZZANINE EQUITY AND TOTAL EQUITY $ 37,770.1 $ 36,376.9 See Condensed Notes to Condensed Financial Information beginning on page S- 6 .
CONDENSED STATEMENTS OF CASH FLOWS	CONDENSED STATEMENTS OF CASH FLOWS For the Years Ended December 31, 2024, 2023 and 2022 (in millions) Years Ended December 31, 2024 2023 2022 OPERATING ACTIVITIES Net Income $ 2,967.1 $ 2,208.1 $ 2,307.2 Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities: Depreciation and Amortization 0.6 0.5 0.4 Amortization of KPCo Basis Difference (21.4) (16.5) — Deferred Income Taxes (53.3) 59.7 (63.3) Loss on the Expected Sale of the Kentucky Operations — — 363.3 Equity Earnings of Unconsolidated Subsidiaries (3,280.2) (2,468.2) (2,809.6) Cash Dividends Received from Unconsolidated Subsidiaries 1,143.4 686.3 603.9 Change in Other Noncurrent Assets 4.9 (28.4) (5.0) Change in Other Noncurrent Liabilities 70.8 92.3 83.5 Changes in Certain Components of Working Capital: Accounts Receivable, Net 17.9 28.7 (61.0) Accounts Payable (16.5) (15.9) 1.1 Other Current Assets — (3.6) (6.0) Other Current Liabilities 55.3 (14.5) (76.6) Net Cash Flows from Operating Activities 888.6 528.5 337.9 INVESTING ACTIVITIES Construction Expenditures (0.6) (0.8) (0.7) Change in Advances to Affiliates, Net 59.9 2,007.6 (1,411.3) Capital Contributions to Unconsolidated Subsidiaries (399.9) (789.9) (568.3) Return of Capital Contributions from Unconsolidated Subsidiaries 898.9 56.6 24.5 Issuance of Notes Receivable to Unconsolidated Subsidiaries — (210.0) (20.0) Repayment of Notes Receivable from Unconsolidated Subsidiaries 190.0 — — Other Investing Activities — — (0.2) Net Cash Flows from (Used for) Investing Activities 748.3 1,063.5 (1,976.0) FINANCING ACTIVITIES Issuance of Common Stock, Net 552.1 999.6 826.5 Issuance of Long-term Debt 1,285.4 1,829.8 986.6 Issuance of Short-term Debt with Original Maturities Greater Than 90 Days 723.8 1,069.9 833.9 Change in Short-term Debt with Original Maturities Less Than 90 Day, Net (172.3) (1,365.4) 1,650.4 Retirement of Long-term Debt (1,104.0) (1,050.0) (300.0) Change in Advances from Affiliates, Net (221.7) (191.6) 336.9 Redemption of Short-term Debt with Original Maturities Greater Than 90 Days (871.1) (1,128.8) (986.1) Dividends Paid on Common Stock (1,898.3) (1,752.3) (1,628.7) Other Financing Activities (41.1) (59.6) (74.5) Net Cash Flows from (Used for) Financing Activities (1,747.2) (1,648.4) 1,645.0 Net Increase (Decrease) in Cash and Cash Equivalents (110.3) (56.4) 6.9 Cash and Cash Equivalents at Beginning of Period 197.8 254.2 247.3 Cash and Cash Equivalents at End of Period $ 87.5 $ 197.8 $ 254.2 See Condensed Notes to Condensed Financial Information beginning on page S- 6 .
Schedule of Long-term Debt	The following table details long-term debt outstanding: Weighted-Average Interest Rate Ranges as of Outstanding as of Interest Rate as of December 31, December 31, Company Maturity December 31, 2024 2024 2023 2024 2023 AEP (in millions) Senior Unsecured Notes 2025-2054 4.32% 1.00%-8.13% 1.00%-8.13% $ 36,410.9 $ 33,779.4 Pollution Control Bonds (a) 2025-2036 (b) 3.26% 0.63%-4.70% 0.63%-4.90% 1,771.3 1,771.6 Notes Payable – Nonaffiliated (c) 2025-2034 6.49% 0.93%-6.89% 0.93%-6.59% 609.9 193.3 Securitization Bonds 2025-2039 (d) 4.08% 2.06%-4.88% 2.06%-3.77% 578.0 368.9 Spent Nuclear Fuel Obligation (e) 316.3 300.4 Junior Subordinated Notes 2025-2054 5.67% 3.88%-7.05% 2.03%-5.70% 2,579.1 2,388.1 Other Long-term Debt 2025-2059 5.60% 3.00%-13.72% 3.00%-13.72% 377.3 1,341.5 Total Long-term Debt Outstanding $ 42,642.8 $ 40,143.2 AEP Texas Senior Unsecured Notes 2025-2052 4.39% 2.10%-6.76% 2.10%-6.76% $ 5,873.8 $ 5,027.2 Pollution Control Bonds (a) 2029-2030 (b) 3.88% 2.60%-4.55% 2.60%-4.55% 440.3 440.3 Securitization Bonds 2025-2029 (d) 2.27% 2.06%-2.29% 2.06%-2.84% 126.8 221.8 Other Long-term Debt 2059 4.50% 4.50% 4.50%-6.71% 0.7 200.5 Total Long-term Debt Outstanding $ 6,441.6 $ 5,889.8 AEPTCo Senior Unsecured Notes 2025-2053 4.12% 2.75%-5.52% 2.75%-5.52% $ 5,768.1 $ 5,414.4 Total Long-term Debt Outstanding $ 5,768.1 $ 5,414.4 APCo Senior Unsecured Notes 2025-2050 4.75% 2.70%-7.00% 2.70%-7.00% $ 4,984.1 $ 4,584.9 Pollution Control Bonds (a) 2025-2036 (b) 2.95% 0.63%-4.22% 0.63%-4.90% 429.9 430.0 Securitization Bonds 2028 (d) 3.77% 3.77% 3.77% 119.8 147.0 Other Long-term Debt 2025-2026 5.84% 5.75%-13.72% 6.46%-13.72% 126.5 426.4 Total Long-term Debt Outstanding $ 5,660.3 $ 5,588.3 I&M Senior Unsecured Notes 2028-2053 4.52% 3.25%-6.05% 3.25%-6.05% $ 2,845.2 $ 2,843.6 Pollution Control Bonds (a) 2025 (b) 2.49% 0.75%-3.05% 0.75%-3.05% 189.9 189.4 Notes Payable – Nonaffiliated (c) 2025-2028 5.78% 0.93%-6.41% 0.93%-6.59% 142.7 163.3 Spent Nuclear Fuel Obligation (e) 316.3 300.4 Other Long-term Debt 2025 6.00% 6.00% 6.00% 0.2 2.7 Total Long-term Debt Outstanding $ 3,494.3 $ 3,499.4 OPCo Senior Unsecured Notes 2030-2051 4.16% 1.63%-6.60% 1.63%-6.60% $ 3,715.7 $ 3,366.8 Total Long-term Debt Outstanding $ 3,715.7 $ 3,366.8 PSO Senior Unsecured Notes 2025-2051 4.29% 2.20%-6.63% 2.20%-6.63% $ 2,854.2 $ 2,257.8 Other Long-term Debt 2027 3.00% 3.00% 3.00%-6.71% 1.4 126.8 Total Long-term Debt Outstanding $ 2,855.6 $ 2,384.6 SWEPCo Senior Unsecured Notes 2026-2051 3.73% 1.65%-6.20% 1.65%-6.20% $ 3,649.4 $ 3,646.9 Securitization Bonds 2039 (d) 4.88% 4.88% —% 331.4 — Total Long-term Debt Outstanding $ 3,980.8 $ 3,646.9 (a) For certain series of Pollution Control Bonds, interest rates are subject to periodic adjustment. Certain series may be purchased on demand at periodic interest adjustment dates. Letters of credit from banks and insurance policies support certain series. Consequently, these bonds have been classified for maturity purposes as Long-term Debt Due Within One Year - Nonaffiliated on the balance sheets. (b) Certain Pollution Control Bonds are subject to redemption earlier than the maturity date. (c) Notes payable represent outstanding promissory notes issued under term loan agreements and credit agreements with a number of banks and other financial institutions. At expiration, all notes then issued and outstanding are due and payable. Interest rates are both fixed and variable. Variable rates generally relate to specified short-term interest rates. (d) Dates represent the scheduled final payment dates for the securitization bonds. The legal maturity date is one to two years later. These bonds have been classified for maturity and repayment purposes based on the scheduled final payment date. (e) Spent Nuclear Fuel Obligation consists of a liability along with accrued interest for disposal of SNF. See “Spent Nuclear Fuel Disposal” section of Note 6 for additional information. The following details long-term debt outstanding as of December 31, 2024 and 2023: Long-term Debt Weighted-Average Interest Rate Ranges as of Outstanding as of Interest Rate as of December 31, December 31, Type of Debt Maturity December 31, 2024 2024 2023 2024 2023 (in millions) Senior Unsecured Notes 2025-2050 4.29% 1.00%-5.95% 1.00%-5.95% $ 5,290.0 $ 5,265.0 Pollution Control Bonds 2026-2029 (a) 3.12% 2.40%-3.75% 1.90%-2.60% 536.8 537.8 Junior Subordinated Notes 2025-2027 5.67% 3.88%-7.05% 2.03%-5.70% 2,579.0 2,388.1 Total Long-term Debt Outstanding 8,405.8 8,190.9 Long-term Debt Due Within One Year 1,281.5 1,104.0 Long-term Debt $ 7,124.3 $ 7,086.9 (a) Certain Pollution Control Bonds are subject to redemption earlier than the maturity date. Long-term debt outstanding as of December 31, 2024 is payable as follows: 2025 2026 2027 2028 2029 After 2029 Total (in millions) Principal Amount (a) $ 1,281.5 $ 50.0 $ 1,758.3 $ 930.4 $ 1,694.5 $ 2,750.0 $ 8,464.7 Unamortized Discount, Net and Debt Issuance Costs (58.9) Total Long-term Debt Outstanding $ 8,405.8 (a) Amounts reflect the impact of fair value hedge accounting. See “Accounting for Fair Value Hedging Strategies” section of Note 10 included in the 2024 Annual Report for additional information.
Schedule of Short-term Debt	AEP’s outstanding short-term debt was as follows: December 31, 2024 2023 Company Type of Debt Outstanding Interest Outstanding Interest (in millions) (in millions) AEP Securitized Debt for Receivables (b) $ 900.0 4.73 % $ 888.0 5.65 % AEP Commercial Paper 1,618.3 4.70 % 1,937.9 5.69 % SWEPCo Notes Payable 5.5 6.69 % 4.3 7.71 % Total Short-term Debt $ 2,523.8 $ 2,830.2 (a) Weighted-average rate of all borrowings outstanding as of December 31, 2024 and 2023, respectively. (b) Amount of securitized debt for receivables as accounted for under the “Transfers and Servicing” accounting guidance . Parent’s outstanding short-term debt was as follows: December 31, 2024 December 31, 2023 Type of Debt Outstanding Weighted-Average Outstanding Weighted-Average (in millions) (in millions) Commercial Paper $ 1,618.3 4.70 % $ 1,937.9 5.69 % Total Short-term Debt $ 1,618.3 $ 1,937.9

SCHEDULE I - CONDENSED FINANC_4

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY - AEPTCO PARENT (Tables)	12 Months Ended
	Dec. 31, 2024
Condensed Financial Statements, Captions [Line Items]
CONDENSED STATEMENTS OF INCOME	CONDENSED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME For the Years Ended December 31, 2024, 2023 and 2022 (in millions, except per-share and share amounts) Years Ended December 31, 2024 2023 2022 REVENUES Revenues $ 5.5 $ 5.1 $ 5.1 TOTAL REVENUES 5.5 5.1 5.1 EXPENSES Other Operation 66.0 16.7 84.9 Loss on the Expected Sale of the Kentucky Operations — — 363.3 Depreciation and Amortization 0.6 0.5 0.4 Amortization of KPCo Basis Difference (21.4) (16.5) — TOTAL EXPENSES 45.2 0.7 448.6 OPERATING INCOME (LOSS) (39.7) 4.4 (443.5) Other Income (Expense): Interest Income 107.9 181.0 80.3 Interest Expense (531.8) (526.3) (275.5) LOSS BEFORE INCOME TAX BENEFIT AND EQUITY EARNINGS (463.6) (340.9) (638.7) Income Tax Benefit (150.5) (80.8) (136.3) Equity Earnings of Unconsolidated Subsidiaries 3,280.2 2,468.2 2,809.6 NET INCOME 2,967.1 2,208.1 2,307.2 Other Comprehensive Income (Loss) 52.4 (139.2) (101.1) TOTAL COMPREHENSIVE INCOME $ 3,019.5 $ 2,068.9 $ 2,206.1 WEIGHTED AVERAGE NUMBER OF BASIC AEP COMMON SHARES OUTSTANDING 530,092,672 518,903,682 511,841,946 TOTAL BASIC EARNINGS PER SHARE ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS $ 5.60 $ 4.26 $ 4.51 WEIGHTED AVERAGE NUMBER OF DILUTED AEP COMMON SHARES OUTSTANDING 531,337,703 520,206,258 513,484,609 TOTAL DILUTED EARNINGS PER SHARE ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS $ 5.58 $ 4.24 $ 4.49 See Condensed Notes to Condensed Financial Information beginning on page S- 6 .
CONDENSED BALANCE SHEETS	CONDENSED BALANCE SHEETS ASSETS December 31, 2024 and 2023 (in millions) December 31, 2024 2023 CURRENT ASSETS Cash and Cash Equivalents $ 87.5 $ 197.8 Other Temporary Investments 2.9 2.6 Advances to Affiliates 1,944.6 2,004.5 Accounts Receivable: Affiliated Companies 32.5 47.7 General — 2.7 Total Accounts Receivable 32.5 50.4 Accrued Tax Benefits 93.7 77.7 Prepayments and Other Current Assets 11.6 11.6 TOTAL CURRENT ASSETS 2,172.8 2,344.6 PROPERTY, PLANT AND EQUIPMENT General 3.2 3.1 Total Property, Plant and Equipment 3.2 3.1 Accumulated Depreciation, Depletion and Amortization 1.7 1.4 TOTAL PROPERTY, PLANT AND EQUIPMENT – NET 1.5 1.7 OTHER NONCURRENT ASSETS Investments in Unconsolidated Subsidiaries 35,306.2 33,598.6 Affiliated Notes Receivable 105.0 295.0 Deferred Charges and Other Noncurrent Assets 184.6 137.0 TOTAL OTHER NONCURRENT ASSETS 35,595.8 34,030.6 TOTAL ASSETS $ 37,770.1 $ 36,376.9 See Condensed Notes to Condensed Financial Information beginning on page S- 6 . CONDENSED BALANCE SHEETS LIABILITIES AND EQUITY December 31, 2024 and 2023 (dollars in millions) December 31, 2024 2023 CURRENT LIABILITIES Advances from Affiliates $ 506.6 $ 728.3 Accounts Payable: General 4.7 11.1 Affiliated Companies 2.2 12.3 Short-term Debt 1,618.3 1,937.9 Long-term Debt Due Within One Year – Nonaffiliated 1,281.5 1,104.0 Other Current Liabilities 202.4 137.7 TOTAL CURRENT LIABILITIES 3,615.7 3,931.3 NONCURRENT LIABILITIES Long-term Debt – Nonaffiliated 7,124.3 7,086.9 Deferred Credits and Other Noncurrent Liabilities 48.5 69.5 TOTAL NONCURRENT LIABILITIES 7,172.8 7,156.4 TOTAL LIABILITIES 10,788.5 11,087.7 MEZZANINE EQUITY Contingently Redeemable Performance Share Awards 37.8 42.5 COMMON SHAREHOLDERS’ EQUITY Common Stock – Par Value – $6.50 Per Share: 2024 2023 Shares Authorized 600,000,000 600,000,000 Shares Issued 534,094,530 527,369,157 (1,186,815 and 1,184,572 Shares were Held in Treasury as of December 31, 2024 and 2023, Respectively) 3,471.6 3,427.9 Paid-in Capital 9,606.1 9,073.9 Retained Earnings 13,869.2 12,800.4 Accumulated Other Comprehensive Income (Loss) (3.1) (55.5) TOTAL AEP COMMON SHAREHOLDERS’ EQUITY 26,943.8 25,246.7 TOTAL LIABILITIES, MEZZANINE EQUITY AND TOTAL EQUITY $ 37,770.1 $ 36,376.9 See Condensed Notes to Condensed Financial Information beginning on page S- 6 .
CONDENSED STATEMENTS OF CASH FLOWS	CONDENSED STATEMENTS OF CASH FLOWS For the Years Ended December 31, 2024, 2023 and 2022 (in millions) Years Ended December 31, 2024 2023 2022 OPERATING ACTIVITIES Net Income $ 2,967.1 $ 2,208.1 $ 2,307.2 Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities: Depreciation and Amortization 0.6 0.5 0.4 Amortization of KPCo Basis Difference (21.4) (16.5) — Deferred Income Taxes (53.3) 59.7 (63.3) Loss on the Expected Sale of the Kentucky Operations — — 363.3 Equity Earnings of Unconsolidated Subsidiaries (3,280.2) (2,468.2) (2,809.6) Cash Dividends Received from Unconsolidated Subsidiaries 1,143.4 686.3 603.9 Change in Other Noncurrent Assets 4.9 (28.4) (5.0) Change in Other Noncurrent Liabilities 70.8 92.3 83.5 Changes in Certain Components of Working Capital: Accounts Receivable, Net 17.9 28.7 (61.0) Accounts Payable (16.5) (15.9) 1.1 Other Current Assets — (3.6) (6.0) Other Current Liabilities 55.3 (14.5) (76.6) Net Cash Flows from Operating Activities 888.6 528.5 337.9 INVESTING ACTIVITIES Construction Expenditures (0.6) (0.8) (0.7) Change in Advances to Affiliates, Net 59.9 2,007.6 (1,411.3) Capital Contributions to Unconsolidated Subsidiaries (399.9) (789.9) (568.3) Return of Capital Contributions from Unconsolidated Subsidiaries 898.9 56.6 24.5 Issuance of Notes Receivable to Unconsolidated Subsidiaries — (210.0) (20.0) Repayment of Notes Receivable from Unconsolidated Subsidiaries 190.0 — — Other Investing Activities — — (0.2) Net Cash Flows from (Used for) Investing Activities 748.3 1,063.5 (1,976.0) FINANCING ACTIVITIES Issuance of Common Stock, Net 552.1 999.6 826.5 Issuance of Long-term Debt 1,285.4 1,829.8 986.6 Issuance of Short-term Debt with Original Maturities Greater Than 90 Days 723.8 1,069.9 833.9 Change in Short-term Debt with Original Maturities Less Than 90 Day, Net (172.3) (1,365.4) 1,650.4 Retirement of Long-term Debt (1,104.0) (1,050.0) (300.0) Change in Advances from Affiliates, Net (221.7) (191.6) 336.9 Redemption of Short-term Debt with Original Maturities Greater Than 90 Days (871.1) (1,128.8) (986.1) Dividends Paid on Common Stock (1,898.3) (1,752.3) (1,628.7) Other Financing Activities (41.1) (59.6) (74.5) Net Cash Flows from (Used for) Financing Activities (1,747.2) (1,648.4) 1,645.0 Net Increase (Decrease) in Cash and Cash Equivalents (110.3) (56.4) 6.9 Cash and Cash Equivalents at Beginning of Period 197.8 254.2 247.3 Cash and Cash Equivalents at End of Period $ 87.5 $ 197.8 $ 254.2 See Condensed Notes to Condensed Financial Information beginning on page S- 6 .
AEP TRANSMISSION COMPANY, LLC | Parent Company
Condensed Financial Statements, Captions [Line Items]
CONDENSED STATEMENTS OF INCOME	CONDENSED STATEMENTS OF INCOME For the Years Ended December 31, 2024, 2023 and 2022 (in millions) Years Ended December 31, 2024 2023 2022 EXPENSES Other Operation $ 1.7 $ 0.2 $ 0.7 TOTAL EXPENSES 1.7 0.2 0.7 OPERATING LOSS (1.7) (0.2) (0.7) Other Income (Expense): Interest Income - Affiliated 241.1 218.0 177.8 Interest Expense (238.7) (215.1) (177.1) INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS OF UNCONSOLIDATED SUBSIDIARIES 0.7 2.7 — Income Tax Expense 0.1 1.4 — Equity Earnings of Unconsolidated Subsidiaries 687.8 612.9 594.2 NET INCOME $ 688.4 $ 614.2 $ 594.2 See Condensed Notes to Condensed Financial Information beginning on page S- 15 .
CONDENSED BALANCE SHEETS	CONDENSED BALANCE SHEETS ASSETS December 31, 2024 and 2023 (in millions) December 31, 2024 2023 CURRENT ASSETS Advances to Affiliates $ 20.4 $ — Accounts Receivable: General — 28.1 Affiliated Companies 61.7 44.0 Total Accounts Receivable 61.7 72.1 Notes Receivable - Affiliated 90.0 95.0 TOTAL CURRENT ASSETS 172.1 167.1 OTHER NONCURRENT ASSETS Notes Receivable - Affiliated 8,498.1 5,319.4 Investments in Unconsolidated Subsidiaries 4,272.8 6,476.2 Deferred Charges and Other Noncurrent Assets 0.3 — TOTAL OTHER NONCURRENT ASSETS 12,771.2 11,795.6 TOTAL ASSETS $ 12,943.3 $ 11,962.7 See Condensed Notes to Condensed Financial Information beginning on page S- 15 . CONDENSED BALANCE SHEETS LIABILITIES AND EQUITY December 31, 2024 and 2023 (in millions) December 31, 2024 2023 CURRENT LIABILITIES Advances from Affiliates $ — $ 42.7 Accounts Payable: General 69.4 35.4 Affiliated Companies 95.1 81.5 Long-term Debt Due Within One Year – Nonaffiliated 90.0 95.0 Accrued Interest 45.0 39.6 Other Current Liabilities 14.8 15.8 TOTAL CURRENT LIABILITIES 314.3 310.0 NONCURRENT LIABILITIES Long-term Debt – Nonaffiliated 5,678.1 5,319.4 TOTAL NONCURRENT LIABILITIES 5,678.1 5,319.4 TOTAL LIABILITIES 5,992.4 5,629.4 MEMBER’S EQUITY Paid-in Capital 3,100.6 3,043.4 Retained Earnings 3,850.3 3,289.9 TOTAL MEMBER’S EQUITY 6,950.9 6,333.3 TOTAL LIABILITIES AND MEMBER’S EQUITY $ 12,943.3 $ 11,962.7 See Condensed Notes to Condensed Financial Information beginning on page S- 15 .
CONDENSED STATEMENTS OF CASH FLOWS	CONDENSED STATEMENTS OF CASH FLOWS For the Years Ended December 31, 2024, 2023 and 2022 (in millions) Years Ended December 31, 2024 2023 2022 OPERATING ACTIVITIES Net Income $ 688.4 $ 614.2 $ 594.2 Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities: Equity Earnings of Unconsolidated Subsidiaries (687.8) (612.9) (594.2) Change in Other Noncurrent Assets — 3.8 — Change in Other Noncurrent Liabilities 4.0 11.5 9.1 Changes in Certain Components of Working Capital: Accounts Receivable, Net 10.4 (37.5) (2.2) Accounts Payable 12.9 36.6 (0.6) Accrued Interest 5.4 10.8 — Other Current Liabilities 34.0 (30.5) (0.8) Net Cash Flows from (Used for) Operating Activities 67.3 (4.0) 5.5 INVESTING ACTIVITIES Change in Advances to Affiliates, Net (20.4) — 12.7 Repayment of Notes Receivable from Affiliated Companies 95.0 60.0 104.0 Issuance of Notes Receivable to Affiliated Companies (450.0) (700.0) (550.0) Return of Capital Contributions from Unconsolidated Subsidiaries 132.8 183.7 130.0 Capital Contributions to Subsidiaries (61.7) (29.7) (69.5) Net Cash Flows Used for Investing Activities (304.3) (486.0) (372.8) FINANCING ACTIVITIES Capital Contributions from Member 61.7 29.7 72.7 Return of Capital to Member (4.5) (8.6) — Issuance of Long-term Debt – Nonaffiliated 445.7 689.0 540.8 Retirement of Long-term Debt – Nonaffiliated (95.0) (60.0) (104.0) Change in Advances from Affiliates, Net (42.7) 14.9 27.8 Dividends Paid to Member (128.0) (175.0) (170.0) Other Financing Activities (0.2) — — Net Cash Flows from Financing Activities 237.0 490.0 367.3 Net Change in Cash and Cash Equivalents — — — Cash and Cash Equivalents at Beginning of Period — — — Cash and Cash Equivalents at End of Period $ — $ — $ — See Condensed Notes to Condensed Financial Information beginning on page S- 15 .

ORGANIZATION AND SUMMARY OF S_4

ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Narrative (Details) $ in Millions	12 Months Ended
	Dec. 31, 2024 USD ($) subsidiary state plan shares	Dec. 31, 2023 USD ($) shares	Dec. 31, 2022 shares
Product Information [Line Items]
Number of states in which entity operates | state	11
Defined contribution plan, number of unfunded non-quality pension plans | plan	2
Defined benefit plan, concentration limits, in excess of all equity investments, percentage	5%
Defined benefit plan, concentration limits, cash equivalents of investment manager's equity portfolio, percentage	10%
Securities loaned, fair value | $	$ 60	$ 62
Antidilutive securities excluded from computation of earnings per share (in shares) | shares	0	0	0
Minimum
Product Information [Line Items]
Securities loaned, collateralized percentage	102%
AEPTCo
Product Information [Line Items]
Number of wholly-owned transmissions subsidiaries | subsidiary	7

ORGANIZATION AND SUMMARY OF S_5

ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Reconciliation of Cash, Cash Equivalents and Restricted Cash (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Restricted Cash and Cash Equivalents Items [Line Items]
Cash and Cash Equivalents	$ 202.9	$ 330.1
Restricted Cash	43.1	48.9
Total Cash, Cash Equivalents and Restricted Cash	246	379	$ 556.5	$ 451.4
AEP Texas
Restricted Cash and Cash Equivalents Items [Line Items]
Cash and Cash Equivalents	0.1	0.1
Restricted Cash	23.5	34
Total Cash, Cash Equivalents and Restricted Cash	23.6	34.1	32.8	30.5
APCo
Restricted Cash and Cash Equivalents Items [Line Items]
Cash and Cash Equivalents	3.9	5
Restricted Cash	16.2	14.9
Total Cash, Cash Equivalents and Restricted Cash	20.1	19.9	21.9	20.1
SWEPCo
Restricted Cash and Cash Equivalents Items [Line Items]
Cash and Cash Equivalents	1.2	2.4
Restricted Cash	3.4	0
Total Cash, Cash Equivalents and Restricted Cash	$ 4.6	$ 2.4	$ 88.4	$ 51.2

ORGANIZATION AND SUMMARY OF S_6

ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Concentrations of Credit Risk and Significant Customers (Details) - Customer Concentration Risk	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Revenue | AEP Subsidiaries
Concentration Risk [Line Items]
Percentage of Significant Customers Concentration Risk	80%	79%	79%
Revenue | AEP TEXAS INC. | NRG Energy and TXU Energy
Concentration Risk [Line Items]
Percentage of Significant Customers Concentration Risk	40%	41%	45%
Accounts Receivable | AEP Subsidiaries
Concentration Risk [Line Items]
Percentage of Significant Customers Concentration Risk	69%	60%	72%
Accounts Receivable | AEP TEXAS INC. | NRG Energy and TXU Energy
Concentration Risk [Line Items]
Percentage of Significant Customers Concentration Risk	37%	34%	42%

ORGANIZATION AND SUMMARY OF S_7

ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Current Target Asset Allocations (Details)	Dec. 31, 2024
Equity | Pension Plans
Defined Benefit Plan, Plan Assets, Allocation [Line Items]
Target	35%
Equity | OPEB
Defined Benefit Plan, Plan Assets, Allocation [Line Items]
Target	67%
Fixed Income | Pension Plans
Defined Benefit Plan, Plan Assets, Allocation [Line Items]
Target	49%
Fixed Income | OPEB
Defined Benefit Plan, Plan Assets, Allocation [Line Items]
Target	32%
Other Investments | Pension Plans
Defined Benefit Plan, Plan Assets, Allocation [Line Items]
Target	15%
Cash and Cash Equivalents | Pension Plans
Defined Benefit Plan, Plan Assets, Allocation [Line Items]
Target	1%
Cash and Cash Equivalents | OPEB
Defined Benefit Plan, Plan Assets, Allocation [Line Items]
Target	1%

ORGANIZATION AND SUMMARY OF S_8

ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Earnings Per Share (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Accounting Policies [Abstract]
Earnings Attributable to AEP Common Shareholders	$ 2,967.1	$ 2,208.1	$ 2,307.2
Earnings Attributable to AEP Common Shareholders	$ 2,967.1	$ 2,208.1	$ 2,307.2
WEIGHTED AVERAGE NUMBER OF BASIC AEP COMMON SHARES OUTSTANDING (in shares)	530,092,672	518,903,682	511,841,946
Weighted-Average Number of Basic AEP Common Shares Outstanding (in USD per share)	$ 5.60	$ 4.26	$ 4.51
Weighted-Average Dilutive Effect of Stock-Based Awards	1,200,000	1,300,000	1,700,000
Weighted-Average Dilutive Effect of Stock-Based Awards (in USD per share)	$ (0.02)	$ (0.02)	$ (0.02)
Weighted-Average Number of Diluted AEP Common Shares Outstanding	531,300,000	520,200,000	513,500,000
Weighted-Average Number of Diluted AEP Common Shares Outstanding (in USD per share)	$ 5.58	$ 4.24	$ 4.49

ORGANIZATION AND SUMMARY OF S_9

ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Depreciation and Amortization (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation and Amortization of Property, Plant and Equipment	$ 3,148.6	$ 2,927.5	$ 3,072.8
Amortization of Certain Securitized Assets	91.3	91.9	93.3
Amortization of Regulatory Assets and Liabilities	50	71	36.7
Depreciation and Amortization	3,289.9	3,090.4	3,202.8
AEP Texas
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation and Amortization of Property, Plant and Equipment	405.9	380	363.5
Amortization of Certain Securitized Assets	91.3	91.9	93.3
Amortization of Regulatory Assets and Liabilities	(3.7)	(3.4)	(4.4)
Depreciation and Amortization	493.5	468.5	452.4
AEPTCo
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation and Amortization of Property, Plant and Equipment	430.9	393.8	346.2
Amortization of Certain Securitized Assets	0	0	0
Amortization of Regulatory Assets and Liabilities	0	0	0
Depreciation and Amortization	430.9	393.8	346.2
APCo
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation and Amortization of Property, Plant and Equipment	600.4	571.1	576.1
Amortization of Certain Securitized Assets	0	0	0
Amortization of Regulatory Assets and Liabilities	2	0.8	(0.2)
Depreciation and Amortization	602.4	571.9	575.9
I&M
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation and Amortization of Property, Plant and Equipment	456.2	439.8	511.9
Amortization of Certain Securitized Assets	0	0	0
Amortization of Regulatory Assets and Liabilities	24.9	30.2	15.3
Depreciation and Amortization	481.1	470	527.2
OPCo
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation and Amortization of Property, Plant and Equipment	386	315.8	293.1
Amortization of Certain Securitized Assets	0	0	0
Amortization of Regulatory Assets and Liabilities	0	0.4	1.2
Depreciation and Amortization	386	316.2	294.3
PSO
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation and Amortization of Property, Plant and Equipment	263.1	240.3	226.2
Amortization of Certain Securitized Assets	0	0	0
Amortization of Regulatory Assets and Liabilities	9.1	15.2	3.9
Depreciation and Amortization	272.2	255.5	230.1
SWEPCo
Public Utility, Property, Plant and Equipment [Line Items]
Depreciation and Amortization of Property, Plant and Equipment	375.4	323.4	319.3
Amortization of Certain Securitized Assets	0	0	0
Amortization of Regulatory Assets and Liabilities	13.9	19.4	5.5
Depreciation and Amortization	$ 389.3	$ 342.8	$ 324.8

ORGANIZATION AND SUMMARY OF _10

ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Supplementary Cash Flow Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Cash Paid (Received) for:
Interest, Net of Capitalized Amounts	$ 1,837.8	$ 1,673.5	$ 1,286.3
Income Taxes	133.4	78.4	116.8
Sale of Transferable Tax Credits	(202)	(102)	0
Noncash Investing and Financing Activities:
Acquisitions Under Finance Leases	29.5	48.7	31.8
Construction Expenditures Included in Current Liabilities as of December 31,	1,312	842.4	1,258.9
Acquisition of Nuclear Fuel Included in Current Liabilities as of December 31,	23.5	24.2	0
Noncash Increase in Noncurrent Assets from the Sale of the Competitive Contracted Renewables Portfolio	$ 0	$ 74.7	$ 0

COMPREHENSIVE INCOME - Schedule

COMPREHENSIVE INCOME - Schedule of Comprehensive Income (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	$ 25,285.9	$ 24,122.4	$ 22,680.2
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)	52.4	(139.2)	(101.1)
Ending balance	26,986.1	25,285.9	24,122.4
Total
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(55.5)	83.7	184.8
Change in Fair Value Recognized in AOCI, Net of Tax	50.6	(198.5)	340.3
Amount of (Gain) Loss Reclassified from AOCI	2.2	53.8	(537.7)
Income Tax (Expense) Benefit	0.4	11.2	(113)
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit	1.8	42.6	(424.7)
Reclassifications of KPCo Pension and OPEB Regulatory Assets to 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 to AOCI, Net of Income Tax (Expense) Benefit		16.7	(16.7)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)	52.4	(139.2)	(101.1)
Ending balance	(3.1)	(55.5)	83.7
Cash Flow Hedges | Revenues
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amount of (Gain) Loss Reclassified from AOCI			0.1
Cash Flow Hedges | Purchased Electricity, Fuel and Other Consumables Used for Electric Generation
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amount of (Gain) Loss Reclassified from AOCI			(528.6)
Pension and OPEB Amortization of Deferred Costs
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	92.6	105.2	115.6
Change in Fair Value Recognized in AOCI, Net of Tax	0	0	0
Amount of (Gain) Loss Reclassified from AOCI	8.1	(16)	(13.2)
Income Tax (Expense) Benefit	1.7	(3.4)	(2.8)
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit	6.4	(12.6)	(10.4)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)	6.4	(12.6)	(10.4)
Ending balance	99	92.6	105.2
Amortization of Prior Service Cost (Credit)
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amount of (Gain) Loss Reclassified from AOCI	(5.4)	(21.2)	(21.8)
Amortization of Actuarial (Gains) Losses
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amount of (Gain) Loss Reclassified from AOCI	2.2	5.2	8.6
Recognition of Pension Settlement Costs
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amount of (Gain) Loss Reclassified from AOCI	11.3
Pension and OPEB Changes in Funded Status
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(244.9)	(245.3)	(73.2)
Change in Fair Value Recognized in AOCI, Net of Tax	41	(16.3)	(155.4)
Reclassifications of KPCo Pension and OPEB Regulatory Assets to 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 to AOCI, Net of Income Tax (Expense) Benefit		16.7	(16.7)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)	41	0.4	(172.1)
Ending balance	(203.9)	(244.9)	(245.3)
Commodity | Cash Flow Hedges
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	104.9	223.5	163.7
Change in Fair Value Recognized in AOCI, Net of Tax	2.5	(175.8)	477.3
Amount of (Gain) Loss Reclassified from AOCI	(11.2)	72.2	(528.5)
Income Tax (Expense) Benefit	(2.3)	15	(111)
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit	(8.9)	57.2	(417.5)
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)	(6.4)	(118.6)	59.8
Ending balance	98.5	104.9	223.5
Commodity | Cash Flow Hedges | Revenues
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amount of (Gain) Loss Reclassified from AOCI			0.1
Commodity | Cash Flow Hedges | Purchased Electricity, Fuel and Other Consumables Used for Electric Generation
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Amount of (Gain) Loss Reclassified from AOCI			(528.6)
Interest Rate on Long-term Debt (USD) | Cash Flow Hedges
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance	(8.1)	0.3	(21.3)
Change in Fair Value Recognized in AOCI, Net of Tax	7.1	(6.4)	18.4
Amount of (Gain) Loss Reclassified from AOCI	5.3	(2.4)	4
Income Tax (Expense) Benefit	1	(0.4)	0.8
Reclassifications from AOCI, Net of Income Tax (Expense) Benefit	4.3	(2)	3.2
TOTAL OTHER COMPREHENSIVE INCOME (LOSS)	11.4	(8.4)	21.6
Ending balance	$ 3.3	$ (8.1)	$ 0.3

RATE MATTERS - AEP Texas Rate M

RATE MATTERS - AEP Texas Rate Matters (Details) - 2024 AEP Texas Base Rate Case - AEP TEXAS INC. - USD ($) $ in Millions	1 Months Ended
	Jul. 31, 2024	Feb. 29, 2024
Public Utilities, General Disclosures [Line Items]
Requested annual base rate increase		$ 164
Requested return on equity		10.60%
Requested debt capital structure		55%
Requested equity capital structure		45%
Approved annual base rate increase	$ 70
Approved return on equity	9.76%
Approved debt capital structure	57.50%
Approved equity capital structure	42.50%

RATE MATTERS - APCo and WPCo Ra

RATE MATTERS - APCo and WPCo Rate Matters (Details) - APPALACHIAN POWER COMPANY customer in Thousands, $ in Millions	1 Months Ended						12 Months Ended
	Nov. 30, 2024 USD ($) consecutiveYear	Sep. 30, 2024 USD ($) customer	Aug. 31, 2024 USD ($)	Apr. 30, 2024 USD ($)	Mar. 31, 2024 USD ($)	Jan. 31, 2024 USD ($)	Dec. 31, 2024 USD ($)	Jan. 31, 2025 USD ($)	Feb. 29, 2024 USD ($)
Public Utilities, General Disclosures [Line Items]
Public utilities, customer outages | customer		260
Incremental other operation and maintenance expenses							$ 98
Virginia
Public Utilities, General Disclosures [Line Items]
Incremental other operation and maintenance expenses							72
West Virginia
Public Utilities, General Disclosures [Line Items]
Incremental other operation and maintenance expenses							$ 26
ENEC Filing
Public Utilities, General Disclosures [Line Items]
Under recovered costs disallowance						$ 232			$ 232
Approved recovery under recovered costs				$ 321		$ 321
Approved carrying charges				4%		4%
Approved carrying charges, recovery period				10 years		10 years
Requested annual base rate increase				$ 58
ENEC Filing | Period ending February 29, 2024
Public Utilities, General Disclosures [Line Items]
Requested annual base rate increase				20
Approved annual base rate increase			$ 20
ENEC Filing | Period September 2024 through August 2025
Public Utilities, General Disclosures [Line Items]
Requested annual base rate increase				$ 38
Approved annual base rate increase			$ 38
ENEC Filing | APCo Portion
Public Utilities, General Disclosures [Line Items]
Under recovered costs disallowance						$ 136
Approved recovery under recovered costs						$ 174
Virginia Fuel Adjustment Clause | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Under recovered costs disallowance								$ 20
2024 Virginia Base Rate Case
Public Utilities, General Disclosures [Line Items]
Requested annual base rate increase		$ 64			$ 95
Approved annual base rate increase	$ 10
Requested return on equity					10.80%
Requested debt capital structure					51%
Requested equity capital structure					49%
Approved return on equity	9.75%
2024 Virginia Base Rate Case, Environmental Compliance Consumable Expenses
Public Utilities, General Disclosures [Line Items]
Requested annual base rate increase		$ 45
2024 West Virginia Base Rate Case
Public Utilities, General Disclosures [Line Items]
Requested annual base rate increase	$ 251
Requested return on equity	10.80%
Requested debt capital structure	52%
Requested equity capital structure	48%
Modified Rate Base Cost
Public Utilities, General Disclosures [Line Items]
Requested annual base rate increase	$ 94
Mitchell Base Rate Surcharge
Public Utilities, General Disclosures [Line Items]
Approved recovery under recovered costs	118
Requested annual base rate increase	21
Regulatory assets expected to be recovered through securitization	2,400
Requested annual increase without securitization	$ 37
Annual increase april 1st surcharge	3%
Annual increase, surcharges, number of consecutive years | consecutiveYear	4
Annual increase april 1st surcharge, proposed filing period	4 years
West Virginia Modified Rate Base Cost
Public Utilities, General Disclosures [Line Items]
Requested annual base rate increase					$ 32

RATE MATTERS - ETT Rate Matters

RATE MATTERS - ETT Rate Matters (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Jan. 31, 2025	Dec. 31, 2024
ETT Interim Transmission Rates
Public Utilities, General Disclosures [Line Items]
Parent ownership interest in ett		50%
Aep share of ett cumulative revenues subject to review		$ 1,800
2025 ETT Base Rate Case | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Requested annual base rate increase	$ 57
Requested return on equity	10.60%
Requested debt capital structure	55%
Requested equity capital structure	45%

RATE MATTERS - I&M Rate Matters

RATE MATTERS - I&M Rate Matters (Details) - INDIANA MICHIGAN POWER COMPANY - USD ($) $ in Millions	1 Months Ended
	Jan. 31, 2025	Jul. 31, 2024	Mar. 31, 2024	Dec. 31, 2023	Sep. 30, 2023	Aug. 31, 2023	Nov. 30, 2024
Public Utilities, General Disclosures [Line Items]
Earning test, over-earning credit to customers							$ 18
Subsequent Event
Public Utilities, General Disclosures [Line Items]
Earning test, over-earning credit to customers, proposed	$ 21
2023 Michigan Power Supply Cost Recovery | Minimum
Public Utilities, General Disclosures [Line Items]
Public utilities, recommended disallowance purchased power			$ 3
2023 Michigan Power Supply Cost Recovery | Maximum
Public Utilities, General Disclosures [Line Items]
Public utilities, recommended disallowance purchased power			$ 15
2023 Indiana Base Rate Case
Public Utilities, General Disclosures [Line Items]
Requested annual increase						$ 116
Requested return on equity						10.50%
Requested debt capital structure						48.80%
Requested equity capital structure						51.20%
Amount of increased depreciation expense requested						$ 41
Requested deferred storm costs						$ 15
Settlement agreement annual increase step one				$ 28
Settlement agreement annual increase step two				$ 34
Settlement agreement return on common equity				9.85%
Settlement agreement equity capital structure				50%
Settlement agreement debt capital structure				50%
Settlement agreement adjusted equity capital structure				51.20%
Settlement agreement increase related to depreciation expense				$ 25
Settlement agreement increase related to storm expense				$ 11
2023 Indiana Base Rate Case | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Approved annual base rate increase	$ 15
2023 Michigan Base Rate Case
Public Utilities, General Disclosures [Line Items]
Requested annual increase					$ 34
Requested return on equity					10.50%
Requested debt capital structure					49.40%
Requested equity capital structure					50.60%
Amount of increased depreciation expense requested					$ 11
Approved annual base rate increase		$ 17
Approved return on equity		9.86%
Approved debt capital structure		52%
Approved equity capital structure		48%

RATE MATTERS - KPCo Rate Matter

RATE MATTERS - KPCo Rate Matters (Details) - USD ($) $ in Millions	1 Months Ended								12 Months Ended
	Jan. 31, 2025	Nov. 30, 2024	Feb. 29, 2024	Feb. 26, 2024	Jan. 31, 2024	Dec. 31, 2023	Nov. 30, 2023	Jun. 30, 2023	Dec. 31, 2023	Dec. 31, 2024
Public Utilities, General Disclosures [Line Items]
Property, plant and equipment, net						$ 564.3			$ 564.3	$ 714.9
2023 Kentucky Base Rate and Securitization Case | KPCo
Public Utilities, General Disclosures [Line Items]
Requested annual increase								$ 94
Requested return on equity								9.90%
Requested securitization bonds regulatory assets recovery								$ 471
Kpco interest in mitchell plant								50%
Property, plant and equipment, net										$ 547
Settlement agreement annual increase							$ 75
Settlement agreement return on common equity							9.75%
Settlement agreement securitization bonds regulatory assets recovery							$ 471
Approved net increase in Kentucky annual revenues					$ 60
Approved return on equity					9.75%
Reduction in revenue requirement for recovery of actual test year pjm transmission costs				$ 14	$ 14
Regulatory assets expected to be recovered through securitization					491
Securitized plant retirement costs					303
Securitized deferred storm costs					79
Securitized purchased power expenses					50
Securitized under recovered rider costs					57
Securitized deferred issuance related expenses					2
2023 Kentucky Base Rate and Securitization Case | KPCo | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Reduction in revenue requirement for recovery of actual test year pjm transmission costs	$ 14
Order entered in mandated period	30 days
Fuel Adjustment Clause Review | KPCo
Public Utilities, General Disclosures [Line Items]
Review period						2 years
Purchased power cost recoveries						$ 432
Customer rate credits		$ 17
Fuel Adjustment Clause Review | KPCo | Minimum
Public Utilities, General Disclosures [Line Items]
Recommended disallowance from staff or intervenors						44
Fuel Adjustment Clause Review | KPCo | Maximum
Public Utilities, General Disclosures [Line Items]
Recommended disallowance from staff or intervenors						$ 60
Rockport Offset Recovery | KPCo
Public Utilities, General Disclosures [Line Items]
Requested recovery of allowed costs					$ 41
Estimated allowed costs recovered through rider			$ 18						$ 23

RATE MATTERS - OPCo Rate Matter

RATE MATTERS - OPCo Rate Matters (Details) - Ohio ESP Filings	1 Months Ended
	Sep. 30, 2023	Jan. 31, 2023
OHIO POWER COMPANY
Public Utilities, General Disclosures [Line Items]
Proposed esp return on common equity		10.65%
KPCo
Public Utilities, General Disclosures [Line Items]
Settlement term	4 years
Approved return on equity	9.70%

RATE MATTERS - PSO Rate Matters

RATE MATTERS - PSO Rate Matters (Details) - 2024 Oklahoma Base Rate Case - PUBLIC SERVICE COMPANY OF OKLAHOMA $ in Millions	1 Months Ended
	Oct. 31, 2024 USD ($)	Jan. 31, 2024 USD ($) MW
Public Utilities, General Disclosures [Line Items]
Requested net increase in oklahoma annual revenues		$ 218
Requested return on equity		10.80%
Requested debt capital structure		48.90%
Requested equity capital structure		51.10%
Wind generation MW | MW		155
Settlement agreement annual increase	$ 120
Settlement agreement return on common equity	9.50%
Settlement agreement debt capital structure	48.90%
Settlement agreement equity capital structure	51.10%
Interim annual base rate increase	$ 120

RATE MATTERS - SWEPCo Rate Matt

RATE MATTERS - SWEPCo Rate Matters (Details) $ in Millions

1 Months Ended

3 Months Ended

12 Months Ended

Jan. 31, 2025 USD ($)

Oct. 31, 2024 USD ($)

Jun. 30, 2024 USD ($)

Apr. 30, 2024 USD ($)

Jun. 30, 2023 USD ($)

Mar. 31, 2023 USD ($)

Jan. 31, 2022 USD ($)

Oct. 31, 2020 USD ($)

Jan. 31, 2018 USD ($)

Jun. 30, 2024 USD ($)

Dec. 31, 2023 USD ($)

Dec. 31, 2021 USD ($)

Dec. 31, 2017 USD ($)

Dec. 31, 2016 USD ($)

Dec. 31, 2013 USD ($)

Dec. 31, 2024 USD ($) MW

Mar. 31, 2024 USD ($)

Securitization Bonds

Public Utilities, General Disclosures [Line Items]

Securitization Bonds

$ 368.9

$ 578

SOUTHWESTERN ELECTRIC POWER COMPANY

Public Utilities, General Disclosures [Line Items]

Storm related expense

$ 44

Disallowance of fuel costs

$ 535

SOUTHWESTERN ELECTRIC POWER COMPANY | Turk Generating Plant

Public Utilities, General Disclosures [Line Items]

Public utilities, base load | MW

600

Public utilities, net maximum capacity | MW

650

Public utilities, percentage of ownership

73%

Public utilities, net book value

$ 1,300

Public utilities, percentage not subject to cost-based rate recovery

20%

Public utilities, percentage subject to cost-based rate recovery

80%

Public utilities, favorable impact

$ 32

SOUTHWESTERN ELECTRIC POWER COMPANY | Securitization Bonds

Public Utilities, General Disclosures [Line Items]

Securitization Bonds

0

$ 331.4

SOUTHWESTERN ELECTRIC POWER COMPANY | Securitization Bonds | Hurricane

Public Utilities, General Disclosures [Line Items]

Securitization Bonds

337

Debt issuance costs, gross

7

SOUTHWESTERN ELECTRIC POWER COMPANY | Securitization Bonds | Hurricane Laura And Delta

Public Utilities, General Disclosures [Line Items]

Securitization Bonds

180

SOUTHWESTERN ELECTRIC POWER COMPANY | Securitization Bonds | Catastrophe Storm Reserve

Public Utilities, General Disclosures [Line Items]

Securitization Bonds

$ 150

$ 150

SOUTHWESTERN ELECTRIC POWER COMPANY | Minimum | Subsequent Event

Public Utilities, General Disclosures [Line Items]

Disallowance of fuel costs

$ 2

SOUTHWESTERN ELECTRIC POWER COMPANY | Minimum | Turk Generating Plant

Public Utilities, General Disclosures [Line Items]

Public utilities, production amount | MW

440

SOUTHWESTERN ELECTRIC POWER COMPANY | Maximum | Subsequent Event

Public Utilities, General Disclosures [Line Items]

Disallowance of fuel costs

$ 25

SOUTHWESTERN ELECTRIC POWER COMPANY | Maximum | Turk Generating Plant

Public Utilities, General Disclosures [Line Items]

Public utilities, production amount | MW

477

2012 Texas Base Rate Case | SOUTHWESTERN ELECTRIC POWER COMPANY

Public Utilities, General Disclosures [Line Items]

2013 reversal of previously recorded regulatory disallowances

$ 114

Turk afudc disallowance

$ 86

Revenue refund provision

$ 160

Estimated turk afudc refunds, period

2 years

Estimated turk afudc refunds

$ 148

2012 Texas Base Rate Case | SOUTHWESTERN ELECTRIC POWER COMPANY | Minimum

Public Utilities, General Disclosures [Line Items]

Recommended customer refunds

$ 149

Recommended refund period

18 months

2012 Texas Base Rate Case | SOUTHWESTERN ELECTRIC POWER COMPANY | Maximum

Public Utilities, General Disclosures [Line Items]

Recommended customer refunds

$ 197

Recommended refund period

48 months

2016 Texas Base Rate Case | SOUTHWESTERN ELECTRIC POWER COMPANY

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 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 | SOUTHWESTERN ELECTRIC POWER COMPANY

Public Utilities, General Disclosures [Line Items]

Approved return on equity

9.25%

Impairment charge total

$ 12

Requested annual increase

$ 105

Requested return on equity

10.35%

Requested net annual increase

$ 90

Revised requested annual increase

100

Revised requested net annual increase

$ 85

Approved annual revenue increase

$ 39

Amount of approved increase related to vegetation management

5

Amount of approved increase related to storm catastrophe reserve

$ 2

2021 Louisiana Storm Cost Filing | SOUTHWESTERN ELECTRIC POWER COMPANY

Public Utilities, General Disclosures [Line Items]

Approved deferred storm costs

$ 150

Interim WACC

3.125%

RATE MATTERS - February 2021 Se

RATE MATTERS - February 2021 Severe Winter Weather Impacts in SPP (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Mar. 31, 2021
Public Utilities, General Disclosures [Line Items]
Total Noncurrent Regulatory Assets	$ 5,129.2	$ 5,092.4
SOUTHWESTERN ELECTRIC POWER COMPANY
Public Utilities, General Disclosures [Line Items]
Total Noncurrent Regulatory Assets	921.3	1,131.8
February 2021 Severe Storm Fuel Costs | SOUTHWESTERN ELECTRIC POWER COMPANY
Public Utilities, General Disclosures [Line Items]
Total Noncurrent Regulatory Assets	180.5	253.3
February 2021 Severe Storm Fuel Costs | Arkansas | SOUTHWESTERN ELECTRIC POWER COMPANY
Public Utilities, General Disclosures [Line Items]
Total Noncurrent Regulatory Assets	$ 37.2	54.2
Remaining Recovery Period	6 years
February 2021 Severe Storm Fuel Costs | Louisiana | SOUTHWESTERN ELECTRIC POWER COMPANY
Public Utilities, General Disclosures [Line Items]
Total Noncurrent Regulatory Assets	$ 70.6	97.2
Remaining Recovery Period			5 years
February 2021 Severe Storm Fuel Costs | Texas | SOUTHWESTERN ELECTRIC POWER COMPANY
Public Utilities, General Disclosures [Line Items]
Total Noncurrent Regulatory Assets	$ 72.7	$ 101.9
Remaining Recovery Period	5 years
Approved Carrying Charge	1.65%

RATE MATTERS - PSO and SWEPCo R

RATE MATTERS - PSO and SWEPCo Rate Matters (Details) - North Central Wind Energy Facilities	1 Months Ended	12 Months Ended
	Apr. 30, 2022	Dec. 31, 2024
Public Utilities, General Disclosures [Line Items]
Net capacity factor guarantee, measurement period started		5 years
Net capacity factor guarantee, full period under coverage		30 years
Net capacity factor guarantee, measurement period, first start period	5 years

RATE MATTERS - FERC Rate Matter

RATE MATTERS - FERC Rate Matters (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Oct. 31, 2023	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021	Oct. 31, 2022
Independence Energy Connection Project
Public Utilities, General Disclosures [Line Items]
Aep share of independence energy connection capital costs		$ 96
Request to Update AEGCo Depreciation Rates
Public Utilities, General Disclosures [Line Items]
Proposed revision, deprecation rates, ownership interests						50%
FERC 2021 PJM and SPP Transmission Formula Rate Challenge
Public Utilities, General Disclosures [Line Items]
Stand alone treatment of nolcs annual revenue increase		$ 52	$ 61	$ 69	$ 78
Request to Update SWEPCo Generation Depreciation Rates
Public Utilities, General Disclosures [Line Items]
Requested annual revenue requirement	$ 5

EFFECTS OF REGULATION - Narrati

EFFECTS OF REGULATION - Narrative (Details) - USD ($) $ in Millions

1 Months Ended

3 Months Ended

12 Months Ended

Jan. 31, 2025

Nov. 30, 2024

Jun. 30, 2024

Apr. 30, 2024

Feb. 29, 2024

Sep. 30, 2023

Aug. 31, 2022

Mar. 31, 2021

Mar. 31, 2024

Jun. 30, 2022

Dec. 31, 2024

Dec. 31, 2023

Dec. 31, 2022

Dec. 31, 2021

Public Utilities, General Disclosures [Line Items]

Disallowance amount

$ 142.5

$ 85.6

$ 48.8

SOUTHWESTERN ELECTRIC POWER COMPANY

Public Utilities, General Disclosures [Line Items]

Disallowance amount

0

$ 85.6

$ 0

Disallowance of fuel costs

$ 535

SOUTHWESTERN ELECTRIC POWER COMPANY | Subsequent Event | Minimum

Public Utilities, General Disclosures [Line Items]

Disallowance of fuel costs

$ 2

SOUTHWESTERN ELECTRIC POWER COMPANY | Subsequent Event | Maximum

Public Utilities, General Disclosures [Line Items]

Disallowance of fuel costs

25

SOUTHWESTERN ELECTRIC POWER COMPANY | Dolet Hills Power Station | Texas

Public Utilities, General Disclosures [Line Items]

Disallowance amount

$ 12

SOUTHWESTERN ELECTRIC POWER COMPANY | Dolet Hills Power Station | Arkansas

Public Utilities, General Disclosures [Line Items]

Disallowance amount

$ 2

SOUTHWESTERN ELECTRIC POWER COMPANY | Dolet Hills Power Station | Louisiana

Public Utilities, General Disclosures [Line Items]

Disallowance amount

$ 14

SOUTHWESTERN ELECTRIC POWER COMPANY | Pirkey Station | Texas

Public Utilities, General Disclosures [Line Items]

Net book value

69

SOUTHWESTERN ELECTRIC POWER COMPANY | Dolet Hills Generating Station and Related Fuel Operations

Public Utilities, General Disclosures [Line Items]

Percentage of fuel supply provided

100%

Net investment

74

Net under-recovered fuel costs

22

SOUTHWESTERN ELECTRIC POWER COMPANY | Dolet Hills Generating Station and Related Fuel Operations | Texas

Public Utilities, General Disclosures [Line Items]

Recovery of fuel costs

$ 48

SOUTHWESTERN ELECTRIC POWER COMPANY | Dolet Hills Generating Station and Related Fuel Operations | Arkansas

Public Utilities, General Disclosures [Line Items]

Recovery of fuel costs

$ 20

Recovery of fuel costs, period

5 years

SOUTHWESTERN ELECTRIC POWER COMPANY | Dolet Hills Generating Station and Related Fuel Operations | Louisiana

Public Utilities, General Disclosures [Line Items]

Recovery of fuel costs

$ 20

Recovery of fuel costs, deferred

$ 35

Fuel disallowance

$ 55

Fuel disallowance, deferral

$ 35

Refund to customer period

5 years

Refund to customer, proposed

$ 55

Deferral, denial of recovery

$ 35

Disallowance of fuel costs

$ 11

Regulatory asset

$ 24

Regulatory asset, recovery period

3 years

SOUTHWESTERN ELECTRIC POWER COMPANY | Pirkey Power Plant and Related Fuel Operations

Public Utilities, General Disclosures [Line Items]

Net investment

$ 188

Net under-recovered fuel costs

$ 22

Fuel disallowance

$ 5

SOUTHWESTERN ELECTRIC POWER COMPANY | Pirkey Power Plant and Related Fuel Operations | Texas

Public Utilities, General Disclosures [Line Items]

Recovery of fuel costs

$ 33

SOUTHWESTERN ELECTRIC POWER COMPANY | Pirkey Power Plant and Related Fuel Operations | Texas | Subsequent Event | Minimum

Public Utilities, General Disclosures [Line Items]

Fuel disallowance

2

SOUTHWESTERN ELECTRIC POWER COMPANY | Pirkey Power Plant and Related Fuel Operations | Texas | Subsequent Event | Maximum

Public Utilities, General Disclosures [Line Items]

Fuel disallowance

$ 25

EFFECTS OF REGULATION - Regulat

EFFECTS OF REGULATION - Regulatory Asset, Early Retirement (Details) - Generating Units Probable of Abandonment $ in Millions	12 Months Ended
	Dec. 31, 2024 USD ($)
Northeastern Plant, Unit 3 | PUBLIC SERVICE COMPANY OF OKLAHOMA
Public Utilities, General Disclosures [Line Items]
Net Book Value	$ 101.7
Accelerated Depreciation Regulatory Asset	189
Cost of Removal Regulatory Liability	21
Annual Depreciation	16.2
Welsh Plant, Units 1 and 3 | SOUTHWESTERN ELECTRIC POWER COMPANY
Public Utilities, General Disclosures [Line Items]
Net Book Value	324.3
Accelerated Depreciation Regulatory Asset	168.6
Cost of Removal Regulatory Liability	57.6
Annual Depreciation	$ 43.6

EFFECTS OF REGULATION - Regul_2

EFFECTS OF REGULATION - Regulatory Asset (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Regulatory Asset [Line Items]
Total Current Regulatory Assets	$ 445.9	$ 514
Total Noncurrent Regulatory Assets	5,129.2	5,092.4
Regulatory Liabilities and Deferred Investment Tax Credits	8,344	8,182.4
PUBLIC SERVICE COMPANY OF OKLAHOMA
Regulatory Asset [Line Items]
Total Current Regulatory Assets	64.7	118.3
Total Noncurrent Regulatory Assets	527.8	522.7
Regulatory Liabilities and Deferred Investment Tax Credits	689.7	765.6
Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	1,310.8	837.3
Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	3,818.4	4,255.1
Approved for recovery | PUBLIC SERVICE COMPANY OF OKLAHOMA
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	497.5	434
Earns/earning a return | Under-recovered Fuel Costs
Regulatory Asset [Line Items]
Total Current Regulatory Assets	$ 245.7	357.4
Remaining Recovery Period	1 year
Earns/earning a return | Under-recovered Fuel Costs | PUBLIC SERVICE COMPANY OF OKLAHOMA
Regulatory Asset [Line Items]
Total Current Regulatory Assets	$ 64.7	118.3
Remaining Recovery Period	1 year
Earns/earning a return | Unrecovered Winter Storm Fuel Costs
Regulatory Asset [Line Items]
Total Current Regulatory Assets	$ 84.2	93.9
Remaining Recovery Period	1 year
Earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 395.1	349.9
Earns/earning a return | Pending final regulatory approval | Unrecovered Winter Storm Fuel Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	33.5	60.1
Earns/earning a return | Pending final regulatory approval | Welsh Plant, Units 1 and 3 Accelerated Depreciation
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	168.6	125.6
Earns/earning a return | Pending final regulatory approval | Pirkey Plant Accelerated Depreciation
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	121.3	114.4
Earns/earning a return | Pending final regulatory approval | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	51	0
Earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	20.7	49.8
Earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	1,711.5	1,946.9
Earns/earning a return | Approved for recovery | PUBLIC SERVICE COMPANY OF OKLAHOMA
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 425.4	325.3
Earns/earning a return | Approved for recovery | Unrecovered Winter Storm Fuel Costs
Regulatory Asset [Line Items]
Remaining Recovery Period	3 years
Total Noncurrent Regulatory Assets	$ 62.8	99.3
Earns/earning a return | Approved for recovery | Storm-Related Costs
Regulatory Asset [Line Items]
Remaining Recovery Period	7 years
Total Noncurrent Regulatory Assets	$ 106.7	170.9
Earns/earning a return | Approved for recovery | Storm-Related Costs | PUBLIC SERVICE COMPANY OF OKLAHOMA
Regulatory Asset [Line Items]
Remaining Recovery Period	7 years
Total Noncurrent Regulatory Assets	$ 106.7	26.2
Earns/earning a return | Approved for recovery | Plant Retirement Costs - Asset Retirement Obligation Costs
Regulatory Asset [Line Items]
Remaining Recovery Period	16 years
Total Noncurrent Regulatory Assets	$ 111	110.8
Earns/earning a return | Approved for recovery | Plant Retirement Costs - Unrecovered Plant
Regulatory Asset [Line Items]
Remaining Recovery Period	22 years
Total Noncurrent Regulatory Assets	$ 661.2	664.2
Earns/earning a return | Approved for recovery | Plant Retirement Costs - Unrecovered Plant | PUBLIC SERVICE COMPANY OF OKLAHOMA
Regulatory Asset [Line Items]
Remaining Recovery Period	22 years
Total Noncurrent Regulatory Assets	$ 274	254.1
Earns/earning a return | Approved for recovery | Long-term Under-recovered Fuel Costs - West Virginia
Regulatory Asset [Line Items]
Remaining Recovery Period	10 years
Total Noncurrent Regulatory Assets	$ 283.8	291.5
Earns/earning a return | Approved for recovery | Fuel Mine Closure Costs - Texas
Regulatory Asset [Line Items]
Remaining Recovery Period	11 years
Total Noncurrent Regulatory Assets	$ 70.6	74.3
Earns/earning a return | Approved for recovery | Pirkey Plant Accelerated Depreciation - Louisiana
Regulatory Asset [Line Items]
Remaining Recovery Period	8 years
Total Noncurrent Regulatory Assets	$ 66.4	65.8
Earns/earning a return | Approved for recovery | Kentucky Deferred Purchased Power Expenses
Regulatory Asset [Line Items]
Remaining Recovery Period	3 years
Total Noncurrent Regulatory Assets	$ 45	43.5
Earns/earning a return | Approved for recovery | Rockport Plant Dry Sorbent Injection System and Selective Catalytic Reduction
Regulatory Asset [Line Items]
Remaining Recovery Period	4 years
Total Noncurrent Regulatory Assets	$ 37.3	46.9
Earns/earning a return | Approved for recovery | Texas Mobile Temporary Emergency Electric Energy Facilities Rider
Regulatory Asset [Line Items]
Remaining Recovery Period	2 years
Total Noncurrent Regulatory Assets	$ 32.6	33.4
Earns/earning a return | Approved for recovery | Environmental Control Projects
Regulatory Asset [Line Items]
Remaining Recovery Period	16 years
Total Noncurrent Regulatory Assets	$ 29.1	31.4
Earns/earning a return | Approved for recovery | Environmental Control Projects | PUBLIC SERVICE COMPANY OF OKLAHOMA
Regulatory Asset [Line Items]
Remaining Recovery Period	16 years
Total Noncurrent Regulatory Assets	$ 21.2	22.5
Earns/earning a return | Approved for recovery | Ohio Basic Transmission Cost Rider
Regulatory Asset [Line Items]
Remaining Recovery Period	2 years
Total Noncurrent Regulatory Assets	$ 26.1	42.2
Earns/earning a return | Approved for recovery | Plant Retirement Costs - Unrecovered Plant, Dolet Hills Power Station, Louisiana
Regulatory Asset [Line Items]
Remaining Recovery Period	8 years
Total Noncurrent Regulatory Assets	$ 19	40.8
Earns/earning a return | Approved for recovery | Long-term Under-recovered Fuel Costs - Virginia
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	0	107
Earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	159.9	124.9
Earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery | PUBLIC SERVICE COMPANY OF OKLAHOMA
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	13.4	8.4
Does not earns/earning a return | Under-recovered Fuel Costs
Regulatory Asset [Line Items]
Total Current Regulatory Assets	$ 116	62.7
Remaining Recovery Period	1 year
Does not earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 915.7	487.4
Does not earns/earning a return | Pending final regulatory approval | PUBLIC SERVICE COMPANY OF OKLAHOMA
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	30.3	88.7
Does not earns/earning a return | Pending final regulatory approval | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	300.8	408.9
Does not earns/earning a return | Pending final regulatory approval | Storm-Related Costs | PUBLIC SERVICE COMPANY OF OKLAHOMA
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	4.9	88.5
Does not earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	86.3	52.6
Does not earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval | PUBLIC SERVICE COMPANY OF OKLAHOMA
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	9	0.2
Does not earns/earning a return | Pending final regulatory approval | Plant Retirement Costs - Asset Retirement Obligation Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	357.4	25.9
Does not earns/earning a return | Pending final regulatory approval | NOLC - Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	92.8	0
Does not earns/earning a return | Pending final regulatory approval | 2024-2025 Virginia Under-Earnings
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	78.4	0
Does not earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	2,106.9	2,308.2
Does not earns/earning a return | Approved for recovery | PUBLIC SERVICE COMPANY OF OKLAHOMA
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 72.1	108.7
Does not earns/earning a return | Approved for recovery | Storm-Related Costs
Regulatory Asset [Line Items]
Remaining Recovery Period	7 years
Total Noncurrent Regulatory Assets	$ 66.5	38.5
Does not earns/earning a return | Approved for recovery | Plant Retirement Costs - Asset Retirement Obligation Costs
Regulatory Asset [Line Items]
Remaining Recovery Period	18 years
Total Noncurrent Regulatory Assets	$ 360.1	330.2
Does not earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	240.1	269.1
Does not earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery | PUBLIC SERVICE COMPANY OF OKLAHOMA
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 10.6	16.2
Does not earns/earning a return | Approved for recovery | Pension and OPEB Funded Status
Regulatory Asset [Line Items]
Remaining Recovery Period	12 years
Total Noncurrent Regulatory Assets	$ 974.2	1,054.1
Does not earns/earning a return | Approved for recovery | Pension and OPEB Funded Status | PUBLIC SERVICE COMPANY OF OKLAHOMA
Regulatory Asset [Line Items]
Remaining Recovery Period	12 years
Total Noncurrent Regulatory Assets	$ 57.6	62.6
Does not earns/earning a return | Approved for recovery | Unamortized Loss on Reacquired Debt
Regulatory Asset [Line Items]
Remaining Recovery Period	24 years
Total Noncurrent Regulatory Assets	$ 90.9	97.2
Does not earns/earning a return | Approved for recovery | Fuel and Purchased Power Adjustment Rider
Regulatory Asset [Line Items]
Remaining Recovery Period	2 years
Total Noncurrent Regulatory Assets	$ 57.4	68.3
Does not earns/earning a return | Approved for recovery | Unrealized Loss on Forward Commitments
Regulatory Asset [Line Items]
Remaining Recovery Period	8 years
Total Noncurrent Regulatory Assets	$ 53.3	131.4
Does not earns/earning a return | Approved for recovery | Unrealized Loss on Forward Commitments | PUBLIC SERVICE COMPANY OF OKLAHOMA
Regulatory Asset [Line Items]
Remaining Recovery Period	2 years
Total Noncurrent Regulatory Assets	$ 3.9	29.9
Does not earns/earning a return | Approved for recovery | OVEC Purchased Power
Regulatory Asset [Line Items]
Remaining Recovery Period	2 years
Total Noncurrent Regulatory Assets	$ 52	50.1
Does not earns/earning a return | Approved for recovery | Plant Retirement Costs - Unrecovered Plant, Texas
Regulatory Asset [Line Items]
Remaining Recovery Period	22 years
Total Noncurrent Regulatory Assets	$ 44.5	48.7
Does not earns/earning a return | Approved for recovery | Cook Plant Nuclear Refueling Outage Levelization
Regulatory Asset [Line Items]
Remaining Recovery Period	3 years
Total Noncurrent Regulatory Assets	$ 43	55.7
Does not earns/earning a return | Approved for recovery | Smart Grid Costs
Regulatory Asset [Line Items]
Remaining Recovery Period	2 years
Total Noncurrent Regulatory Assets	$ 33.8	26.3
Does not earns/earning a return | Approved for recovery | Postemployment Benefits
Regulatory Asset [Line Items]
Remaining Recovery Period	3 years
Total Noncurrent Regulatory Assets	$ 27.9	30.6
Does not earns/earning a return | Approved for recovery | Ohio Enhanced Service Reliability Plan
Regulatory Asset [Line Items]
Remaining Recovery Period	2 years
Total Noncurrent Regulatory Assets	$ 26.2	35.3
Does not earns/earning a return | Approved for recovery | 2020-2022 Virginia Triennial Under Earnings
Regulatory Asset [Line Items]
Remaining Recovery Period	3 years
Total Noncurrent Regulatory Assets	$ 26	37.4
Does not earns/earning a return | Approved for recovery | Ohio Distribution Investment Rider
Regulatory Asset [Line Items]
Remaining Recovery Period	2 years
Total Noncurrent Regulatory Assets	$ 11	$ 35.3

EFFECTS OF REGULATION - Regul_3

EFFECTS OF REGULATION - Regulatory Liabilities (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Regulatory Liability [Line Items]
Total Current Regulatory Liabilities	$ 53.5	$ 26.5
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	8,344	8,182.4
Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	322	207.9
Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	8,022	7,974.5
Pays/paying a return | Over-recovered Fuel Costs
Regulatory Liability [Line Items]
Total Current Regulatory Liabilities	$ 21.6	3.3
Remaining Refund Period	1 year
Pays/paying a return | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 176	103.1
Pays/paying a return | Pending final regulatory determination | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	176	103.1
Pays/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	5,526.4	5,823.1
Pays/paying a return | Approved for payment | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	1,622.1	2,179.7
Regulatory liabilities, not subject to rate normalization requirements, amount	$ 192	228
Regulatory liabilities, not subject to rate normalization requirements, refund period	10 years
Pays/paying a return | Approved for payment | Asset Removal Costs
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 3,828	3,563.5
Pays/paying a return | Approved for payment | Rockport Plant, Unit 2 Accelerated Depreciation for Leasehold Improvements
Regulatory Liability [Line Items]
Remaining Refund Period	4 years
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 35.9	44.9
Pays/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	40.4	35
Does not pay/paying a return | Over-recovered Fuel Costs
Regulatory Liability [Line Items]
Total Current Regulatory Liabilities	$ 31.9	23.2
Remaining Refund Period	1 year
Does not pay/paying a return | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 146	104.8
Does not pay/paying a return | Pending final regulatory determination | FERC 2021 Transmission Formula Rate Challenge Refunds
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	131.3	103.1
Does not pay/paying a return | Pending final regulatory determination | Other Regulatory Liabilities Pending Final Regulatory Determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	14.7	1.7
Does not pay/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 2,495.6	2,151.4
Does not pay/paying a return | Approved for payment | Over-recovered Fuel Costs
Regulatory Liability [Line Items]
Remaining Refund Period	8 years
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 32.1	26.1
Does not pay/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	90.1	106.5
Does not pay/paying a return | Approved for payment | Excess Nuclear Decommissioning Funding
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 2,137.3	1,721.9
Does not pay/paying a return | Approved for payment | Deferred Investment Tax Credits
Regulatory Liability [Line Items]
Remaining Refund Period	29 years
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 65.1	154.5
Does not pay/paying a return | Approved for payment | Demand Side Management
Regulatory Liability [Line Items]
Remaining Refund Period	2 years
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 52.6	31.3
Does not pay/paying a return | Approved for payment | Spent Nuclear Fuel
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 50.4	47.6
Does not pay/paying a return | Approved for payment | 2017-2019 Virginia Triennial Revenue Provision
Regulatory Liability [Line Items]
Remaining Refund Period	25 years
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 35.2	37.1
Does not pay/paying a return | Approved for payment | Peak Demand Reduction/Energy Efficiency
Regulatory Liability [Line Items]
Remaining Refund Period	2 years
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 32.8	$ 26.4

EFFECTS OF REGULATION - Regul_4

EFFECTS OF REGULATION - Regulatory Asset - AEP Texas (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 5,129.2	$ 5,092.4
Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	1,310.8	837.3
Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	3,818.4	4,255.1
Earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	395.1	349.9
Earns/earning a return | Pending final regulatory approval | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	51	0
Earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	20.7	49.8
Earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	1,711.5	1,946.9
Earns/earning a return | Approved for recovery | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 106.7	170.9
Remaining Recovery Period	7 years
Earns/earning a return | Approved for recovery | Texas Mobile Temporary Emergency Electric Energy Facilities Rider
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 32.6	33.4
Remaining Recovery Period	2 years
Earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 159.9	124.9
Does not earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	915.7	487.4
Does not earns/earning a return | Pending final regulatory approval | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	300.8	408.9
Does not earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	86.3	52.6
Does not earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	2,106.9	2,308.2
Does not earns/earning a return | Approved for recovery | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 66.5	38.5
Remaining Recovery Period	7 years
Does not earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 240.1	269.1
Does not earns/earning a return | Approved for recovery | Pension and OPEB Funded Status
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 974.2	1,054.1
Remaining Recovery Period	12 years
AEP TEXAS INC.
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 353.6	315.3
AEP TEXAS INC. | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	77.1	64.3
AEP TEXAS INC. | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 276.5	251
AEP TEXAS INC. | Approved for recovery | Texas Transmission Cost Recovery Factor
Regulatory Asset [Line Items]
Remaining Recovery Period	2 years
AEP TEXAS INC. | Earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 41.3	0
AEP TEXAS INC. | Earns/earning a return | Pending final regulatory approval | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	41.3	0
AEP TEXAS INC. | Earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	60.8	43.5
AEP TEXAS INC. | Earns/earning a return | Approved for recovery | Texas Mobile Temporary Emergency Electric Energy Facilities Rider
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 32.6	33.4
Remaining Recovery Period	2 years
AEP TEXAS INC. | Earns/earning a return | Approved for recovery | Meter Replacement Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 5.8	9.4
Remaining Recovery Period	2 years
AEP TEXAS INC. | Earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 22.4	0.7
AEP TEXAS INC. | Does not earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	35.8	64.3
AEP TEXAS INC. | Does not earns/earning a return | Pending final regulatory approval | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	13.1	37.7
AEP TEXAS INC. | Does not earns/earning a return | Pending final regulatory approval | Deferred Pension and OPEB Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	15.6	0
AEP TEXAS INC. | Does not earns/earning a return | Pending final regulatory approval | Line Inspection Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	5.8	5.7
AEP TEXAS INC. | Does not earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	1.3	20.9
AEP TEXAS INC. | Does not earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	215.7	207.5
AEP TEXAS INC. | Does not earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	14.8	15.1
AEP TEXAS INC. | Does not earns/earning a return | Approved for recovery | Pension and OPEB Funded Status
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 177.5	183.2
Remaining Recovery Period	12 years
AEP TEXAS INC. | Does not earns/earning a return | Approved for recovery | Texas Transmission Cost Recovery Factor
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 14.2	0
AEP TEXAS INC. | Does not earns/earning a return | Approved for recovery | Peak Demand Reduction/Energy Efficiency
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 9.2	$ 9.2
Remaining Recovery Period	2 years

EFFECTS OF REGULATION - Regul_5

EFFECTS OF REGULATION - Regulatory Liabilities - AEP Texas (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Regulatory Liability [Line Items]
Total Current Regulatory Liabilities	$ 53.5	$ 26.5
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	8,344	8,182.4
Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	322	207.9
Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	8,022	7,974.5
Pays/paying a return | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	176	103.1
Pays/paying a return | Pending final regulatory determination | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	176	103.1
Pays/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	5,526.4	5,823.1
Pays/paying a return | Approved for payment | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	1,622.1	2,179.7
Regulatory liabilities, not subject to rate normalization requirements, amount	$ 192	228
Regulatory liabilities, not subject to rate normalization requirements, refund period	10 years
Pays/paying a return | Approved for payment | Asset Removal Costs
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 3,828	3,563.5
Pays/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	40.4	35
Does not pay/paying a return | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	146	104.8
Does not pay/paying a return | Pending final regulatory determination | Other Regulatory Liabilities Pending Final Regulatory Determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	14.7	1.7
Does not pay/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	2,495.6	2,151.4
Does not pay/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	90.1	106.5
AEP TEXAS INC.
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	1,285.4	1,261.4
AEP TEXAS INC. | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	0	14.5
AEP TEXAS INC. | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	1,285.4	1,246.9
AEP TEXAS INC. | Pays/paying a return | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	0	13
AEP TEXAS INC. | Pays/paying a return | Pending final regulatory determination | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	0	13
AEP TEXAS INC. | Pays/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	1,258.2	1,212.9
AEP TEXAS INC. | Pays/paying a return | Approved for payment | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	409.4	412
Regulatory liabilities, not subject to rate normalization requirements, amount	$ 22
Regulatory liabilities, not subject to rate normalization requirements, refund period	5 years
AEP TEXAS INC. | Pays/paying a return | Approved for payment | Asset Removal Costs
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 844	797.1
AEP TEXAS INC. | Pays/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	4.8	3.8
AEP TEXAS INC. | Does not pay/paying a return | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	0	1.5
AEP TEXAS INC. | Does not pay/paying a return | Pending final regulatory determination | Other Regulatory Liabilities Pending Final Regulatory Determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	0	1.5
AEP TEXAS INC. | Does not pay/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	27.2	34
AEP TEXAS INC. | Does not pay/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 5.6	7.4
AEP TEXAS INC. | Does not pay/paying a return | Approved for payment | Transition and Restoration Charges
Regulatory Liability [Line Items]
Remaining Refund Period	5 years
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 21.6	$ 26.6

EFFECTS OF REGULATION - Regul_6

EFFECTS OF REGULATION - Regulatory Asset - AEPTCO (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 5,129.2	$ 5,092.4
Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	3,818.4	4,255.1
Does not earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	2,106.9	2,308.2
AEP TRANSMISSION COMPANY, LLC
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	0.4	3.1
AEP TRANSMISSION COMPANY, LLC | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	0.4	3.1
AEP TRANSMISSION COMPANY, LLC | Does not earns/earning a return | Approved for recovery | PJM/SPP Annual Formula Rate True-up
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 0.4	$ 3.1
Remaining Recovery Period	2 years

EFFECTS OF REGULATION - Regul_7

EFFECTS OF REGULATION - Regulatory Liabilities - AEPTCo (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 8,344	$ 8,182.4
Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	322	207.9
Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	8,022	7,974.5
Pays/paying a return | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	176	103.1
Pays/paying a return | Pending final regulatory determination | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	176	103.1
Pays/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	5,526.4	5,823.1
Pays/paying a return | Approved for payment | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	1,622.1	2,179.7
Regulatory liabilities, not subject to rate normalization requirements, amount	$ 192	228
Regulatory liabilities, not subject to rate normalization requirements, refund period	10 years
Pays/paying a return | Approved for payment | Asset Removal Costs
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 3,828	3,563.5
AEP TRANSMISSION COMPANY, LLC
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	878.4	783.7
AEP TRANSMISSION COMPANY, LLC | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	8.8	8.7
AEP TRANSMISSION COMPANY, LLC | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	869.6	775
AEP TRANSMISSION COMPANY, LLC | Pays/paying a return | Pending final regulatory determination | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	8.8	8.7
AEP TRANSMISSION COMPANY, LLC | Pays/paying a return | Approved for payment | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	287.3	308.7
Regulatory liabilities, not subject to rate normalization requirements, amount	$ 9	13
Regulatory liabilities, not subject to rate normalization requirements, refund period	4 years
AEP TRANSMISSION COMPANY, LLC | Pays/paying a return | Approved for payment | Asset Removal Costs
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 582.3	$ 466.3

EFFECTS OF REGULATION - Regul_8

EFFECTS OF REGULATION - Regulatory Asset - APCo (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Regulatory Asset [Line Items]
Total Current Regulatory Assets	$ 445.9	$ 514
Total Noncurrent Regulatory Assets	5,129.2	5,092.4
Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	1,310.8	837.3
Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	3,818.4	4,255.1
Earns/earning a return | Under-recovered Fuel Costs
Regulatory Asset [Line Items]
Total Current Regulatory Assets	$ 245.7	357.4
Remaining Recovery Period	1 year
Earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 395.1	349.9
Earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	20.7	49.8
Earns/earning a return | Pending final regulatory approval | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	51	0
Earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 1,711.5	1,946.9
Earns/earning a return | Approved for recovery | Plant Retirement Costs - Asset Retirement Obligation Costs
Regulatory Asset [Line Items]
Remaining Recovery Period	16 years
Total Noncurrent Regulatory Assets	$ 111	110.8
Earns/earning a return | Approved for recovery | Storm-Related Costs
Regulatory Asset [Line Items]
Remaining Recovery Period	7 years
Total Noncurrent Regulatory Assets	$ 106.7	170.9
Earns/earning a return | Approved for recovery | Long-term Under-recovered Fuel Costs - West Virginia
Regulatory Asset [Line Items]
Remaining Recovery Period	10 years
Total Noncurrent Regulatory Assets	$ 283.8	291.5
Earns/earning a return | Approved for recovery | Plant Retirement Costs - Unrecovered Plant
Regulatory Asset [Line Items]
Remaining Recovery Period	22 years
Total Noncurrent Regulatory Assets	$ 661.2	664.2
Earns/earning a return | Approved for recovery | Long-term Under-recovered Fuel Costs - Virginia
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	0	107
Earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	159.9	124.9
Does not earns/earning a return | Under-recovered Fuel Costs
Regulatory Asset [Line Items]
Total Current Regulatory Assets	$ 116	62.7
Remaining Recovery Period	1 year
Does not earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 915.7	487.4
Does not earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	86.3	52.6
Does not earns/earning a return | Pending final regulatory approval | Plant Retirement Costs - Asset Retirement Obligation Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	357.4	25.9
Does not earns/earning a return | Pending final regulatory approval | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	300.8	408.9
Does not earns/earning a return | Pending final regulatory approval | 2024-2025 Virginia Under-Earnings
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	78.4	0
Does not earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 2,106.9	2,308.2
Does not earns/earning a return | Approved for recovery | Plant Retirement Costs - Asset Retirement Obligation Costs
Regulatory Asset [Line Items]
Remaining Recovery Period	18 years
Total Noncurrent Regulatory Assets	$ 360.1	330.2
Does not earns/earning a return | Approved for recovery | Storm-Related Costs
Regulatory Asset [Line Items]
Remaining Recovery Period	7 years
Total Noncurrent Regulatory Assets	$ 66.5	38.5
Does not earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 240.1	269.1
Does not earns/earning a return | Approved for recovery | Pension and OPEB Funded Status
Regulatory Asset [Line Items]
Remaining Recovery Period	12 years
Total Noncurrent Regulatory Assets	$ 974.2	1,054.1
Does not earns/earning a return | Approved for recovery | Unamortized Loss on Reacquired Debt
Regulatory Asset [Line Items]
Remaining Recovery Period	24 years
Total Noncurrent Regulatory Assets	$ 90.9	97.2
Does not earns/earning a return | Approved for recovery | 2020-2022 Virginia Triennial Under Earnings
Regulatory Asset [Line Items]
Remaining Recovery Period	3 years
Total Noncurrent Regulatory Assets	$ 26	37.4
Does not earns/earning a return | Approved for recovery | Postemployment Benefits
Regulatory Asset [Line Items]
Remaining Recovery Period	3 years
Total Noncurrent Regulatory Assets	$ 27.9	30.6
Does not earns/earning a return | Approved for recovery | Unrealized Loss on Forward Commitments
Regulatory Asset [Line Items]
Remaining Recovery Period	8 years
Total Noncurrent Regulatory Assets	$ 53.3	131.4
APPALACHIAN POWER COMPANY
Regulatory Asset [Line Items]
Total Current Regulatory Assets	148.1	155.4
Total Noncurrent Regulatory Assets	1,366	1,155.1
APPALACHIAN POWER COMPANY | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	535.5	125.5
APPALACHIAN POWER COMPANY | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	830.5	1,029.6
APPALACHIAN POWER COMPANY | Earns/earning a return | Under-recovered Fuel Costs
Regulatory Asset [Line Items]
Total Current Regulatory Assets	$ 148.1	147.4
Remaining Recovery Period	1 year
APPALACHIAN POWER COMPANY | Earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 1.1	0.6
APPALACHIAN POWER COMPANY | Earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	1.1	0.6
APPALACHIAN POWER COMPANY | Earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 227.3	340.3
APPALACHIAN POWER COMPANY | Earns/earning a return | Approved for recovery | Long-term Under-recovered Fuel Costs - West Virginia
Regulatory Asset [Line Items]
Remaining Recovery Period	10 years
Total Noncurrent Regulatory Assets	$ 154.1	154.2
APPALACHIAN POWER COMPANY | Earns/earning a return | Approved for recovery | Plant Retirement Costs - Unrecovered Plant
Regulatory Asset [Line Items]
Remaining Recovery Period	19 years
Total Noncurrent Regulatory Assets	$ 68	72
APPALACHIAN POWER COMPANY | Earns/earning a return | Approved for recovery | Long-term Under-recovered Fuel Costs - Virginia
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	0	107
APPALACHIAN POWER COMPANY | Earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	5.2	7.1
APPALACHIAN POWER COMPANY | Does not earns/earning a return | Under-recovered Fuel Costs
Regulatory Asset [Line Items]
Total Current Regulatory Assets	$ 0	8
Remaining Recovery Period	1 year
APPALACHIAN POWER COMPANY | Does not earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 534.4	124.9
APPALACHIAN POWER COMPANY | Does not earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	11.9	7.5
APPALACHIAN POWER COMPANY | Does not earns/earning a return | Pending final regulatory approval | Plant Retirement Costs - Asset Retirement Obligation Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	282.1	25.9
APPALACHIAN POWER COMPANY | Does not earns/earning a return | Pending final regulatory approval | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	144.2	91.5
APPALACHIAN POWER COMPANY | Does not earns/earning a return | Pending final regulatory approval | 2024-2025 Virginia Under-Earnings
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	78.4	0
APPALACHIAN POWER COMPANY | Does not earns/earning a return | Pending final regulatory approval | Pension Settlement
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	17.8	0
APPALACHIAN POWER COMPANY | Does not earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 603.2	689.3
APPALACHIAN POWER COMPANY | Does not earns/earning a return | Approved for recovery | Plant Retirement Costs - Asset Retirement Obligation Costs
Regulatory Asset [Line Items]
Remaining Recovery Period	15 years
Total Noncurrent Regulatory Assets	$ 307.5	324.7
APPALACHIAN POWER COMPANY | Does not earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 30	27.8
APPALACHIAN POWER COMPANY | Does not earns/earning a return | Approved for recovery | Pension and OPEB Funded Status
Regulatory Asset [Line Items]
Remaining Recovery Period	12 years
Total Noncurrent Regulatory Assets	$ 107.9	115.8
APPALACHIAN POWER COMPANY | Does not earns/earning a return | Approved for recovery | Unamortized Loss on Reacquired Debt
Regulatory Asset [Line Items]
Remaining Recovery Period	21 years
Total Noncurrent Regulatory Assets	$ 67	70.7
APPALACHIAN POWER COMPANY | Does not earns/earning a return | Approved for recovery | 2020-2022 Virginia Triennial Under Earnings
Regulatory Asset [Line Items]
Remaining Recovery Period	3 years
Total Noncurrent Regulatory Assets	$ 26	37.4
APPALACHIAN POWER COMPANY | Does not earns/earning a return | Approved for recovery | Peak Demand Reduction/Energy Efficiency
Regulatory Asset [Line Items]
Remaining Recovery Period	2 years
Total Noncurrent Regulatory Assets	$ 14.2	15
APPALACHIAN POWER COMPANY | Does not earns/earning a return | Approved for recovery | Postemployment Benefits
Regulatory Asset [Line Items]
Remaining Recovery Period	3 years
Total Noncurrent Regulatory Assets	$ 13.2	14.9
APPALACHIAN POWER COMPANY | Does not earns/earning a return | Approved for recovery | Vegetation Management Program - West Virginia
Regulatory Asset [Line Items]
Remaining Recovery Period	2 years
Total Noncurrent Regulatory Assets	$ 11.9	12.9
APPALACHIAN POWER COMPANY | Does not earns/earning a return | Approved for recovery | Virginia Generation Rate Adjustment Clause
Regulatory Asset [Line Items]
Remaining Recovery Period	2 years
Total Noncurrent Regulatory Assets	$ 11.6	10.9
APPALACHIAN POWER COMPANY | Does not earns/earning a return | Approved for recovery | Excess SO2 Allowance Inventory - Virginia
Regulatory Asset [Line Items]
Remaining Recovery Period	8 years
Total Noncurrent Regulatory Assets	$ 10.5	11.8
APPALACHIAN POWER COMPANY | Does not earns/earning a return | Approved for recovery | Virginia Transmission Rate Adjustment Clause
Regulatory Asset [Line Items]
Remaining Recovery Period	2 years
Total Noncurrent Regulatory Assets	$ 3.4	25.5
APPALACHIAN POWER COMPANY | Does not earns/earning a return | Approved for recovery | Unrealized Loss on Forward Commitments
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 0	$ 21.9

EFFECTS OF REGULATION - Regul_9

EFFECTS OF REGULATION - Regulatory Liabilities - APCo (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Regulatory Liability [Line Items]
Total Current Regulatory Liabilities	$ 53.5	$ 26.5
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	8,344	8,182.4
Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	322	207.9
Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	8,022	7,974.5
Does not pay/paying a return | Over-recovered Fuel Costs
Regulatory Liability [Line Items]
Total Current Regulatory Liabilities	$ 31.9	23.2
Remaining Refund Period	1 year
Does not pay/paying a return | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 146	104.8
Does not pay/paying a return | Pending final regulatory determination | FERC 2021 Transmission Formula Rate Challenge Refunds
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	131.3	103.1
Does not pay/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 2,495.6	2,151.4
Does not pay/paying a return | Approved for payment | Over-recovered Fuel Costs
Regulatory Liability [Line Items]
Remaining Refund Period	8 years
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 32.1	26.1
Does not pay/paying a return | Approved for payment | Deferred Investment Tax Credits
Regulatory Liability [Line Items]
Remaining Refund Period	29 years
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 65.1	154.5
Does not pay/paying a return | Approved for payment | 2017-2019 Virginia Triennial Revenue Provision
Regulatory Liability [Line Items]
Remaining Refund Period	25 years
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 35.2	37.1
Does not pay/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	90.1	106.5
Pays/paying a return | Over-recovered Fuel Costs
Regulatory Liability [Line Items]
Total Current Regulatory Liabilities	$ 21.6	3.3
Remaining Refund Period	1 year
Pays/paying a return | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 176	103.1
Pays/paying a return | Pending final regulatory determination | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	176	103.1
Pays/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	5,526.4	5,823.1
Pays/paying a return | Approved for payment | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	1,622.1	2,179.7
Regulatory liabilities, not subject to rate normalization requirements, amount	$ 192	228
Regulatory liabilities, not subject to rate normalization requirements, refund period	10 years
Pays/paying a return | Approved for payment | Asset Removal Costs
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 3,828	3,563.5
Pays/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	40.4	35
APPALACHIAN POWER COMPANY
Regulatory Liability [Line Items]
Total Current Regulatory Liabilities	21.6	0
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	1,115.8	1,081.9
APPALACHIAN POWER COMPANY | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	18.6	27.6
APPALACHIAN POWER COMPANY | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	1,097.2	1,054.3
APPALACHIAN POWER COMPANY | Does not pay/paying a return | Over-recovered Fuel Costs
Regulatory Liability [Line Items]
Total Current Regulatory Liabilities	$ 21.6	0
Remaining Refund Period	1 year
APPALACHIAN POWER COMPANY | Does not pay/paying a return | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 24.9	19.7
APPALACHIAN POWER COMPANY | Does not pay/paying a return | Pending final regulatory determination | FERC 2021 Transmission Formula Rate Challenge Refunds
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	24.9	19.7
APPALACHIAN POWER COMPANY | Does not pay/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 72.3	54.3
APPALACHIAN POWER COMPANY | Does not pay/paying a return | Approved for payment | 2017-2019 Virginia Triennial Revenue Provision
Regulatory Liability [Line Items]
Remaining Refund Period	25 years
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 35.2	37.1
APPALACHIAN POWER COMPANY | Does not pay/paying a return | Approved for payment | Virginia Transmission Rate Adjustment Clause
Regulatory Liability [Line Items]
Remaining Refund Period	2 years
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 10.2	1.5
APPALACHIAN POWER COMPANY | Does not pay/paying a return | Approved for payment | Energy Efficiency Rate Adjustment Clause - Virginia
Regulatory Liability [Line Items]
Remaining Refund Period	2 years
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 10	3.2
APPALACHIAN POWER COMPANY | Does not pay/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	16.9	12.5
APPALACHIAN POWER COMPANY | Pays/paying a return | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	(6.3)	7.9
APPALACHIAN POWER COMPANY | Pays/paying a return | Pending final regulatory determination | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	(6.3)	7.9
APPALACHIAN POWER COMPANY | Pays/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	1,024.9	1,000
APPALACHIAN POWER COMPANY | Pays/paying a return | Approved for payment | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	219.3	240.1
Regulatory liabilities, not subject to rate normalization requirements, amount	$ 12	35
Regulatory liabilities, not subject to rate normalization requirements, refund period	4 years
APPALACHIAN POWER COMPANY | Pays/paying a return | Approved for payment | Asset Removal Costs
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 805.6	759.6
APPALACHIAN POWER COMPANY | Pays/paying a return | Approved for payment | Deferred Investment Tax Credits
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 0	$ 0.3

EFFECTS OF REGULATION - Regu_10

EFFECTS OF REGULATION - Regulatory Asset - I&M (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2024
Regulatory Asset [Line Items]
Total Current Regulatory Assets	$ 514	$ 445.9
Total Noncurrent Regulatory Assets	5,092.4	5,129.2
Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	837.3	1,310.8
Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	4,255.1	3,818.4
Earns/earning a return | Under-recovered Fuel Costs
Regulatory Asset [Line Items]
Total Current Regulatory Assets	357.4	$ 245.7
Remaining Recovery Period		1 year
Earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	349.9	$ 395.1
Earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	49.8	20.7
Earns/earning a return | Pending final regulatory approval | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	0	51
Earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	1,946.9	$ 1,711.5
Earns/earning a return | Approved for recovery | Plant Retirement Costs - Asset Retirement Obligation Costs
Regulatory Asset [Line Items]
Remaining Recovery Period		16 years
Total Noncurrent Regulatory Assets	110.8	$ 111
Earns/earning a return | Approved for recovery | Storm-Related Costs
Regulatory Asset [Line Items]
Remaining Recovery Period		7 years
Total Noncurrent Regulatory Assets	170.9	$ 106.7
Earns/earning a return | Approved for recovery | Plant Retirement Costs - Unrecovered Plant
Regulatory Asset [Line Items]
Remaining Recovery Period		22 years
Total Noncurrent Regulatory Assets	664.2	$ 661.2
Earns/earning a return | Approved for recovery | Rockport Plant Dry Sorbent Injection System and Selective Catalytic Reduction
Regulatory Asset [Line Items]
Remaining Recovery Period		4 years
Total Noncurrent Regulatory Assets	46.9	$ 37.3
Earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	124.9	159.9
Does not earns/earning a return | Under-recovered Fuel Costs
Regulatory Asset [Line Items]
Total Current Regulatory Assets	62.7	$ 116
Remaining Recovery Period		1 year
Does not earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	487.4	$ 915.7
Does not earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	52.6	86.3
Does not earns/earning a return | Pending final regulatory approval | Plant Retirement Costs - Asset Retirement Obligation Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	25.9	357.4
Does not earns/earning a return | Pending final regulatory approval | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	408.9	300.8
Does not earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	2,308.2	$ 2,106.9
Does not earns/earning a return | Approved for recovery | Plant Retirement Costs - Asset Retirement Obligation Costs
Regulatory Asset [Line Items]
Remaining Recovery Period		18 years
Total Noncurrent Regulatory Assets	330.2	$ 360.1
Does not earns/earning a return | Approved for recovery | Storm-Related Costs
Regulatory Asset [Line Items]
Remaining Recovery Period		7 years
Total Noncurrent Regulatory Assets	38.5	$ 66.5
Does not earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	269.1	$ 240.1
Does not earns/earning a return | Approved for recovery | Cook Plant Nuclear Refueling Outage Levelization
Regulatory Asset [Line Items]
Remaining Recovery Period		3 years
Total Noncurrent Regulatory Assets	55.7	$ 43
Does not earns/earning a return | Approved for recovery | Pension and OPEB Funded Status
Regulatory Asset [Line Items]
Remaining Recovery Period		12 years
Total Noncurrent Regulatory Assets	1,054.1	$ 974.2
Does not earns/earning a return | Approved for recovery | Unamortized Loss on Reacquired Debt
Regulatory Asset [Line Items]
Remaining Recovery Period		24 years
Total Noncurrent Regulatory Assets	97.2	$ 90.9
Does not earns/earning a return | Approved for recovery | Postemployment Benefits
Regulatory Asset [Line Items]
Remaining Recovery Period		3 years
Total Noncurrent Regulatory Assets	30.6	$ 27.9
INDIANA MICHIGAN POWER COMPANY
Regulatory Asset [Line Items]
Total Current Regulatory Assets	14.8	10.6
Total Noncurrent Regulatory Assets	406.3	548.1
INDIANA MICHIGAN POWER COMPANY | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	33.2	115
INDIANA MICHIGAN POWER COMPANY | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	373.1	433.1
INDIANA MICHIGAN POWER COMPANY | Earns/earning a return | Under-recovered Fuel Costs
Regulatory Asset [Line Items]
Total Current Regulatory Assets	14.8	$ 10.6
Remaining Recovery Period		1 year
INDIANA MICHIGAN POWER COMPANY | Earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	0.2	$ 6.4
INDIANA MICHIGAN POWER COMPANY | Earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	0.2	6.4
INDIANA MICHIGAN POWER COMPANY | Earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	229.3	$ 194.8
INDIANA MICHIGAN POWER COMPANY | Earns/earning a return | Approved for recovery | Plant Retirement Costs - Unrecovered Plant
Regulatory Asset [Line Items]
Remaining Recovery Period		4 years
Total Noncurrent Regulatory Assets	122.5	$ 98
INDIANA MICHIGAN POWER COMPANY | Earns/earning a return | Approved for recovery | Rockport Plant Dry Sorbent Injection System and Selective Catalytic Reduction
Regulatory Asset [Line Items]
Remaining Recovery Period		4 years
Total Noncurrent Regulatory Assets	46.9	$ 37.3
INDIANA MICHIGAN POWER COMPANY | Earns/earning a return | Approved for recovery | Cook Plant Uprate Project
Regulatory Asset [Line Items]
Remaining Recovery Period		9 years
Total Noncurrent Regulatory Assets	22.9	$ 20.5
INDIANA MICHIGAN POWER COMPANY | Earns/earning a return | Approved for recovery | Deferred Cook Plant Life Cycle Management Project Costs - Michigan, FERC
Regulatory Asset [Line Items]
Remaining Recovery Period		10 years
Total Noncurrent Regulatory Assets	11.1	$ 10.1
INDIANA MICHIGAN POWER COMPANY | Earns/earning a return | Approved for recovery | Cook Plant Turbine - Indiana
Regulatory Asset [Line Items]
Remaining Recovery Period		14 years
Total Noncurrent Regulatory Assets	8.4	$ 7.8
INDIANA MICHIGAN POWER COMPANY | Earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	17.5	21.1
INDIANA MICHIGAN POWER COMPANY | Does not earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	33	108.6
INDIANA MICHIGAN POWER COMPANY | Does not earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	3.3	1.6
INDIANA MICHIGAN POWER COMPANY | Does not earns/earning a return | Pending final regulatory approval | Plant Retirement Costs - Asset Retirement Obligation Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	0	74
INDIANA MICHIGAN POWER COMPANY | Does not earns/earning a return | Pending final regulatory approval | NOLC Costs - Indiana
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	0	26.7
INDIANA MICHIGAN POWER COMPANY | Does not earns/earning a return | Pending final regulatory approval | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	29.7	6.3
INDIANA MICHIGAN POWER COMPANY | Does not earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	143.8	$ 238.3
INDIANA MICHIGAN POWER COMPANY | Does not earns/earning a return | Approved for recovery | Storm-Related Costs
Regulatory Asset [Line Items]
Remaining Recovery Period		4 years
Total Noncurrent Regulatory Assets	3.4	$ 20.2
INDIANA MICHIGAN POWER COMPANY | Does not earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	17.6	20.2
INDIANA MICHIGAN POWER COMPANY | Does not earns/earning a return | Approved for recovery | Income Taxes, Net
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	0	$ 108.8
Regulatory asset, not subject to rate normalization requirements, amount	$ 12
Regulatory asset, not subject to rate normalization requirements, refund period	4 years
INDIANA MICHIGAN POWER COMPANY | Does not earns/earning a return | Approved for recovery | Cook Plant Nuclear Refueling Outage Levelization
Regulatory Asset [Line Items]
Remaining Recovery Period		3 years
Total Noncurrent Regulatory Assets	$ 55.7	$ 43
INDIANA MICHIGAN POWER COMPANY | Does not earns/earning a return | Approved for recovery | Pension and OPEB Funded Status
Regulatory Asset [Line Items]
Remaining Recovery Period		12 years
Total Noncurrent Regulatory Assets	25.4	$ 14.6
INDIANA MICHIGAN POWER COMPANY | Does not earns/earning a return | Approved for recovery | Excess SO2 Allowance Inventory - Indiana
Regulatory Asset [Line Items]
Remaining Recovery Period		4 years
Total Noncurrent Regulatory Assets	14.8	$ 11.9
INDIANA MICHIGAN POWER COMPANY | Does not earns/earning a return | Approved for recovery | Unamortized Loss on Reacquired Debt
Regulatory Asset [Line Items]
Remaining Recovery Period		24 years
Total Noncurrent Regulatory Assets	11.8	$ 10.9
INDIANA MICHIGAN POWER COMPANY | Does not earns/earning a return | Approved for recovery | Postemployment Benefits
Regulatory Asset [Line Items]
Remaining Recovery Period		3 years
Total Noncurrent Regulatory Assets	7	$ 7.3
INDIANA MICHIGAN POWER COMPANY | Does not earns/earning a return | Approved for recovery | Environmental Cost Rider - Indiana
Regulatory Asset [Line Items]
Remaining Recovery Period		2 years
Total Noncurrent Regulatory Assets	$ 8.1	$ 1.4

EFFECTS OF REGULATION - Regu_11

EFFECTS OF REGULATION - Regulatory Liabilities - I&M (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Regulatory Liability [Line Items]
Total Current Regulatory Liabilities	$ 53.5	$ 26.5
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	8,344	8,182.4
Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	322	207.9
Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	8,022	7,974.5
Does not pay/paying a return | Over-recovered Fuel Costs
Regulatory Liability [Line Items]
Total Current Regulatory Liabilities	$ 31.9	23.2
Remaining Refund Period	1 year
Does not pay/paying a return | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 146	104.8
Does not pay/paying a return | Pending final regulatory determination | FERC 2021 Transmission Formula Rate Challenge Refunds
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	131.3	103.1
Does not pay/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 2,495.6	2,151.4
Does not pay/paying a return | Approved for payment | Over-recovered Fuel Costs
Regulatory Liability [Line Items]
Remaining Refund Period	8 years
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 32.1	26.1
Does not pay/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	90.1	106.5
Does not pay/paying a return | Approved for payment | Excess Nuclear Decommissioning Funding
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	2,137.3	1,721.9
Does not pay/paying a return | Approved for payment | Spent Nuclear Fuel
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 50.4	47.6
Does not pay/paying a return | Approved for payment | Demand Side Management
Regulatory Liability [Line Items]
Remaining Refund Period	2 years
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 52.6	31.3
Does not pay/paying a return | Approved for payment | Deferred Investment Tax Credits
Regulatory Liability [Line Items]
Remaining Refund Period	29 years
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 65.1	154.5
Pays/paying a return | Over-recovered Fuel Costs
Regulatory Liability [Line Items]
Total Current Regulatory Liabilities	$ 21.6	3.3
Remaining Refund Period	1 year
Pays/paying a return | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 176	103.1
Pays/paying a return | Pending final regulatory determination | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	176	103.1
Pays/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	5,526.4	5,823.1
Pays/paying a return | Approved for payment | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	1,622.1	2,179.7
Regulatory liabilities, not subject to rate normalization requirements, amount	192	228
Pays/paying a return | Approved for payment | Asset Removal Costs
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	3,828	3,563.5
Pays/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	40.4	35
INDIANA MICHIGAN POWER COMPANY
Regulatory Liability [Line Items]
Total Current Regulatory Liabilities	10.3	23.2
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	2,480.8	2,052.3
INDIANA MICHIGAN POWER COMPANY | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	43.4	(80.2)
INDIANA MICHIGAN POWER COMPANY | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	2,437.4	2,132.5
INDIANA MICHIGAN POWER COMPANY | Does not pay/paying a return | Over-recovered Fuel Costs
Regulatory Liability [Line Items]
Total Current Regulatory Liabilities	$ 10.3	23.2
Remaining Refund Period	1 year
INDIANA MICHIGAN POWER COMPANY | Does not pay/paying a return | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 43.4	22.8
INDIANA MICHIGAN POWER COMPANY | Does not pay/paying a return | Pending final regulatory determination | FERC 2021 Transmission Formula Rate Challenge Refunds
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	28.9	22.8
INDIANA MICHIGAN POWER COMPANY | Does not pay/paying a return | Pending final regulatory determination | Cook Plant PTC Deferral - Michigan
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	14.5	0
INDIANA MICHIGAN POWER COMPANY | Does not pay/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	2,238.8	1,820.9
INDIANA MICHIGAN POWER COMPANY | Does not pay/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	2.3	4.8
INDIANA MICHIGAN POWER COMPANY | Does not pay/paying a return | Approved for payment | Excess Nuclear Decommissioning Funding
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	2,137.3	1,721.9
INDIANA MICHIGAN POWER COMPANY | Does not pay/paying a return | Approved for payment | Spent Nuclear Fuel
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 50.4	47.6
INDIANA MICHIGAN POWER COMPANY | Does not pay/paying a return | Approved for payment | Demand Side Management
Regulatory Liability [Line Items]
Remaining Refund Period	2 years
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 33	16.7
INDIANA MICHIGAN POWER COMPANY | Does not pay/paying a return | Approved for payment | Deferred Investment Tax Credits
Regulatory Liability [Line Items]
Remaining Refund Period	26 years
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 13.8	15.8
INDIANA MICHIGAN POWER COMPANY | Does not pay/paying a return | Approved for payment | PJM Costs and Off-system Sales Margin Sharing - Indiana
Regulatory Liability [Line Items]
Remaining Refund Period	1 year
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 2	14.1
INDIANA MICHIGAN POWER COMPANY | Pays/paying a return | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	0	(103)
INDIANA MICHIGAN POWER COMPANY | Pays/paying a return | Pending final regulatory determination | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	0	(103)
INDIANA MICHIGAN POWER COMPANY | Pays/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	198.6	311.6
INDIANA MICHIGAN POWER COMPANY | Pays/paying a return | Approved for payment | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	0	116.8
Regulatory liabilities, not subject to rate normalization requirements, amount		25
INDIANA MICHIGAN POWER COMPANY | Pays/paying a return | Approved for payment | Asset Removal Costs
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 174.2	168.1
INDIANA MICHIGAN POWER COMPANY | Pays/paying a return | Approved for payment | Renewable Energy Surcharge - Michigan
Regulatory Liability [Line Items]
Remaining Refund Period	2 years
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 24.3	26.6
INDIANA MICHIGAN POWER COMPANY | Pays/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 0.1	$ 0.1

EFFECTS OF REGULATION - Regu_12

EFFECTS OF REGULATION - Regulatory Asset - OPCo (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 5,129.2	$ 5,092.4
Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	1,310.8	837.3
Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	3,818.4	4,255.1
Earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	395.1	349.9
Earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	20.7	49.8
Earns/earning a return | Pending final regulatory approval | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	51	0
Earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	1,711.5	1,946.9
Earns/earning a return | Approved for recovery | Ohio Basic Transmission Cost Rider
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 26.1	42.2
Remaining Recovery Period	2 years
Earns/earning a return | Approved for recovery | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 106.7	170.9
Remaining Recovery Period	7 years
Earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 159.9	124.9
Does not earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	915.7	487.4
Does not earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	86.3	52.6
Does not earns/earning a return | Pending final regulatory approval | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	300.8	408.9
Does not earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	2,106.9	2,308.2
Does not earns/earning a return | Approved for recovery | Pension and OPEB Funded Status
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 974.2	1,054.1
Remaining Recovery Period	12 years
Does not earns/earning a return | Approved for recovery | OVEC Purchased Power
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 52	50.1
Remaining Recovery Period	2 years
Does not earns/earning a return | Approved for recovery | Unrealized Loss on Forward Commitments
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 53.3	131.4
Remaining Recovery Period	8 years
Does not earns/earning a return | Approved for recovery | Smart Grid Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 33.8	26.3
Remaining Recovery Period	2 years
Does not earns/earning a return | Approved for recovery | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 66.5	38.5
Remaining Recovery Period	7 years
Does not earns/earning a return | Approved for recovery | Ohio Enhanced Service Reliability Plan
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 26.2	35.3
Remaining Recovery Period	2 years
Does not earns/earning a return | Approved for recovery | Ohio Distribution Investment Rider
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 11	35.3
Remaining Recovery Period	2 years
Does not earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 240.1	269.1
OHIO POWER COMPANY
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	379.1	455
OHIO POWER COMPANY | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	0.5	23.6
OHIO POWER COMPANY | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	378.6	431.4
OHIO POWER COMPANY | Earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	0.4	0
OHIO POWER COMPANY | Earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	0.4	0
OHIO POWER COMPANY | Earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	26.1	44
OHIO POWER COMPANY | Earns/earning a return | Approved for recovery | Ohio Basic Transmission Cost Rider
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 26.1	42.2
Remaining Recovery Period	2 years
OHIO POWER COMPANY | Earns/earning a return | Approved for recovery | Ohio Distribution Decoupling
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 0	1.8
OHIO POWER COMPANY | Does not earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	0.1	23.6
OHIO POWER COMPANY | Does not earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	0.1	0
OHIO POWER COMPANY | Does not earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	352.5	387.4
OHIO POWER COMPANY | Does not earns/earning a return | Approved for recovery | Pension and OPEB Funded Status
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 134	147.1
Remaining Recovery Period	12 years
OHIO POWER COMPANY | Does not earns/earning a return | Approved for recovery | OVEC Purchased Power
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 52	50.1
Remaining Recovery Period	2 years
OHIO POWER COMPANY | Does not earns/earning a return | Approved for recovery | Unrealized Loss on Forward Commitments
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 47.6	50.8
Remaining Recovery Period	8 years
OHIO POWER COMPANY | Does not earns/earning a return | Approved for recovery | Smart Grid Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 33.8	26.3
Remaining Recovery Period	2 years
OHIO POWER COMPANY | Does not earns/earning a return | Approved for recovery | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 28.6	30.9
Remaining Recovery Period	2 years
OHIO POWER COMPANY | Does not earns/earning a return | Approved for recovery | Ohio Enhanced Service Reliability Plan
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 26.2	35.3
Remaining Recovery Period	2 years
OHIO POWER COMPANY | Does not earns/earning a return | Approved for recovery | Bad Debt Rider
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 13.7	0.7
Remaining Recovery Period	2 years
OHIO POWER COMPANY | Does not earns/earning a return | Approved for recovery | Ohio Distribution Investment Rider
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 11	35.3
Remaining Recovery Period	2 years
OHIO POWER COMPANY | Does not earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 5.6	$ 10.9

EFFECTS OF REGULATION - Regu_13

EFFECTS OF REGULATION - Regulatory Liabilities - OPCo (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 8,344	$ 8,182.4
Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	322	207.9
Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 8,022	7,974.5
Does not pay/paying a return | Over-recovered Fuel Costs
Regulatory Liability [Line Items]
Remaining Refund Period	1 year
Does not pay/paying a return | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 146	104.8
Does not pay/paying a return | Pending final regulatory determination | FERC 2021 Transmission Formula Rate Challenge Refunds
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	131.3	103.1
Does not pay/paying a return | Pending final regulatory determination | Other Regulatory Liabilities Pending Final Regulatory Determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	14.7	1.7
Does not pay/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	2,495.6	2,151.4
Does not pay/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	90.1	106.5
Does not pay/paying a return | Approved for payment | Over-recovered Fuel Costs
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 32.1	26.1
Remaining Refund Period	8 years
Pays/paying a return | Over-recovered Fuel Costs
Regulatory Liability [Line Items]
Remaining Refund Period	1 year
Pays/paying a return | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 176	103.1
Pays/paying a return | Pending final regulatory determination | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	176	103.1
Pays/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	5,526.4	5,823.1
Pays/paying a return | Approved for payment | Asset Removal Costs
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	3,828	3,563.5
Pays/paying a return | Approved for payment | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	1,622.1	2,179.7
Regulatory liabilities, not subject to rate normalization requirements, amount	$ 192	228
Regulatory liabilities, not subject to rate normalization requirements, refund period	10 years
Pays/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 40.4	35
OHIO POWER COMPANY
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	987.7	1,003.6
OHIO POWER COMPANY | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	914.8	946.4
OHIO POWER COMPANY | Does not pay/paying a return | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	72.9	57.2
OHIO POWER COMPANY | Does not pay/paying a return | Pending final regulatory determination | FERC 2021 Transmission Formula Rate Challenge Refunds
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	72.7	57
OHIO POWER COMPANY | Does not pay/paying a return | Pending final regulatory determination | Other Regulatory Liabilities Pending Final Regulatory Determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	0.2	0.2
OHIO POWER COMPANY | Does not pay/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	63.2	62.7
OHIO POWER COMPANY | Does not pay/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	8.3	13.4
OHIO POWER COMPANY | Does not pay/paying a return | Approved for payment | Over-recovered Fuel Costs
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 32.1	26.1
Remaining Refund Period	8 years
OHIO POWER COMPANY | Does not pay/paying a return | Approved for payment | Peak Demand Reduction/Energy Efficiency
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 22.8	23.2
Remaining Refund Period	2 years
OHIO POWER COMPANY | Pays/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 851.6	883.7
OHIO POWER COMPANY | Pays/paying a return | Approved for payment | Asset Removal Costs
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	480	475.5
OHIO POWER COMPANY | Pays/paying a return | Approved for payment | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	367.6	408.2
Regulatory liabilities, not subject to rate normalization requirements, amount	$ 100	132
Regulatory liabilities, not subject to rate normalization requirements, refund period	4 years
OHIO POWER COMPANY | Pays/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 4	$ 0

EFFECTS OF REGULATION - Regu_14

EFFECTS OF REGULATION - Regulatory Asset - PSO (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Regulatory Asset [Line Items]
Total Current Regulatory Assets	$ 445.9	$ 514
Total Noncurrent Regulatory Assets	5,129.2	5,092.4
Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	1,310.8	837.3
Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	3,818.4	4,255.1
Earns/earning a return | Under-recovered Fuel Costs
Regulatory Asset [Line Items]
Total Current Regulatory Assets	$ 245.7	357.4
Remaining Recovery Period	1 year
Earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 395.1	349.9
Earns/earning a return | Pending final regulatory approval | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	51	0
Earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	20.7	49.8
Earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	1,711.5	1,946.9
Earns/earning a return | Approved for recovery | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 106.7	170.9
Remaining Recovery Period	7 years
Earns/earning a return | Approved for recovery | Plant Retirement Costs - Unrecovered Plant
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 661.2	664.2
Remaining Recovery Period	22 years
Earns/earning a return | Approved for recovery | Environmental Control Projects
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 29.1	31.4
Remaining Recovery Period	16 years
Earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 159.9	124.9
Does not earns/earning a return | Under-recovered Fuel Costs
Regulatory Asset [Line Items]
Total Current Regulatory Assets	$ 116	62.7
Remaining Recovery Period	1 year
Does not earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 915.7	487.4
Does not earns/earning a return | Pending final regulatory approval | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	300.8	408.9
Does not earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	86.3	52.6
Does not earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	2,106.9	2,308.2
Does not earns/earning a return | Approved for recovery | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 66.5	38.5
Remaining Recovery Period	7 years
Does not earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 240.1	269.1
Does not earns/earning a return | Approved for recovery | Pension and OPEB Funded Status
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 974.2	1,054.1
Remaining Recovery Period	12 years
Does not earns/earning a return | Approved for recovery | Unrealized Loss on Forward Commitments
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 53.3	131.4
Remaining Recovery Period	8 years
PUBLIC SERVICE COMPANY OF OKLAHOMA
Regulatory Asset [Line Items]
Total Current Regulatory Assets	$ 64.7	118.3
Total Noncurrent Regulatory Assets	527.8	522.7
PUBLIC SERVICE COMPANY OF OKLAHOMA | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	497.5	434
PUBLIC SERVICE COMPANY OF OKLAHOMA | Earns/earning a return | Under-recovered Fuel Costs
Regulatory Asset [Line Items]
Total Current Regulatory Assets	$ 64.7	118.3
Remaining Recovery Period	1 year
PUBLIC SERVICE COMPANY OF OKLAHOMA | Earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 425.4	325.3
PUBLIC SERVICE COMPANY OF OKLAHOMA | Earns/earning a return | Approved for recovery | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 106.7	26.2
Remaining Recovery Period	7 years
PUBLIC SERVICE COMPANY OF OKLAHOMA | Earns/earning a return | Approved for recovery | Plant Retirement Costs - Unrecovered Plant
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 274	254.1
Remaining Recovery Period	22 years
PUBLIC SERVICE COMPANY OF OKLAHOMA | Earns/earning a return | Approved for recovery | Environmental Control Projects
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 21.2	22.5
Remaining Recovery Period	16 years
PUBLIC SERVICE COMPANY OF OKLAHOMA | Earns/earning a return | Approved for recovery | Meter Replacement Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 10.1	14.1
Remaining Recovery Period	3 years
PUBLIC SERVICE COMPANY OF OKLAHOMA | Earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 13.4	8.4
PUBLIC SERVICE COMPANY OF OKLAHOMA | Does not earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	30.3	88.7
PUBLIC SERVICE COMPANY OF OKLAHOMA | Does not earns/earning a return | Pending final regulatory approval | NOCL - Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	16.4	0
PUBLIC SERVICE COMPANY OF OKLAHOMA | Does not earns/earning a return | Pending final regulatory approval | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	4.9	88.5
PUBLIC SERVICE COMPANY OF OKLAHOMA | Does not earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	9	0.2
PUBLIC SERVICE COMPANY OF OKLAHOMA | Does not earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	72.1	108.7
PUBLIC SERVICE COMPANY OF OKLAHOMA | Does not earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	10.6	16.2
PUBLIC SERVICE COMPANY OF OKLAHOMA | Does not earns/earning a return | Approved for recovery | Pension and OPEB Funded Status
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 57.6	62.6
Remaining Recovery Period	12 years
PUBLIC SERVICE COMPANY OF OKLAHOMA | Does not earns/earning a return | Approved for recovery | Unrealized Loss on Forward Commitments
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 3.9	$ 29.9
Remaining Recovery Period	2 years

EFFECTS OF REGULATION - Regu_15

EFFECTS OF REGULATION - Regulatory Liabilities - PSO (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 8,344	$ 8,182.4
Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	322	207.9
Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	8,022	7,974.5
Does not pay/paying a return | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	146	104.8
Does not pay/paying a return | Pending final regulatory determination | FERC 2021 Transmission Formula Rate Challenge Refunds
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	131.3	103.1
Does not pay/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	2,495.6	2,151.4
Does not pay/paying a return | Approved for payment | Deferred Investment Tax Credits
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 65.1	154.5
Remaining Refund Period	29 years
Does not pay/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 90.1	106.5
Pays/paying a return | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	176	103.1
Pays/paying a return | Pending final regulatory determination | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	176	103.1
Pays/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	5,526.4	5,823.1
Pays/paying a return | Approved for payment | Asset Removal Costs
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	3,828	3,563.5
Pays/paying a return | Approved for payment | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	1,622.1	2,179.7
Regulatory liabilities, not subject to rate normalization requirements, amount	$ 192	228
Regulatory liabilities, not subject to rate normalization requirements, refund period	10 years
Pays/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 40.4	35
PUBLIC SERVICE COMPANY OF OKLAHOMA
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	689.7	765.6
PUBLIC SERVICE COMPANY OF OKLAHOMA | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	688.1	764.4
PUBLIC SERVICE COMPANY OF OKLAHOMA | Does not pay/paying a return | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	1.6	1.2
PUBLIC SERVICE COMPANY OF OKLAHOMA | Does not pay/paying a return | Pending final regulatory determination | FERC 2021 Transmission Formula Rate Challenge Refunds
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	1.6	1.2
PUBLIC SERVICE COMPANY OF OKLAHOMA | Does not pay/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	46.5	51.2
PUBLIC SERVICE COMPANY OF OKLAHOMA | Does not pay/paying a return | Approved for payment | Deferred Investment Tax Credits
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 46.2	47.2
Remaining Refund Period	12 years
PUBLIC SERVICE COMPANY OF OKLAHOMA | Does not pay/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 0.3	4
PUBLIC SERVICE COMPANY OF OKLAHOMA | Pays/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	641.6	713.2
PUBLIC SERVICE COMPANY OF OKLAHOMA | Pays/paying a return | Approved for payment | Asset Removal Costs
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	323.6	317.5
PUBLIC SERVICE COMPANY OF OKLAHOMA | Pays/paying a return | Approved for payment | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	318	395.7
Regulatory liabilities, not subject to rate normalization requirements, amount	$ 46	$ 51
Regulatory liabilities, not subject to rate normalization requirements, refund period	10 years

EFFECTS OF REGULATION - Regu_16

EFFECTS OF REGULATION - Regulatory Asset - SWEPCo (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Regulatory Asset [Line Items]
Total Current Regulatory Assets	$ 445.9	$ 514
Total Noncurrent Regulatory Assets	5,129.2	5,092.4
Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	1,310.8	837.3
Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	3,818.4	4,255.1
Earns/earning a return | Unrecovered Winter Storm Fuel Costs
Regulatory Asset [Line Items]
Total Current Regulatory Assets	$ 84.2	93.9
Remaining Recovery Period	1 year
Earns/earning a return | Under-recovered Fuel Costs
Regulatory Asset [Line Items]
Total Current Regulatory Assets	$ 245.7	357.4
Remaining Recovery Period	1 year
Earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 395.1	349.9
Earns/earning a return | Pending final regulatory approval | Unrecovered Winter Storm Fuel Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	33.5	60.1
Earns/earning a return | Pending final regulatory approval | Welsh Plant, Units 1 and 3 Accelerated Depreciation
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	168.6	125.6
Earns/earning a return | Pending final regulatory approval | Pirkey Plant Accelerated Depreciation
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	121.3	114.4
Earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	20.7	49.8
Earns/earning a return | Pending final regulatory approval | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	51	0
Earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 1,711.5	1,946.9
Earns/earning a return | Approved for recovery | Unrecovered Winter Storm Fuel Costs
Regulatory Asset [Line Items]
Remaining Recovery Period	3 years
Total Noncurrent Regulatory Assets	$ 62.8	99.3
Earns/earning a return | Approved for recovery | Storm-Related Costs
Regulatory Asset [Line Items]
Remaining Recovery Period	7 years
Total Noncurrent Regulatory Assets	$ 106.7	170.9
Earns/earning a return | Approved for recovery | Fuel Mine Closure Costs - Texas
Regulatory Asset [Line Items]
Remaining Recovery Period	11 years
Total Noncurrent Regulatory Assets	$ 70.6	74.3
Earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	159.9	124.9
Does not earns/earning a return | Under-recovered Fuel Costs
Regulatory Asset [Line Items]
Total Current Regulatory Assets	$ 116	62.7
Remaining Recovery Period	1 year
Does not earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 915.7	487.4
Does not earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	86.3	52.6
Does not earns/earning a return | Pending final regulatory approval | NOLC - Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	92.8	0
Does not earns/earning a return | Pending final regulatory approval | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	300.8	408.9
Does not earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 2,106.9	2,308.2
Does not earns/earning a return | Approved for recovery | Storm-Related Costs
Regulatory Asset [Line Items]
Remaining Recovery Period	7 years
Total Noncurrent Regulatory Assets	$ 66.5	38.5
Does not earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 240.1	269.1
Does not earns/earning a return | Approved for recovery | Pension and OPEB Funded Status
Regulatory Asset [Line Items]
Remaining Recovery Period	12 years
Total Noncurrent Regulatory Assets	$ 974.2	1,054.1
Does not earns/earning a return | Approved for recovery | Plant Retirement Costs - Unrecovered Plant, Texas
Regulatory Asset [Line Items]
Remaining Recovery Period	22 years
Total Noncurrent Regulatory Assets	$ 44.5	48.7
Does not earns/earning a return | Approved for recovery | Unrealized Loss on Forward Commitments
Regulatory Asset [Line Items]
Remaining Recovery Period	8 years
Total Noncurrent Regulatory Assets	$ 53.3	131.4
SOUTHWESTERN ELECTRIC POWER COMPANY
Regulatory Asset [Line Items]
Total Current Regulatory Assets	106.6	170.8
Total Noncurrent Regulatory Assets	921.3	1,131.8
SOUTHWESTERN ELECTRIC POWER COMPANY | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	454.2	407.8
SOUTHWESTERN ELECTRIC POWER COMPANY | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	467.1	724
SOUTHWESTERN ELECTRIC POWER COMPANY | Earns/earning a return | Unrecovered Winter Storm Fuel Costs
Regulatory Asset [Line Items]
Total Current Regulatory Assets	$ 84.2	93.9
Remaining Recovery Period	1 year
SOUTHWESTERN ELECTRIC POWER COMPANY | Earns/earning a return | Under-recovered Fuel Costs
Regulatory Asset [Line Items]
Total Current Regulatory Assets	$ 22.4	76.9
Remaining Recovery Period	1 year
SOUTHWESTERN ELECTRIC POWER COMPANY | Earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 346	338.1
SOUTHWESTERN ELECTRIC POWER COMPANY | Earns/earning a return | Pending final regulatory approval | Unrecovered Winter Storm Fuel Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	33.5	60.1
SOUTHWESTERN ELECTRIC POWER COMPANY | Earns/earning a return | Pending final regulatory approval | Welsh Plant, Units 1 and 3 Accelerated Depreciation
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	168.6	125.6
SOUTHWESTERN ELECTRIC POWER COMPANY | Earns/earning a return | Pending final regulatory approval | Pirkey Plant Accelerated Depreciation
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	121.3	114.4
SOUTHWESTERN ELECTRIC POWER COMPANY | Earns/earning a return | Pending final regulatory approval | Dolet Hills Power Station Accelerated Depreciation
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	11.8	12
SOUTHWESTERN ELECTRIC POWER COMPANY | Earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	10.8	26
SOUTHWESTERN ELECTRIC POWER COMPANY | Earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 293.3	483.1
SOUTHWESTERN ELECTRIC POWER COMPANY | Earns/earning a return | Approved for recovery | Unrecovered Winter Storm Fuel Costs
Regulatory Asset [Line Items]
Remaining Recovery Period	3 years
Total Noncurrent Regulatory Assets	$ 62.8	99.3
SOUTHWESTERN ELECTRIC POWER COMPANY | Earns/earning a return | Approved for recovery | Pirkey Plant Accelerated Depreciation
Regulatory Asset [Line Items]
Remaining Recovery Period	8 years
Total Noncurrent Regulatory Assets	$ 66.4	65.8
SOUTHWESTERN ELECTRIC POWER COMPANY | Earns/earning a return | Approved for recovery | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 0	144.7
SOUTHWESTERN ELECTRIC POWER COMPANY | Earns/earning a return | Approved for recovery | Fuel Mine Closure Costs - Texas
Regulatory Asset [Line Items]
Remaining Recovery Period	11 years
Total Noncurrent Regulatory Assets	$ 70.6	74.3
SOUTHWESTERN ELECTRIC POWER COMPANY | Earns/earning a return | Approved for recovery | Plant Retirement Costs - Unrecovered Plant, Arkansas
Regulatory Asset [Line Items]
Remaining Recovery Period	18 years
Total Noncurrent Regulatory Assets	$ 40.2	44.4
SOUTHWESTERN ELECTRIC POWER COMPANY | Earns/earning a return | Approved for recovery | Dolet Hills Power Station Fuel Costs - Louisiana
Regulatory Asset [Line Items]
Remaining Recovery Period	3 years
Total Noncurrent Regulatory Assets	$ 21.7	0
SOUTHWESTERN ELECTRIC POWER COMPANY | Earns/earning a return | Approved for recovery | Plant Retirement Costs - Unrecovered Plant, Dolet Hills Power Station - Louisiana
Regulatory Asset [Line Items]
Remaining Recovery Period	8 years
Total Noncurrent Regulatory Assets	$ 19	40.8
SOUTHWESTERN ELECTRIC POWER COMPANY | Earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	12.6	13.8
SOUTHWESTERN ELECTRIC POWER COMPANY | Does not earns/earning a return | Pending final regulatory approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	108.2	69.7
SOUTHWESTERN ELECTRIC POWER COMPANY | Does not earns/earning a return | Pending final regulatory approval | Other Regulatory Assets Pending Final Regulatory Approval
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	18.7	13.7
SOUTHWESTERN ELECTRIC POWER COMPANY | Does not earns/earning a return | Pending final regulatory approval | NOLC - Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	49.6	0
SOUTHWESTERN ELECTRIC POWER COMPANY | Does not earns/earning a return | Pending final regulatory approval | Storm-Related Costs
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	39.9	56
SOUTHWESTERN ELECTRIC POWER COMPANY | Does not earns/earning a return | Approved for recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 173.8	240.9
SOUTHWESTERN ELECTRIC POWER COMPANY | Does not earns/earning a return | Approved for recovery | Plant Retirement Costs - Unrecovered Plant, Arkansas
Regulatory Asset [Line Items]
Remaining Recovery Period	3 years
Total Noncurrent Regulatory Assets	$ 12.8	17.3
SOUTHWESTERN ELECTRIC POWER COMPANY | Does not earns/earning a return | Approved for recovery | Other Regulatory Assets Approved for Recovery
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 22.1	30.1
SOUTHWESTERN ELECTRIC POWER COMPANY | Does not earns/earning a return | Approved for recovery | Pension and OPEB Funded Status
Regulatory Asset [Line Items]
Remaining Recovery Period	12 years
Total Noncurrent Regulatory Assets	$ 93.2	109.2
SOUTHWESTERN ELECTRIC POWER COMPANY | Does not earns/earning a return | Approved for recovery | Plant Retirement Costs - Unrecovered Plant, Texas
Regulatory Asset [Line Items]
Remaining Recovery Period	22 years
Total Noncurrent Regulatory Assets	$ 44.5	48.7
SOUTHWESTERN ELECTRIC POWER COMPANY | Does not earns/earning a return | Approved for recovery | Unrealized Loss on Forward Commitments
Regulatory Asset [Line Items]
Remaining Recovery Period	3 years
Total Noncurrent Regulatory Assets	$ 1.2	15.4
SOUTHWESTERN ELECTRIC POWER COMPANY | Does not earns/earning a return | Approved for recovery | North Central Wind Rider
Regulatory Asset [Line Items]
Total Noncurrent Regulatory Assets	$ 0	$ 20.2

EFFECTS OF REGULATION - Regu_17

EFFECTS OF REGULATION - Regulatory Liabilities - SWEPCO (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Regulatory Liability [Line Items]
Total Current Regulatory Liabilities	$ 53.5	$ 26.5
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	8,344	8,182.4
Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	322	207.9
Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	8,022	7,974.5
Pays/paying a return | Over-recovered Fuel Costs
Regulatory Liability [Line Items]
Total Current Regulatory Liabilities	$ 21.6	3.3
Remaining Refund Period	1 year
Pays/paying a return | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 176	103.1
Pays/paying a return | Pending final regulatory determination | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	176	103.1
Pays/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	5,526.4	5,823.1
Pays/paying a return | Approved for payment | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	1,622.1	2,179.7
Pays/paying a return | Approved for payment | Asset Removal Costs
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	3,828	3,563.5
Pays/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	40.4	35
Does not pay/paying a return | Over-recovered Fuel Costs
Regulatory Liability [Line Items]
Total Current Regulatory Liabilities	$ 31.9	23.2
Remaining Refund Period	1 year
Does not pay/paying a return | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 146	104.8
Does not pay/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 2,495.6	2,151.4
Does not pay/paying a return | Approved for payment | Over-recovered Fuel Costs
Regulatory Liability [Line Items]
Remaining Refund Period	8 years
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 32.1	26.1
Does not pay/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	90.1	106.5
SOUTHWESTERN ELECTRIC POWER COMPANY
Regulatory Liability [Line Items]
Total Current Regulatory Liabilities	21.6	3.3
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	610.8	756.1
SOUTHWESTERN ELECTRIC POWER COMPANY | Pending final regulatory determination
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	7	7
SOUTHWESTERN ELECTRIC POWER COMPANY | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	603.8	749.1
SOUTHWESTERN ELECTRIC POWER COMPANY | Pays/paying a return | Over-recovered Fuel Costs
Regulatory Liability [Line Items]
Total Current Regulatory Liabilities	$ 21.6	3.3
Remaining Refund Period	1 year
SOUTHWESTERN ELECTRIC POWER COMPANY | Pays/paying a return | Pending final regulatory determination | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 7	7
SOUTHWESTERN ELECTRIC POWER COMPANY | Pays/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	591.4	740
SOUTHWESTERN ELECTRIC POWER COMPANY | Pays/paying a return | Approved for payment | Income Taxes, Net
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	127.5	292.4
SOUTHWESTERN ELECTRIC POWER COMPANY | Pays/paying a return | Approved for payment | Asset Removal Costs
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	456.6	443.2
SOUTHWESTERN ELECTRIC POWER COMPANY | Pays/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	7.3	4.4
SOUTHWESTERN ELECTRIC POWER COMPANY | Does not pay/paying a return | Approved for payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	12.4	9.1
SOUTHWESTERN ELECTRIC POWER COMPANY | Does not pay/paying a return | Approved for payment | Other Regulatory Liabilities Approved for Payment
Regulatory Liability [Line Items]
Total Noncurrent Regulatory Liabilities and Deferred Investment Tax Credits	$ 12.4	$ 9.1

COMMITMENTS, GUARANTEES AND C_3

COMMITMENTS, GUARANTEES AND CONTINGENCIES -Contractual Commitments (Details) $ in Millions	Dec. 31, 2024 USD ($)
Other Commitments [Line Items]
Less Than 1 Year	$ 1,194.8
2-3 Years	1,326
4-5 Years	810
After 5 Years	832.3
Total	4,163.1
APPALACHIAN POWER COMPANY
Other Commitments [Line Items]
Less Than 1 Year	547.1
2-3 Years	408.5
4-5 Years	215
After 5 Years	148.2
Total	1,318.8
INDIANA MICHIGAN POWER COMPANY
Other Commitments [Line Items]
Less Than 1 Year	271.4
2-3 Years	582.8
4-5 Years	452.4
After 5 Years	585.4
Total	1,892
PUBLIC SERVICE COMPANY OF OKLAHOMA
Other Commitments [Line Items]
Less Than 1 Year	90.3
2-3 Years	140.6
4-5 Years	62.4
After 5 Years	19.7
Total	313
SOUTHWESTERN ELECTRIC POWER COMPANY
Other Commitments [Line Items]
Less Than 1 Year	100.9
2-3 Years	59.8
4-5 Years	0
After 5 Years	0
Total	160.7
Fuel Purchase Contracts
Other Commitments [Line Items]
Less Than 1 Year	1,002
2-3 Years	942
4-5 Years	475.7
After 5 Years	368.3
Total	2,788
Fuel Purchase Contracts | APPALACHIAN POWER COMPANY
Other Commitments [Line Items]
Less Than 1 Year	506.7
2-3 Years	328.6
4-5 Years	167
After 5 Years	96
Total	1,098.3
Fuel Purchase Contracts | INDIANA MICHIGAN POWER COMPANY
Other Commitments [Line Items]
Less Than 1 Year	151.5
2-3 Years	346.6
4-5 Years	220.7
After 5 Years	263.9
Total	982.7
Fuel Purchase Contracts | PUBLIC SERVICE COMPANY OF OKLAHOMA
Other Commitments [Line Items]
Less Than 1 Year	27.4
2-3 Years	17
4-5 Years	0
After 5 Years	0
Total	44.4
Fuel Purchase Contracts | SOUTHWESTERN ELECTRIC POWER COMPANY
Other Commitments [Line Items]
Less Than 1 Year	89.4
2-3 Years	46.6
4-5 Years	0
After 5 Years	0
Total	136
Energy and Capacity Purchase Contracts
Other Commitments [Line Items]
Less Than 1 Year	192.8
2-3 Years	384
4-5 Years	334.3
After 5 Years	464
Total	1,375.1
Energy and Capacity Purchase Contracts | APPALACHIAN POWER COMPANY
Other Commitments [Line Items]
Less Than 1 Year	40.4
2-3 Years	79.9
4-5 Years	48
After 5 Years	52.2
Total	220.5
Energy and Capacity Purchase Contracts | INDIANA MICHIGAN POWER COMPANY
Other Commitments [Line Items]
Less Than 1 Year	119.9
2-3 Years	236.2
4-5 Years	231.7
After 5 Years	321.5
Total	909.3
Energy and Capacity Purchase Contracts | OHIO POWER COMPANY
Other Commitments [Line Items]
Less Than 1 Year	33.2
2-3 Years	64.2
4-5 Years	66.3
After 5 Years	69.5
Total	233.2
Energy and Capacity Purchase Contracts | PUBLIC SERVICE COMPANY OF OKLAHOMA
Other Commitments [Line Items]
Less Than 1 Year	62.9
2-3 Years	123.6
4-5 Years	62.4
After 5 Years	19.7
Total	268.6
Energy and Capacity Purchase Contracts | SOUTHWESTERN ELECTRIC POWER COMPANY
Other Commitments [Line Items]
Less Than 1 Year	11.5
2-3 Years	13.2
4-5 Years	0
After 5 Years	0
Total	$ 24.7

COMMITMENTS, GUARANTEES AND C_4

COMMITMENTS, GUARANTEES AND CONTINGENCIES - Narrative (Details)	1 Months Ended	3 Months Ended	12 Months Ended
	Jul. 31, 2024 USD ($)	Sep. 30, 2024 USD ($)	Dec. 31, 2024 USD ($) site unit millsPerKWh MW	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)	Mar. 31, 2024 USD ($)	Mar. 30, 2024 USD ($)
Other Commitments [Line Items]
Litigation settlement	$ 450,000
Loss contingency, loss in period		$ 19,000,000
Cook Plant
Other Commitments [Line Items]
Nuclear contingencies, producing power | MW			2,296
INDIANA MICHIGAN POWER COMPANY | Cook Plant
Other Commitments [Line Items]
Nuclear contingencies, number of units | unit			2
Environmental Response Compensation and Liability Act (Superfund) and State Remediation
Other Commitments [Line Items]
Number of additional sites for which could lead to potentially responsible party designation | site			11
Environmental Response Compensation and Liability Act (Superfund) and State Remediation | AEP Generation Resources Inc.
Other Commitments [Line Items]
Number of sites for which potentially responsible party designation was named | site			1
Environmental Response Compensation and Liability Act (Superfund) and State Remediation | SOUTHWESTERN ELECTRIC POWER COMPANY
Other Commitments [Line Items]
Number of sites for which potentially responsible party designation was named | site			1
Environmental Response Compensation and Liability Act (Superfund) and State Remediation | OHIO POWER COMPANY
Other Commitments [Line Items]
Number of sites for which potentially responsible party designation was named | site			2
Environmental Response Compensation and Liability Act (Superfund) and State Remediation | APPALACHIAN POWER COMPANY
Other Commitments [Line Items]
Number of sites for which potentially responsible party designation was named | site			1
Decommissioning and Low Level Waste Accumulation Disposal
Other Commitments [Line Items]
Cost of decommissioning and disposal of radioactive waste			$ 2,400,000,000
Additional ongoing costs for post decommissioning storage of SNF			7,000,000
Subsequent decommissioning of the spent fuel storage facility			45,000,000
Amount recovered in rates for decommissioning costs			1,000,000	$ 2,000,000	$ 2,000,000
Decommissioning trust assets amount			4,000,000,000	3,500,000,000
Decommissioning and Low Level Waste Accumulation Disposal | INDIANA MICHIGAN POWER COMPANY
Other Commitments [Line Items]
Cost of decommissioning and disposal of radioactive waste			2,400,000,000
Additional ongoing costs for post decommissioning storage of SNF			7,000,000
Subsequent decommissioning of the spent fuel storage facility			45,000,000
Amount recovered in rates for decommissioning costs			1,000,000	2,000,000	2,000,000
Decommissioning trust assets amount			4,000,000,000	3,500,000,000
Spent Nuclear Fuel Disposal
Other Commitments [Line Items]
DOE SNF disposal fee			0
Disposal, assessed fees and related interest			316,000,000	300,000,000
Trust fund assets one time fee obligation for nuclear fuel disposition			367,000,000	348,000,000
Spent nuclear fuel storage costs recovery			12,000,000	21,000,000	3,000,000
Settlement amount recoverable for dry cask current			11,000,000	12,000,000
Settlement amount recoverable for dry cask noncurrent			$ 15,000,000	9,000,000
Spent Nuclear Fuel Disposal | INDIANA MICHIGAN POWER COMPANY
Other Commitments [Line Items]
Spent nuclear fuel obligation, fee charged | millsPerKWh			1,000,000
DOE SNF disposal fee			$ 0
Disposal, assessed fees and related interest			316,000,000	300,000,000
Trust fund assets one time fee obligation for nuclear fuel disposition			367,000,000	348,000,000
Spent nuclear fuel storage costs recovery			12,000,000	21,000,000	$ 3,000,000
Settlement amount recoverable for dry cask current			11,000,000	12,000,000
Settlement amount recoverable for dry cask noncurrent			15,000,000	$ 9,000,000
Nuclear Incident Liability
Other Commitments [Line Items]
Insurance coverage for property damage decommissioning and decontamination			2,700,000,000
Nonnuclear incident coverage for property damage decommissioning and decontamination			750,000,000
Contingent financial obligation for mutual insurance			47,000,000
Insurance protection for public liability arising from nuclear incident			16,300,000,000
Commercially available insurance			500,000,000
Assessed amount per nuclear incident			332,000,000
Deferred premium assessment annual payment			49,000,000
Commercially available insurance for catastrophic nature			500,000,000
Liability coverage under Price Anderson Act			15,800,000,000
Nuclear Incident Liability | INDIANA MICHIGAN POWER COMPANY
Other Commitments [Line Items]
Insurance coverage for property damage decommissioning and decontamination			2,700,000,000
Nonnuclear incident coverage for property damage decommissioning and decontamination			750,000,000
Contingent financial obligation for mutual insurance			47,000,000
Insurance protection for public liability arising from nuclear incident			16,300,000,000
Commercially available insurance			500,000,000
Assessed amount per nuclear incident			332,000,000
Deferred premium assessment annual payment			49,000,000
Commercially available insurance for catastrophic nature			500,000,000
Liability coverage under Price Anderson Act			15,800,000,000
Letter of Credit
Other Commitments [Line Items]
Debt instrument, face amount			450,000,000
Letter of Credit | Revolving Credit Facility
Other Commitments [Line Items]
Line of credit facility, borrowing capacity			$ 0
Letter of Credit | Revolving Credit Facility | Subsidiaries
Other Commitments [Line Items]
Line of credit facility, borrowing capacity						$ 1,200,000,000
Letter of Credit | Revolving Credit Facility | Letter Of Credit, Due March 2029
Other Commitments [Line Items]
Line of credit facility, borrowing capacity						5,000,000,000
Letter of Credit | Revolving Credit Facility | Letter Of Credit, Due March 2027
Other Commitments [Line Items]
Line of credit facility, borrowing capacity						$ 1,000,000,000	$ 4,000,000,000

COMMITMENTS, GUARANTEES AND C_5

COMMITMENTS, GUARANTEES AND CONTINGENCIES - Future Payments (Details) - Letter of Credit $ in Millions	Dec. 31, 2024 USD ($)
Other Commitments [Line Items]
Future payments	$ 238
AEP TEXAS INC.
Other Commitments [Line Items]
Future payments	$ 1.8

COMMITMENTS, GUARANTEES AND C_6

COMMITMENTS, GUARANTEES AND CONTINGENCIES - ARO CCR Rule (Details) - USD ($) $ in Millions	Dec. 31, 2024	Jun. 30, 2024	Dec. 31, 2023	Dec. 31, 2022
Other Commitments [Line Items]
Increase in ARO	$ 3,611.7		$ 3,031.2	$ 2,943.6
CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		$ 674.4
Increase in Generation Property | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		176.9
Increase in Regulatory Assets | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		355
Charged to Operating Expenses | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		142.5
APPALACHIAN POWER COMPANY
Other Commitments [Line Items]
Increase in ARO	801.7		464	427.7
APPALACHIAN POWER COMPANY | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		312.2
APPALACHIAN POWER COMPANY | Increase in Generation Property | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		75.6
APPALACHIAN POWER COMPANY | Increase in Regulatory Assets | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		236.6
APPALACHIAN POWER COMPANY | Charged to Operating Expenses | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		0
INDIANA MICHIGAN POWER COMPANY
Other Commitments [Line Items]
Increase in ARO	2,093.8		2,106	2,028.1
INDIANA MICHIGAN POWER COMPANY | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		85.7
INDIANA MICHIGAN POWER COMPANY | Increase in Generation Property | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		0
INDIANA MICHIGAN POWER COMPANY | Increase in Regulatory Assets | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		72.3
INDIANA MICHIGAN POWER COMPANY | Charged to Operating Expenses | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		13.4
OHIO POWER COMPANY
Other Commitments [Line Items]
Increase in ARO	56.3		2.1	5
OHIO POWER COMPANY | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		52.9
OHIO POWER COMPANY | Increase in Generation Property | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		0
OHIO POWER COMPANY | Increase in Regulatory Assets | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		0
OHIO POWER COMPANY | Charged to Operating Expenses | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		52.9
PUBLIC SERVICE COMPANY OF OKLAHOMA
Other Commitments [Line Items]
Increase in ARO	121.8		84.2	75.7
PUBLIC SERVICE COMPANY OF OKLAHOMA | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		33.7
PUBLIC SERVICE COMPANY OF OKLAHOMA | Increase in Generation Property | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		33.7
PUBLIC SERVICE COMPANY OF OKLAHOMA | Increase in Regulatory Assets | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		0
PUBLIC SERVICE COMPANY OF OKLAHOMA | Charged to Operating Expenses | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		0
SOUTHWESTERN ELECTRIC POWER COMPANY
Other Commitments [Line Items]
Increase in ARO	$ 278.7		$ 281.6	$ 280.9
SOUTHWESTERN ELECTRIC POWER COMPANY | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		23.8
SOUTHWESTERN ELECTRIC POWER COMPANY | Increase in Generation Property | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		23.8
SOUTHWESTERN ELECTRIC POWER COMPANY | Increase in Regulatory Assets | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		0
SOUTHWESTERN ELECTRIC POWER COMPANY | Charged to Operating Expenses | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		0
Non Registrant | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		166.1
Non Registrant | Increase in Generation Property | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		43.8
Non Registrant | Increase in Regulatory Assets | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		46.1
Non Registrant | Charged to Operating Expenses | CCR Rule Revision
Other Commitments [Line Items]
Increase in ARO		$ 76.2

ACQUISITIONS, DISPOSITIONS AN_2

ACQUISITIONS, DISPOSITIONS AND IMPAIRMENTS (Details) $ in Millions

1 Months Ended

3 Months Ended

12 Months Ended

Dec. 31, 2024 USD ($) MW

Sep. 30, 2024 USD ($)

Feb. 29, 2024 USD ($)

Dec. 31, 2023 USD ($)

Aug. 31, 2023 USD ($)

Mar. 31, 2023 USD ($)

Jun. 30, 2022 USD ($)

Mar. 31, 2022 USD ($)

Jan. 31, 2022 USD ($)

Dec. 31, 2023 USD ($)

Mar. 31, 2023 USD ($)

Sep. 30, 2022 USD ($)

Jun. 30, 2022 USD ($)

Dec. 31, 2024 USD ($) MW

Dec. 31, 2023 USD ($)

Dec. 31, 2022 USD ($)

Dec. 31, 2020 property MW

Oct. 31, 2021 USD ($)

Dec. 31, 2019 partnership counterparty joint_venture

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Asset impairment charges

$ 142.5

$ 85.6

$ 48.8

Loss on the Sale of the Competitive Contracted Renewables Portfolio

0

92.7

0

Other than temporary impairment

0

19

188

Kentucky Operations

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Asset impairment charges

363

Useful life

30 years

30 years

SOUTHWESTERN ELECTRIC POWER COMPANY

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Asset impairment charges

$ 0

85.6

$ 0

VIU

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Wind generation MW | MW

1,484

Enterprise value

$ 2,850

Decrease in expected transaction costs

$ 28

Pretax reduction in investment basis

$ 335

335

VIU | Diversion Wind Energy, LLC

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Wind generation MW | MW

201

Percentage of shares acquired

100%

100%

Property, plant and equipment, gross

$ 423

$ 423

Operating lease

20

20

Asset retirement obligations

$ 6

$ 6

VIU | Proceeds for KY Operations

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Enterprise value

$ 2,646

VIU | PUBLIC SERVICE COMPANY OF OKLAHOMA

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Business combination, consideration transferred

146

VIU | SOUTHWESTERN ELECTRIC POWER COMPANY | Turk Generating Plant

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Asset impairment charges

$ 86

VIU | SOUTHWESTERN ELECTRIC POWER COMPANY | Dolet Hills Power Station

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Asset impairment charges

$ 12

VIU | Traverse

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Wind generation MW | MW

998

Payments to acquire facilities

$ 1,200

VIU | Maverick

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Wind generation MW | MW

287

VIU | Sundance

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Wind generation MW | MW

199

VIU | North Central Wind Energy Facilities

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Number of properties | property

3

Payments to acquire facilities

$ 2,000

VIU | PUBLIC SERVICE COMPANY OF OKLAHOMA

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Percentage of voting interest acquired

45.50%

45.50%

VIU | SOUTHWESTERN ELECTRIC POWER COMPANY

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Percentage of voting interest acquired

54.50%

54.50%

Generation & Marketing | Disposal Group, Disposed of by Sale, Not Discontinued Operations | AEP OnSite Partners

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Proceeds from disposal of business

$ 318

Generation & Marketing | Disposal Group, Disposed of by Sale, Not Discontinued Operations | New Mexico Renewable Development

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Proceeds from disposal of business

$ 107

AEPTHCo

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Enterprise value

$ 2,850

Pretax reduction in investment basis

$ 335

$ 335

AEPTHCo | Proceeds for KY Operations

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Enterprise value

2,646

G&M

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Loss on the Sale of the Competitive Contracted Renewables Portfolio

93

Gain (loss) on disposal of business, net of tax

$ 73

G&M | New Mexico Renewable Development

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Other than temporary impairment

$ 19

G&M | BP Wind Energy

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Other than temporary impairment

$ 2

$ 186

Ownership percentage

50%

Number of tax equity partnerships acquired interests in | partnership

2

Number of counterparties with long-term power purchase agreement | counterparty

3

Number of non-consolidated joint ventures acquired interests in | joint_venture

5

G&M | Proceeds of Mineral Rights Sale

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Gain (loss) on disposition of other assets

$ 116

G&M | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Competitive Contracted Renewables

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Proceeds from disposal of business

$ 1,200

G&M | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Proceeds of Mineral Rights Sale

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Proceeds from sale of acquisition

$ 120

BENEFIT PLANS - Schedule of Def

BENEFIT PLANS - Schedule of Defined Benefit Assumptions (Details)	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Health Care Trend Rates
Initial	6.50%	7%
Ultimate	4.50%	4.50%
Year Ultimate Reached	2029	2030
AEP TEXAS INC.
Health Care Trend Rates
Initial	6.50%	7%
Ultimate	4.50%	4.50%
Year Ultimate Reached	2029	2030
APPALACHIAN POWER COMPANY
Health Care Trend Rates
Initial	6.50%	7%
Ultimate	4.50%	4.50%
Year Ultimate Reached	2029	2030
SOUTHWESTERN ELECTRIC POWER COMPANY
Health Care Trend Rates
Initial	6.50%	7%
Ultimate	4.50%	4.50%
Year Ultimate Reached	2029	2030
INDIANA MICHIGAN POWER COMPANY
Health Care Trend Rates
Initial	6.50%	7%
Ultimate	4.50%	4.50%
Year Ultimate Reached	2029	2030
PUBLIC SERVICE COMPANY OF OKLAHOMA
Health Care Trend Rates
Initial	6.50%	7%
Ultimate	4.50%	4.50%
Year Ultimate Reached	2029	2030
OHIO POWER COMPANY
Health Care Trend Rates
Initial	6.50%	7%
Ultimate	4.50%	4.50%
Year Ultimate Reached	2029	2030
Pension Plans
Assumption
Discount Rate	5.65%	5.15%
Interest Crediting Rate	4.55%	4%
Rate of Compensation Increase	5.55%	5.05%
Assumption
Discount Rate	5.20%	5.50%	2.90%
Interest Crediting Rate	4.05%	4.25%	4%
Expected Return on Plan Assets	7.30%	7.50%	5.25%
Rate of Compensation Increase	5.10%	5.05%	5.05%
Pension Plans | Minimum
Assumption
Rate of Compensation Increase	3%
Pension Plans | Maximum
Assumption
Rate of Compensation Increase	11.50%
Pension Plans | AEP TEXAS INC.
Assumption
Discount Rate	5.65%	5.15%
Interest Crediting Rate	4.55%	4%
Rate of Compensation Increase	5.70%	5.20%
Assumption
Discount Rate	5.20%	5.50%	2.90%
Interest Crediting Rate	4.05%	4.25%	4%
Expected Return on Plan Assets	7.30%	7.50%	5.25%
Rate of Compensation Increase	5.25%	5.20%	5.15%
Pension Plans | AEP TEXAS INC. | Minimum
Assumption
Rate of Compensation Increase	3%
Pension Plans | AEP TEXAS INC. | Maximum
Assumption
Rate of Compensation Increase	11.50%
Pension Plans | APPALACHIAN POWER COMPANY
Assumption
Discount Rate	5.65%	5.15%
Interest Crediting Rate	4.55%	4%
Rate of Compensation Increase	5.55%	4.95%
Assumption
Discount Rate	5.20%	5.50%	2.90%
Interest Crediting Rate	4.05%	4.25%	4%
Expected Return on Plan Assets	7.30%	7.50%	5.25%
Rate of Compensation Increase	5.10%	4.95%	4.90%
Pension Plans | APPALACHIAN POWER COMPANY | Minimum
Assumption
Rate of Compensation Increase	3%
Pension Plans | APPALACHIAN POWER COMPANY | Maximum
Assumption
Rate of Compensation Increase	11.50%
Pension Plans | SOUTHWESTERN ELECTRIC POWER COMPANY
Assumption
Discount Rate	5.65%	5.15%
Interest Crediting Rate	4.55%	4%
Rate of Compensation Increase	5.55%	5%
Assumption
Discount Rate	5.20%	5.50%	2.90%
Interest Crediting Rate	4.05%	4.25%	4%
Expected Return on Plan Assets	7.30%	7.50%	5.25%
Rate of Compensation Increase	5.10%	5%	5%
Pension Plans | SOUTHWESTERN ELECTRIC POWER COMPANY | Minimum
Assumption
Rate of Compensation Increase	3%
Pension Plans | SOUTHWESTERN ELECTRIC POWER COMPANY | Maximum
Assumption
Rate of Compensation Increase	11.50%
Pension Plans | INDIANA MICHIGAN POWER COMPANY
Assumption
Discount Rate	5.65%	5.15%
Interest Crediting Rate	4.55%	4%
Rate of Compensation Increase	5.50%	5.05%
Assumption
Discount Rate	5.20%	5.50%	2.90%
Interest Crediting Rate	4.05%	4.25%	4%
Expected Return on Plan Assets	7.30%	7.50%	5.25%
Rate of Compensation Increase	5.10%	5.05%	5%
Pension Plans | INDIANA MICHIGAN POWER COMPANY | Minimum
Assumption
Rate of Compensation Increase	3%
Pension Plans | INDIANA MICHIGAN POWER COMPANY | Maximum
Assumption
Rate of Compensation Increase	11.50%
Pension Plans | PUBLIC SERVICE COMPANY OF OKLAHOMA
Assumption
Discount Rate	5.65%	5.15%
Interest Crediting Rate	4.55%	4%
Rate of Compensation Increase	5.70%	5.20%
Assumption
Discount Rate	5.20%	5.50%	2.90%
Interest Crediting Rate	4.05%	4.25%	4%
Expected Return on Plan Assets	7.30%	7.50%	5.25%
Rate of Compensation Increase	5.20%	5.20%	5.15%
Pension Plans | PUBLIC SERVICE COMPANY OF OKLAHOMA | Minimum
Assumption
Rate of Compensation Increase	3%
Pension Plans | PUBLIC SERVICE COMPANY OF OKLAHOMA | Maximum
Assumption
Rate of Compensation Increase	11.50%
Pension Plans | OHIO POWER COMPANY
Assumption
Discount Rate	5.65%	5.15%
Interest Crediting Rate	4.55%	4%
Rate of Compensation Increase	6%	5.45%
Assumption
Discount Rate	5.20%	5.50%	2.90%
Interest Crediting Rate	4.05%	4.25%	4%
Expected Return on Plan Assets	7.30%	7.50%	5.25%
Rate of Compensation Increase	5.50%	5.45%	5.35%
Pension Plans | OHIO POWER COMPANY | Minimum
Assumption
Rate of Compensation Increase	3%
Pension Plans | OHIO POWER COMPANY | Maximum
Assumption
Rate of Compensation Increase	11.50%
OPEB
Assumption
Discount Rate	5.60%	5.15%
Assumption
Discount Rate	5.15%	5.50%	2.90%
Expected Return on Plan Assets	6.75%	7.25%	5.50%
OPEB | AEP TEXAS INC.
Assumption
Discount Rate	5.60%	5.15%
Assumption
Discount Rate	5.15%	5.50%	2.90%
Expected Return on Plan Assets	6.75%	7.25%	5.50%
OPEB | APPALACHIAN POWER COMPANY
Assumption
Discount Rate	5.60%	5.15%
Assumption
Discount Rate	5.15%	5.50%	2.90%
Expected Return on Plan Assets	6.75%	7.25%	5.50%
OPEB | SOUTHWESTERN ELECTRIC POWER COMPANY
Assumption
Discount Rate	5.60%	5.15%
Assumption
Discount Rate	5.15%	5.50%	2.90%
Expected Return on Plan Assets	6.75%	7.25%	5.50%
OPEB | INDIANA MICHIGAN POWER COMPANY
Assumption
Discount Rate	5.60%	5.15%
Assumption
Discount Rate	5.15%	5.50%	2.90%
Expected Return on Plan Assets	6.75%	7.25%	5.50%
OPEB | PUBLIC SERVICE COMPANY OF OKLAHOMA
Assumption
Discount Rate	5.60%	5.15%
Assumption
Discount Rate	5.15%	5.50%	2.90%
Expected Return on Plan Assets	6.75%	7.25%	5.50%
OPEB | OHIO POWER COMPANY
Assumption
Discount Rate	5.60%	5.15%
Assumption
Discount Rate	5.15%	5.50%	2.90%
Expected Return on Plan Assets	6.75%	7.25%	5.50%

BENEFIT PLANS - Narrative (Deta

BENEFIT PLANS - Narrative (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Defined Benefit Plan Disclosure [Line Items]
Life insurance administrative load	5%
Investment gains or losses period	5 years
Employer contribution cost	$ 379	$ 396	$ 329
Withdrawal liability	$ 12,000	$ 13,000
Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	5.55%	5.05%
Minimum | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	3%
Maximum | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	11.50%
AEP TEXAS INC. | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	5.70%	5.20%
AEP TEXAS INC. | Minimum | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	3%
AEP TEXAS INC. | Maximum | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	11.50%
APPALACHIAN POWER COMPANY | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	5.55%	4.95%
APPALACHIAN POWER COMPANY | Minimum | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	3%
APPALACHIAN POWER COMPANY | Maximum | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	11.50%
PUBLIC SERVICE COMPANY OF OKLAHOMA | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	5.70%	5.20%
PUBLIC SERVICE COMPANY OF OKLAHOMA | Minimum | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	3%
PUBLIC SERVICE COMPANY OF OKLAHOMA | Maximum | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	11.50%
OHIO POWER COMPANY | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	6%	5.45%
OHIO POWER COMPANY | Minimum | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	3%
OHIO POWER COMPANY | Maximum | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	11.50%
INDIANA MICHIGAN POWER COMPANY | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	5.50%	5.05%
INDIANA MICHIGAN POWER COMPANY | Minimum | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	3%
INDIANA MICHIGAN POWER COMPANY | Maximum | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	11.50%
SOUTHWESTERN ELECTRIC POWER COMPANY | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	5.55%	5%
SOUTHWESTERN ELECTRIC POWER COMPANY | Minimum | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	3%
SOUTHWESTERN ELECTRIC POWER COMPANY | Maximum | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Rate of compensation increase	11.50%
Defined Contribution, Employer Matching Conditions One
Defined Benefit Plan Disclosure [Line Items]
Employer matching contribution, percent of match	100%
Employer matching contribution, percent of employees contribution	1%
Defined Contribution, Employer Matching Conditions One | AEP TEXAS INC.
Defined Benefit Plan Disclosure [Line Items]
Employer matching contribution, percent of match	100%
Employer matching contribution, percent of employees contribution	1%
Defined Contribution, Employer Matching Conditions One | APPALACHIAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Employer matching contribution, percent of match	100%
Employer matching contribution, percent of employees contribution	1%
Defined Contribution, Employer Matching Conditions One | PUBLIC SERVICE COMPANY OF OKLAHOMA
Defined Benefit Plan Disclosure [Line Items]
Employer matching contribution, percent of match	100%
Employer matching contribution, percent of employees contribution	1%
Defined Contribution, Employer Matching Conditions One | OHIO POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Employer matching contribution, percent of match	100%
Employer matching contribution, percent of employees contribution	1%
Defined Contribution, Employer Matching Conditions One | INDIANA MICHIGAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Employer matching contribution, percent of match	100%
Employer matching contribution, percent of employees contribution	1%
Defined Contribution, Employer Matching Conditions One | SOUTHWESTERN ELECTRIC POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Employer matching contribution, percent of match	100%
Employer matching contribution, percent of employees contribution	1%
Defined Contribution, Employer Matching Conditions Two
Defined Benefit Plan Disclosure [Line Items]
Employer matching contribution, percent of match	70%
Employer matching contribution, percent of employees contribution	5%
Defined Contribution, Employer Matching Conditions Two | AEP TEXAS INC.
Defined Benefit Plan Disclosure [Line Items]
Employer matching contribution, percent of match	70%
Employer matching contribution, percent of employees contribution	5%
Defined Contribution, Employer Matching Conditions Two | APPALACHIAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Employer matching contribution, percent of match	70%
Employer matching contribution, percent of employees contribution	5%
Defined Contribution, Employer Matching Conditions Two | PUBLIC SERVICE COMPANY OF OKLAHOMA
Defined Benefit Plan Disclosure [Line Items]
Employer matching contribution, percent of match	70%
Employer matching contribution, percent of employees contribution	5%
Defined Contribution, Employer Matching Conditions Two | OHIO POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Employer matching contribution, percent of match	70%
Employer matching contribution, percent of employees contribution	5%
Defined Contribution, Employer Matching Conditions Two | INDIANA MICHIGAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Employer matching contribution, percent of match	70%
Employer matching contribution, percent of employees contribution	5%
Defined Contribution, Employer Matching Conditions Two | SOUTHWESTERN ELECTRIC POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Employer matching contribution, percent of match	70%
Employer matching contribution, percent of employees contribution	5%

BENEFIT PLANS - Schedule of Obl

BENEFIT PLANS - Schedule of Obligation and Funded Status (Details) - USD ($)	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Qualified Plans
Change in Fair Value of Plan Assets
Company Contributions	$ 0	$ 0
Nonqualified Plans
Change in Fair Value of Plan Assets
Company Contributions	14,000,000	8,000,000
Pension Plans
Change in Benefit Obligation
Benefit Obligation as of January 1,	4,161,600,000	4,072,700,000
Service Cost	100,600,000	94,300,000	$ 123,100,000
Interest Cost	207,400,000	219,200,000	148,200,000
Actuarial (Gain) Loss	(44,600,000)	144,000,000
Settlements	(329,400,000)
Benefit Payments	(223,800,000)	(368,600,000)
Benefit Obligation as of December 31,	3,871,800,000	4,161,600,000	4,072,700,000
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1,	4,118,200,000	4,124,700,000
Actual Gain on Plan Assets	87,200,000	353,800,000
Company Contributions	14,000,000	8,300,000
Settlements	(329,400,000)
Benefit Payments	(223,800,000)	(368,600,000)
Fair Value of Plan Assets as of December 31,	3,666,200,000	4,118,200,000	4,124,700,000
Funded (Underfunded) Status as of December 31,	(205,600,000)	(43,400,000)
Pension Plans | AEP TEXAS INC.
Change in Benefit Obligation
Benefit Obligation as of January 1,	343,100,000	334,100,000
Service Cost	8,900,000	8,200,000	11,100,000
Interest Cost	17,300,000	18,300,000	12,100,000
Actuarial (Gain) Loss	5,500,000	20,100,000
Settlements	(34,800,000)
Benefit Payments	(17,300,000)	(37,600,000)
Benefit Obligation as of December 31,	322,700,000	343,100,000	334,100,000
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1,	332,700,000	335,100,000
Actual Gain on Plan Assets	7,100,000	34,800,000
Company Contributions	400,000	400,000
Settlements	(34,800,000)
Benefit Payments	(17,300,000)	(37,600,000)
Fair Value of Plan Assets as of December 31,	288,100,000	332,700,000	335,100,000
Funded (Underfunded) Status as of December 31,	(34,600,000)	(10,400,000)
Pension Plans | APPALACHIAN POWER COMPANY
Change in Benefit Obligation
Benefit Obligation as of January 1,	504,100,000	485,700,000
Service Cost	9,500,000	9,100,000	11,400,000
Interest Cost	24,700,000	26,400,000	17,500,000
Actuarial (Gain) Loss	(12,900,000)	23,200,000
Settlements	(42,000,000)
Benefit Payments	(30,400,000)	(40,300,000)
Benefit Obligation as of December 31,	453,000,000	504,100,000	485,700,000
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1,	549,800,000	531,700,000
Actual Gain on Plan Assets	10,400,000	58,400,000
Company Contributions	0	0
Settlements	(42,000,000)
Benefit Payments	(30,400,000)	(40,300,000)
Fair Value of Plan Assets as of December 31,	487,800,000	549,800,000	531,700,000
Funded (Underfunded) Status as of December 31,	34,800,000	45,700,000
Pension Plans | INDIANA MICHIGAN POWER COMPANY
Change in Benefit Obligation
Benefit Obligation as of January 1,	477,000,000	466,800,000
Service Cost	13,000,000	11,900,000	16,200,000
Interest Cost	23,900,000	24,900,000	17,000,000
Actuarial (Gain) Loss	(8,400,000)	8,500,000
Settlements	(33,100,000)
Benefit Payments	(22,600,000)	(35,100,000)
Benefit Obligation as of December 31,	449,800,000	477,000,000	466,800,000
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1,	550,600,000	533,700,000
Actual Gain on Plan Assets	11,600,000	51,500,000
Company Contributions	0	500,000
Settlements	(33,100,000)
Benefit Payments	(22,600,000)	(35,100,000)
Fair Value of Plan Assets as of December 31,	506,500,000	550,600,000	533,700,000
Funded (Underfunded) Status as of December 31,	56,700,000	73,600,000
Pension Plans | OHIO POWER COMPANY
Change in Benefit Obligation
Benefit Obligation as of January 1,	378,400,000	363,600,000
Service Cost	9,200,000	8,400,000	11,200,000
Interest Cost	18,800,000	19,800,000	13,300,000
Actuarial (Gain) Loss	(8,300,000)	17,500,000
Settlements	(23,200,000)
Benefit Payments	(24,200,000)	(30,900,000)
Benefit Obligation as of December 31,	350,700,000	378,400,000	363,600,000
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1,	419,500,000	406,400,000
Actual Gain on Plan Assets	8,600,000	44,000,000
Company Contributions	0	0
Settlements	(23,200,000)
Benefit Payments	(24,200,000)	(30,900,000)
Fair Value of Plan Assets as of December 31,	380,700,000	419,500,000	406,400,000
Funded (Underfunded) Status as of December 31,	30,000,000	41,100,000
Pension Plans | PUBLIC SERVICE COMPANY OF OKLAHOMA
Change in Benefit Obligation
Benefit Obligation as of January 1,	202,200,000	192,300,000
Service Cost	5,900,000	5,500,000	7,400,000
Interest Cost	10,100,000	10,700,000	7,000,000
Actuarial (Gain) Loss	100,000	13,600,000
Settlements	(18,500,000)
Benefit Payments	(9,600,000)	(19,900,000)
Benefit Obligation as of December 31,	190,200,000	202,200,000	192,300,000
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1,	222,700,000	218,500,000
Actual Gain on Plan Assets	5,000,000	24,000,000
Company Contributions	100,000	100,000
Settlements	(18,500,000)
Benefit Payments	(9,600,000)	(19,900,000)
Fair Value of Plan Assets as of December 31,	199,700,000	222,700,000	218,500,000
Funded (Underfunded) Status as of December 31,	9,500,000	20,500,000
Pension Plans | SOUTHWESTERN ELECTRIC POWER COMPANY
Change in Benefit Obligation
Benefit Obligation as of January 1,	261,200,000	250,700,000
Service Cost	7,800,000	7,700,000	10,600,000
Interest Cost	12,500,000	13,900,000	9,100,000
Actuarial (Gain) Loss	(11,200,000)	16,800,000
Settlements	(33,100,000)
Benefit Payments	(9,400,000)	(27,900,000)
Benefit Obligation as of December 31,	227,800,000	261,200,000	250,700,000
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1,	227,500,000	231,300,000
Actual Gain on Plan Assets	3,600,000	23,900,000
Company Contributions	200,000	200,000
Settlements	(33,100,000)
Benefit Payments	(9,400,000)	(27,900,000)
Fair Value of Plan Assets as of December 31,	188,800,000	227,500,000	231,300,000
Funded (Underfunded) Status as of December 31,	(39,000,000)	(33,700,000)
OPEB
Change in Benefit Obligation
Benefit Obligation as of January 1,	849,500,000	872,600,000
Service Cost	4,500,000	4,600,000	7,400,000
Interest Cost	42,000,000	46,200,000	29,200,000
Actuarial (Gain) Loss	(192,300,000)	19,800,000
Special/Contractual Termination Benefits	3,500,000
Benefit Payments	(105,800,000)	(137,800,000)
Participant Contributions	44,900,000	43,600,000
Medicare Subsidy	300,000	500,000
Benefit Obligation as of December 31,	646,600,000	849,500,000	872,600,000
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1,	1,673,300,000	1,549,300,000
Actual Gain on Plan Assets	159,200,000	213,200,000
Company Contributions	4,300,000	5,000,000
Participant Contributions	44,900,000	43,600,000
Benefit Payments	(105,800,000)	(137,800,000)
Fair Value of Plan Assets as of December 31,	1,775,900,000	1,673,300,000	1,549,300,000
Funded (Underfunded) Status as of December 31,	1,129,300,000	823,800,000
OPEB | AEP TEXAS INC.
Change in Benefit Obligation
Benefit Obligation as of January 1,	66,400,000	68,600,000
Service Cost	300,000	300,000	500,000
Interest Cost	3,300,000	3,600,000	2,200,000
Actuarial (Gain) Loss	(15,400,000)	1,200,000
Special/Contractual Termination Benefits	400,000
Benefit Payments	(8,300,000)	(10,700,000)
Participant Contributions	3,500,000	3,400,000
Medicare Subsidy	0	0
Benefit Obligation as of December 31,	50,200,000	66,400,000	68,600,000
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1,	137,500,000	128,300,000
Actual Gain on Plan Assets	14,000,000	16,500,000
Company Contributions	0	0
Participant Contributions	3,500,000	3,400,000
Benefit Payments	(8,300,000)	(10,700,000)
Fair Value of Plan Assets as of December 31,	146,700,000	137,500,000	128,300,000
Funded (Underfunded) Status as of December 31,	96,500,000	71,100,000
OPEB | APPALACHIAN POWER COMPANY
Change in Benefit Obligation
Benefit Obligation as of January 1,	134,600,000	140,700,000
Service Cost	500,000	500,000	800,000
Interest Cost	6,600,000	7,400,000	4,700,000
Actuarial (Gain) Loss	(30,400,000)	900,000
Special/Contractual Termination Benefits	600,000
Benefit Payments	(16,700,000)	(21,600,000)
Participant Contributions	6,800,000	6,600,000
Medicare Subsidy	100,000	100,000
Benefit Obligation as of December 31,	102,100,000	134,600,000	140,700,000
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1,	243,000,000	228,600,000
Actual Gain on Plan Assets	22,500,000	28,100,000
Company Contributions	800,000	1,300,000
Participant Contributions	6,800,000	6,600,000
Benefit Payments	(16,700,000)	(21,600,000)
Fair Value of Plan Assets as of December 31,	256,400,000	243,000,000	228,600,000
Funded (Underfunded) Status as of December 31,	154,300,000	108,400,000
OPEB | INDIANA MICHIGAN POWER COMPANY
Change in Benefit Obligation
Benefit Obligation as of January 1,	98,800,000	101,900,000
Service Cost	600,000	600,000	900,000
Interest Cost	4,800,000	5,400,000	3,400,000
Actuarial (Gain) Loss	(24,700,000)	3,200,000
Special/Contractual Termination Benefits	400,000
Benefit Payments	(13,400,000)	(18,300,000)
Participant Contributions	6,000,000	6,000,000
Medicare Subsidy	0	0
Benefit Obligation as of December 31,	72,500,000	98,800,000	101,900,000
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1,	204,600,000	190,500,000
Actual Gain on Plan Assets	14,700,000	26,400,000
Company Contributions	0	0
Participant Contributions	6,000,000	6,000,000
Benefit Payments	(13,400,000)	(18,300,000)
Fair Value of Plan Assets as of December 31,	211,900,000	204,600,000	190,500,000
Funded (Underfunded) Status as of December 31,	139,400,000	105,800,000
OPEB | OHIO POWER COMPANY
Change in Benefit Obligation
Benefit Obligation as of January 1,	85,900,000	88,900,000
Service Cost	400,000	400,000	600,000
Interest Cost	4,200,000	4,700,000	3,000,000
Actuarial (Gain) Loss	(20,700,000)	2,200,000
Special/Contractual Termination Benefits	300,000
Benefit Payments	(11,300,000)	(15,000,000)
Participant Contributions	4,600,000	4,700,000
Medicare Subsidy	0	0
Benefit Obligation as of December 31,	63,400,000	85,900,000	88,900,000
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1,	177,800,000	166,200,000
Actual Gain on Plan Assets	14,100,000	21,900,000
Company Contributions	0	0
Participant Contributions	4,600,000	4,700,000
Benefit Payments	(11,300,000)	(15,000,000)
Fair Value of Plan Assets as of December 31,	185,200,000	177,800,000	166,200,000
Funded (Underfunded) Status as of December 31,	121,800,000	91,900,000
OPEB | PUBLIC SERVICE COMPANY OF OKLAHOMA
Change in Benefit Obligation
Benefit Obligation as of January 1,	43,700,000	45,700,000
Service Cost	300,000	300,000	400,000
Interest Cost	2,100,000	2,400,000	1,500,000
Actuarial (Gain) Loss	(10,400,000)	400,000
Special/Contractual Termination Benefits	100,000
Benefit Payments	(5,800,000)	(7,600,000)
Participant Contributions	2,600,000	2,500,000
Medicare Subsidy	0	0
Benefit Obligation as of December 31,	32,600,000	43,700,000	45,700,000
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1,	90,200,000	85,400,000
Actual Gain on Plan Assets	8,300,000	9,900,000
Company Contributions	0	0
Participant Contributions	2,600,000	2,500,000
Benefit Payments	(5,800,000)	(7,600,000)
Fair Value of Plan Assets as of December 31,	95,300,000	90,200,000	85,400,000
Funded (Underfunded) Status as of December 31,	62,700,000	46,500,000
OPEB | SOUTHWESTERN ELECTRIC POWER COMPANY
Change in Benefit Obligation
Benefit Obligation as of January 1,	53,700,000	55,100,000
Service Cost	400,000	400,000	600,000
Interest Cost	2,700,000	2,900,000	1,800,000
Actuarial (Gain) Loss	(11,500,000)	1,200,000
Special/Contractual Termination Benefits	300,000
Benefit Payments	(7,400,000)	(8,800,000)
Participant Contributions	3,300,000	2,900,000
Medicare Subsidy	0	0
Benefit Obligation as of December 31,	41,500,000	53,700,000	55,100,000
Change in Fair Value of Plan Assets
Fair Value of Plan Assets as of January 1,	111,100,000	103,000,000
Actual Gain on Plan Assets	14,200,000	14,000,000
Company Contributions	0	0
Participant Contributions	3,300,000	2,900,000
Benefit Payments	(7,400,000)	(8,800,000)
Fair Value of Plan Assets as of December 31,	121,200,000	111,100,000	$ 103,000,000
Funded (Underfunded) Status as of December 31,	$ 79,700,000	$ 57,400,000

BENEFIT PLANS - Schedule of Amo

BENEFIT PLANS - Schedule of Amounts Included on the Balance Sheets (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Other Noncurrent Assets - Employee Benefits and Pension Assets	$ 0	$ 17.3
Other Current Liabilities – Accrued Short-term Benefit Liability	(5.2)	(6.7)
Other Noncurrent Liabilities – Accrued Long-term Benefit Liability	(200.4)	(54)
Funded (Underfunded) Status	(205.6)	(43.4)
Pension Plans | AEP TEXAS INC.
Defined Benefit Plan Disclosure [Line Items]
Other Noncurrent Assets - Employee Benefits and Pension Assets	0	0.1
Other Current Liabilities – Accrued Short-term Benefit Liability	(0.3)	(0.3)
Other Noncurrent Liabilities – Accrued Long-term Benefit Liability	(34.3)	(10.2)
Funded (Underfunded) Status	(34.6)	(10.4)
Pension Plans | APPALACHIAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Other Noncurrent Assets - Employee Benefits and Pension Assets	35.2	46
Other Current Liabilities – Accrued Short-term Benefit Liability	0	0
Other Noncurrent Liabilities – Accrued Long-term Benefit Liability	(0.4)	(0.3)
Funded (Underfunded) Status	34.8	45.7
Pension Plans | INDIANA MICHIGAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Other Noncurrent Assets - Employee Benefits and Pension Assets	58.2	74.8
Other Current Liabilities – Accrued Short-term Benefit Liability	0	0
Other Noncurrent Liabilities – Accrued Long-term Benefit Liability	(1.5)	(1.2)
Funded (Underfunded) Status	56.7	73.6
Pension Plans | OHIO POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Other Noncurrent Assets - Employee Benefits and Pension Assets	30.3	41.4
Other Current Liabilities – Accrued Short-term Benefit Liability	0	0
Other Noncurrent Liabilities – Accrued Long-term Benefit Liability	(0.3)	(0.3)
Funded (Underfunded) Status	30	41.1
Pension Plans | PUBLIC SERVICE COMPANY OF OKLAHOMA
Defined Benefit Plan Disclosure [Line Items]
Other Noncurrent Assets - Employee Benefits and Pension Assets	10.9	21.8
Other Current Liabilities – Accrued Short-term Benefit Liability	(0.1)	(0.1)
Other Noncurrent Liabilities – Accrued Long-term Benefit Liability	(1.3)	(1.2)
Funded (Underfunded) Status	9.5	20.5
Pension Plans | SOUTHWESTERN ELECTRIC POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Other Noncurrent Assets - Employee Benefits and Pension Assets	0	0
Other Current Liabilities – Accrued Short-term Benefit Liability	(0.1)	(0.1)
Other Noncurrent Liabilities – Accrued Long-term Benefit Liability	(38.9)	(33.6)
Funded (Underfunded) Status	(39)	(33.7)
OPEB
Defined Benefit Plan Disclosure [Line Items]
Other Noncurrent Assets - Employee Benefits and Pension Assets	1,130.8	838
Other Current Liabilities – Accrued Short-term Benefit Liability	(2.2)	(2.4)
Other Noncurrent Liabilities – Accrued Long-term Benefit Liability	0.7	(11.8)
Funded (Underfunded) Status	1,129.3	823.8
OPEB | AEP TEXAS INC.
Defined Benefit Plan Disclosure [Line Items]
Other Noncurrent Assets - Employee Benefits and Pension Assets	96.5	71.1
Other Current Liabilities – Accrued Short-term Benefit Liability	0	0
Other Noncurrent Liabilities – Accrued Long-term Benefit Liability	0	0
Funded (Underfunded) Status	96.5	71.1
OPEB | APPALACHIAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Other Noncurrent Assets - Employee Benefits and Pension Assets	168.7	125.6
Other Current Liabilities – Accrued Short-term Benefit Liability	(1.4)	(1.6)
Other Noncurrent Liabilities – Accrued Long-term Benefit Liability	(13)	(15.6)
Funded (Underfunded) Status	154.3	108.4
OPEB | INDIANA MICHIGAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Other Noncurrent Assets - Employee Benefits and Pension Assets	139.4	105.8
Other Current Liabilities – Accrued Short-term Benefit Liability	0	0
Other Noncurrent Liabilities – Accrued Long-term Benefit Liability	0	0
Funded (Underfunded) Status	139.4	105.8
OPEB | OHIO POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Other Noncurrent Assets - Employee Benefits and Pension Assets	121.8	91.9
Other Current Liabilities – Accrued Short-term Benefit Liability	0	0
Other Noncurrent Liabilities – Accrued Long-term Benefit Liability	0	0
Funded (Underfunded) Status	121.8	91.9
OPEB | PUBLIC SERVICE COMPANY OF OKLAHOMA
Defined Benefit Plan Disclosure [Line Items]
Other Noncurrent Assets - Employee Benefits and Pension Assets	62.7	46.5
Other Current Liabilities – Accrued Short-term Benefit Liability	0	0
Other Noncurrent Liabilities – Accrued Long-term Benefit Liability	0	0
Funded (Underfunded) Status	62.7	46.5
OPEB | SOUTHWESTERN ELECTRIC POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Other Noncurrent Assets - Employee Benefits and Pension Assets	79.7	57.4
Other Current Liabilities – Accrued Short-term Benefit Liability	0	0
Other Noncurrent Liabilities – Accrued Long-term Benefit Liability	0	0
Funded (Underfunded) Status	$ 79.7	$ 57.4

BENEFIT PLANS - Schedule of A_2

BENEFIT PLANS - Schedule of Amounts Included in Regulatory Assets, Deferred Income Taxes and AOCI (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Net Actuarial (Gain) Loss	$ 1,153.5	$ 1,063.4
Prior Service Cost	0.2	0.2
Actuarial Gain (Loss) During the Year	188	129.2
Amortization of Actuarial Loss	(4.5)	(1.4)
Amounts Recognized Due to Settlement	(93.4)
Change for the Year	90.1	127.8
Pension Plans | Regulatory Assets
Defined Benefit Plan Disclosure [Line Items]
Recorded as	1,019.8	938.6
Pension Plans | Deferred Income Taxes
Defined Benefit Plan Disclosure [Line Items]
Recorded as	28.2	26.4
Pension Plans | Net of Tax AOCI
Defined Benefit Plan Disclosure [Line Items]
Recorded as	105.7	98.6
Pension Plans | AEP TEXAS INC.
Defined Benefit Plan Disclosure [Line Items]
Net Actuarial (Gain) Loss	189.3	175.2
Prior Service Cost	0	0
Actuarial Gain (Loss) During the Year	24.2	13.4
Amortization of Actuarial Loss	(0.3)	(0.1)
Amounts Recognized Due to Settlement	(9.8)
Change for the Year	14.1	13.3
Pension Plans | AEP TEXAS INC. | Regulatory Assets
Defined Benefit Plan Disclosure [Line Items]
Recorded as	176.7	163.4
Pension Plans | AEP TEXAS INC. | Deferred Income Taxes
Defined Benefit Plan Disclosure [Line Items]
Recorded as	2.8	2.7
Pension Plans | AEP TEXAS INC. | Net of Tax AOCI
Defined Benefit Plan Disclosure [Line Items]
Recorded as	9.8	9.1
Pension Plans | APPALACHIAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Net Actuarial (Gain) Loss	112.1	104.9
Prior Service Cost	0	0
Actuarial Gain (Loss) During the Year	19.4	9.3
Amortization of Actuarial Loss	(0.4)	0
Amounts Recognized Due to Settlement	(11.8)
Change for the Year	7.2	9.3
Pension Plans | APPALACHIAN POWER COMPANY | Regulatory Assets
Defined Benefit Plan Disclosure [Line Items]
Recorded as	109.9	102.6
Pension Plans | APPALACHIAN POWER COMPANY | Deferred Income Taxes
Defined Benefit Plan Disclosure [Line Items]
Recorded as	0.4	0.4
Pension Plans | APPALACHIAN POWER COMPANY | Net of Tax AOCI
Defined Benefit Plan Disclosure [Line Items]
Recorded as	1.8	1.9
Pension Plans | INDIANA MICHIGAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Net Actuarial (Gain) Loss	7.5	(5.8)
Prior Service Cost	0	0
Actuarial Gain (Loss) During the Year	23	1.2
Amortization of Actuarial Loss	(0.4)	(0.1)
Amounts Recognized Due to Settlement	(9.3)
Change for the Year	13.3	1.1
Pension Plans | INDIANA MICHIGAN POWER COMPANY | Regulatory Assets
Defined Benefit Plan Disclosure [Line Items]
Recorded as	17.5	6.4
Pension Plans | INDIANA MICHIGAN POWER COMPANY | Deferred Income Taxes
Defined Benefit Plan Disclosure [Line Items]
Recorded as	(2.2)	(2.6)
Pension Plans | INDIANA MICHIGAN POWER COMPANY | Net of Tax AOCI
Defined Benefit Plan Disclosure [Line Items]
Recorded as	(7.8)	(9.6)
Pension Plans | OHIO POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Net Actuarial (Gain) Loss	140.9	131.9
Prior Service Cost	0	0
Actuarial Gain (Loss) During the Year	15.8	7.6
Amortization of Actuarial Loss	(0.3)	0
Amounts Recognized Due to Settlement	(6.5)
Change for the Year	9	7.6
Pension Plans | OHIO POWER COMPANY | Regulatory Assets
Defined Benefit Plan Disclosure [Line Items]
Recorded as	140.9	131.9
Pension Plans | OHIO POWER COMPANY | Deferred Income Taxes
Defined Benefit Plan Disclosure [Line Items]
Recorded as	0	0
Pension Plans | OHIO POWER COMPANY | Net of Tax AOCI
Defined Benefit Plan Disclosure [Line Items]
Recorded as	0	0
Pension Plans | PUBLIC SERVICE COMPANY OF OKLAHOMA
Defined Benefit Plan Disclosure [Line Items]
Net Actuarial (Gain) Loss	53.8	46.7
Prior Service Cost	0	0
Actuarial Gain (Loss) During the Year	12.5	7.9
Amortization of Actuarial Loss	(0.2)	0
Amounts Recognized Due to Settlement	(5.2)
Change for the Year	7.1	7.9
Pension Plans | PUBLIC SERVICE COMPANY OF OKLAHOMA | Regulatory Assets
Defined Benefit Plan Disclosure [Line Items]
Recorded as	53.8	46.7
Pension Plans | PUBLIC SERVICE COMPANY OF OKLAHOMA | Deferred Income Taxes
Defined Benefit Plan Disclosure [Line Items]
Recorded as	0	0
Pension Plans | PUBLIC SERVICE COMPANY OF OKLAHOMA | Net of Tax AOCI
Defined Benefit Plan Disclosure [Line Items]
Recorded as	0	0
Pension Plans | SOUTHWESTERN ELECTRIC POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Net Actuarial (Gain) Loss	82.9	89.6
Prior Service Cost	0	0
Actuarial Gain (Loss) During the Year	2.7	12.1
Amortization of Actuarial Loss	(0.1)	(0.1)
Amounts Recognized Due to Settlement	(9.3)
Change for the Year	(6.7)	12
Pension Plans | SOUTHWESTERN ELECTRIC POWER COMPANY | Regulatory Assets
Defined Benefit Plan Disclosure [Line Items]
Recorded as	83	89.7
Pension Plans | SOUTHWESTERN ELECTRIC POWER COMPANY | Deferred Income Taxes
Defined Benefit Plan Disclosure [Line Items]
Recorded as	0	0
Pension Plans | SOUTHWESTERN ELECTRIC POWER COMPANY | Net of Tax AOCI
Defined Benefit Plan Disclosure [Line Items]
Recorded as	(0.1)	(0.1)
OPEB
Defined Benefit Plan Disclosure [Line Items]
Net Actuarial (Gain) Loss	(41.6)	201.5
Prior Service Cost	(14.7)	(27.4)
Actuarial Gain (Loss) During the Year	(240.1)	(83.7)
Amortization of Actuarial Loss	(3)	(14.8)
Amortization of Prior Service Credit	12.7	63.1
Change for the Year	(230.4)	(35.4)
OPEB | Regulatory Assets
Defined Benefit Plan Disclosure [Line Items]
Recorded as	(55.4)	106.1
OPEB | Deferred Income Taxes
Defined Benefit Plan Disclosure [Line Items]
Recorded as	(0.1)	14.3
OPEB | Net of Tax AOCI
Defined Benefit Plan Disclosure [Line Items]
Recorded as	(0.8)	53.7
OPEB | AEP TEXAS INC.
Defined Benefit Plan Disclosure [Line Items]
Net Actuarial (Gain) Loss	1.6	22.1
Prior Service Cost	(1.3)	(2.3)
Actuarial Gain (Loss) During the Year	(20.3)	(6.4)
Amortization of Actuarial Loss	(0.2)	(1.2)
Amortization of Prior Service Credit	1	5.3
Change for the Year	(19.5)	(2.3)
OPEB | AEP TEXAS INC. | Regulatory Assets
Defined Benefit Plan Disclosure [Line Items]
Recorded as	0.8	19.8
OPEB | AEP TEXAS INC. | Deferred Income Taxes
Defined Benefit Plan Disclosure [Line Items]
Recorded as	0	0
OPEB | AEP TEXAS INC. | Net of Tax AOCI
Defined Benefit Plan Disclosure [Line Items]
Recorded as	(0.5)	0
OPEB | APPALACHIAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Net Actuarial (Gain) Loss	(9.9)	27.1
Prior Service Cost	(2.3)	(4.2)
Actuarial Gain (Loss) During the Year	(36.6)	(11.1)
Amortization of Actuarial Loss	(0.4)	(2.3)
Amortization of Prior Service Credit	1.9	9.2
Change for the Year	(35.1)	(4.2)
OPEB | APPALACHIAN POWER COMPANY | Regulatory Assets
Defined Benefit Plan Disclosure [Line Items]
Recorded as	(2)	13.2
OPEB | APPALACHIAN POWER COMPANY | Deferred Income Taxes
Defined Benefit Plan Disclosure [Line Items]
Recorded as	(2.2)	2
OPEB | APPALACHIAN POWER COMPANY | Net of Tax AOCI
Defined Benefit Plan Disclosure [Line Items]
Recorded as	(8)	7.7
OPEB | INDIANA MICHIGAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Net Actuarial (Gain) Loss	2.3	28.7
Prior Service Cost	(2)	(3.7)
Actuarial Gain (Loss) During the Year	(25.9)	(9.6)
Amortization of Actuarial Loss	(0.5)	(1.9)
Amortization of Prior Service Credit	1.7	8.7
Change for the Year	(24.7)	(2.8)
OPEB | INDIANA MICHIGAN POWER COMPANY | Regulatory Assets
Defined Benefit Plan Disclosure [Line Items]
Recorded as	(2.9)	19
OPEB | INDIANA MICHIGAN POWER COMPANY | Deferred Income Taxes
Defined Benefit Plan Disclosure [Line Items]
Recorded as	0.7	1.3
OPEB | INDIANA MICHIGAN POWER COMPANY | Net of Tax AOCI
Defined Benefit Plan Disclosure [Line Items]
Recorded as	2.5	4.7
OPEB | OHIO POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Net Actuarial (Gain) Loss	(5.3)	18.1
Prior Service Cost	(1.6)	(2.9)
Actuarial Gain (Loss) During the Year	(23)	(7.9)
Amortization of Actuarial Loss	(0.4)	(1.6)
Amortization of Prior Service Credit	1.3	6.3
Change for the Year	(22.1)	(3.2)
OPEB | OHIO POWER COMPANY | Regulatory Assets
Defined Benefit Plan Disclosure [Line Items]
Recorded as	(6.9)	15.2
OPEB | OHIO POWER COMPANY | Deferred Income Taxes
Defined Benefit Plan Disclosure [Line Items]
Recorded as	0	0
OPEB | OHIO POWER COMPANY | Net of Tax AOCI
Defined Benefit Plan Disclosure [Line Items]
Recorded as	0	0
OPEB | PUBLIC SERVICE COMPANY OF OKLAHOMA
Defined Benefit Plan Disclosure [Line Items]
Net Actuarial (Gain) Loss	4.7	17.5
Prior Service Cost	(0.9)	(1.6)
Actuarial Gain (Loss) During the Year	(12.6)	(3.7)
Amortization of Actuarial Loss	(0.2)	(0.8)
Amortization of Prior Service Credit	0.7	4
Change for the Year	(12.1)	(0.5)
OPEB | PUBLIC SERVICE COMPANY OF OKLAHOMA | Regulatory Assets
Defined Benefit Plan Disclosure [Line Items]
Recorded as	3.8	15.9
OPEB | PUBLIC SERVICE COMPANY OF OKLAHOMA | Deferred Income Taxes
Defined Benefit Plan Disclosure [Line Items]
Recorded as	0	0
OPEB | PUBLIC SERVICE COMPANY OF OKLAHOMA | Net of Tax AOCI
Defined Benefit Plan Disclosure [Line Items]
Recorded as	0	0
OPEB | SOUTHWESTERN ELECTRIC POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Net Actuarial (Gain) Loss	0	18.4
Prior Service Cost	(1)	(2.1)
Actuarial Gain (Loss) During the Year	(18.1)	(5.6)
Amortization of Actuarial Loss	(0.3)	(1)
Amortization of Prior Service Credit	1.1	4.9
Change for the Year	(17.3)	(1.7)
OPEB | SOUTHWESTERN ELECTRIC POWER COMPANY | Regulatory Assets
Defined Benefit Plan Disclosure [Line Items]
Recorded as	0.5	10.2
OPEB | SOUTHWESTERN ELECTRIC POWER COMPANY | Deferred Income Taxes
Defined Benefit Plan Disclosure [Line Items]
Recorded as	(0.3)	1.3
OPEB | SOUTHWESTERN ELECTRIC POWER COMPANY | Net of Tax AOCI
Defined Benefit Plan Disclosure [Line Items]
Recorded as	$ (1.2)	$ 4.8

BENEFIT PLANS - Schedule of Pen

BENEFIT PLANS - Schedule of Pension and OPEB Assets (Details)	Dec. 31, 2024	Dec. 31, 2023
Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Asset allocations	100%	100%
Pension Plans | AEP TEXAS INC.
Defined Benefit Plan Disclosure [Line Items]
Asset allocations	7.90%	8.10%
Pension Plans | APPALACHIAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Asset allocations	13.30%	13.40%
Pension Plans | INDIANA MICHIGAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Asset allocations	13.80%	13.40%
Pension Plans | OHIO POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Asset allocations	10.40%	10.20%
Pension Plans | PUBLIC SERVICE COMPANY OF OKLAHOMA
Defined Benefit Plan Disclosure [Line Items]
Asset allocations	5.50%	5.40%
Pension Plans | SOUTHWESTERN ELECTRIC POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Asset allocations	5.20%	5.50%
OPEB
Defined Benefit Plan Disclosure [Line Items]
Asset allocations	100%	100%
OPEB | AEP TEXAS INC.
Defined Benefit Plan Disclosure [Line Items]
Asset allocations	8.30%	8.20%
OPEB | APPALACHIAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Asset allocations	14.40%	14.50%
OPEB | INDIANA MICHIGAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Asset allocations	11.90%	12.20%
OPEB | OHIO POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Asset allocations	10.40%	10.60%
OPEB | PUBLIC SERVICE COMPANY OF OKLAHOMA
Defined Benefit Plan Disclosure [Line Items]
Asset allocations	5.40%	5.40%
OPEB | SOUTHWESTERN ELECTRIC POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Asset allocations	6.80%	6.60%

BENEFIT PLANS - Schedule of Ass

BENEFIT PLANS - Schedule of Assets by Fair Value (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 3,666.2	$ 4,118.2	$ 4,124.7
Year End Allocation	100%	100%
OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 1,775.9	$ 1,673.3	$ 1,549.3
Year End Allocation	100%	100%
Level 1 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 791	$ 809.4
Level 1 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	1,033.1	897.8
Level 2 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	1,788.9	2,252.1
Level 2 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	463.5	501.2
Level 3 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0.1
Level 3 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Other | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	1,086.3	1,056.6
Other | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	279.3	274.3
Equities | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 1,265.9	$ 1,222
Year End Allocation	34.50%	29.70%
Equities | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 1,077.6	$ 960.6
Year End Allocation	60.60%	57.40%
Equities | Level 1 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 793.3	$ 801.1
Equities | Level 1 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	948.2	829
Equities | Level 2 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Equities | Level 2 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Equities | Level 3 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Equities | Level 3 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Equities | Other | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	472.6	420.9
Equities | Other | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	129.4	131.6
Domestic | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 327	$ 411.3
Year End Allocation	8.90%	10%
Domestic | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 616.8	$ 540.6
Year End Allocation	34.70%	32.30%
Domestic | Level 1 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 327	$ 411.3
Domestic | Level 1 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	616.8	540.6
Domestic | Level 2 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Domestic | Level 2 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Domestic | Level 3 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Domestic | Level 3 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Domestic | Other | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Domestic | Other | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
International | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 290.2	$ 389.8
Year End Allocation	7.90%	9.50%
International | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 267.2	$ 288.4
Year End Allocation	15%	17.20%
International | Level 1 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 290.2	$ 389.8
International | Level 1 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	267.2	288.4
International | Level 2 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
International | Level 2 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
International | Level 3 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
International | Level 3 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
International | Other | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
International | Other | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Common Collective Trusts | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 648.7	$ 420.9
Year End Allocation	17.70%	10.20%
Common Collective Trusts | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 193.6	$ 131.6
Year End Allocation	10.90%	7.90%
Common Collective Trusts | Level 1 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 176.1	$ 0
Common Collective Trusts | Level 1 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	64.2	0
Common Collective Trusts | Level 2 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Common Collective Trusts | Level 2 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Common Collective Trusts | Level 3 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Common Collective Trusts | Level 3 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Common Collective Trusts | Other | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	472.6	420.9
Common Collective Trusts | Other | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	129.4	131.6
Fixed Income | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 1,745.3	$ 2,209.4
Year End Allocation	47.60%	53.60%
Fixed Income | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 512.4	$ 538.5
Year End Allocation	28.90%	32.20%
Fixed Income | Level 1 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ (2.3)	$ 8.3
Fixed Income | Level 1 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	57.3	42.9
Fixed Income | Level 2 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	1,747.6	2,201.1
Fixed Income | Level 2 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	322.2	348.9
Fixed Income | Level 3 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fixed Income | Level 3 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fixed Income | Other | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Fixed Income | Other | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	132.9	146.7
Common Collective Trust - Debt | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 132.9	$ 146.7
Year End Allocation	7.50%	8.80%
Common Collective Trust - Debt | Level 1 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 0	$ 0
Common Collective Trust - Debt | Level 2 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Common Collective Trust - Debt | Level 3 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Common Collective Trust - Debt | Other | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	132.9	146.7
United States Government and Agency Securities | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 863.3	$ 1,107.5
Year End Allocation	23.60%	26.90%
United States Government and Agency Securities | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 157.1	$ 164.7
Year End Allocation	8.90%	9.80%
United States Government and Agency Securities | Level 1 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ (2.3)	$ 8.3
United States Government and Agency Securities | Level 1 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	(0.5)	1.4
United States Government and Agency Securities | Level 2 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	865.6	1,099.2
United States Government and Agency Securities | Level 2 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	157.6	163.3
United States Government and Agency Securities | Level 3 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
United States Government and Agency Securities | Level 3 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
United States Government and Agency Securities | Other | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
United States Government and Agency Securities | Other | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Corporate Debt | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 719.2	$ 894.8
Year End Allocation	19.60%	21.70%
Corporate Debt | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 132.3	$ 149
Year End Allocation	7.50%	8.90%
Corporate Debt | Level 1 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 0	$ 0
Corporate Debt | Level 1 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Corporate Debt | Level 2 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	719.2	894.8
Corporate Debt | Level 2 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	132.3	149
Corporate Debt | Level 3 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Corporate Debt | Level 3 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Corporate Debt | Other | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Corporate Debt | Other | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Foreign Debt | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 136.1	$ 167.1
Year End Allocation	3.70%	4.10%
Foreign Debt | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 27.1	$ 28.6
Year End Allocation	1.50%	1.70%
Foreign Debt | Level 1 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 0	$ 0
Foreign Debt | Level 1 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Foreign Debt | Level 2 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	136.1	167.1
Foreign Debt | Level 2 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	27.1	28.6
Foreign Debt | Level 3 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Foreign Debt | Level 3 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Foreign Debt | Other | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Foreign Debt | Other | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
State and Local Government | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 25.8	$ 38.7
Year End Allocation	0.70%	0.90%
State and Local Government | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 62.8	$ 49.3
Year End Allocation	3.50%	3%
State and Local Government | Level 1 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 0	$ 0
State and Local Government | Level 1 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	57.8	41.5
State and Local Government | Level 2 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	25.8	38.7
State and Local Government | Level 2 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	5	7.8
State and Local Government | Level 3 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
State and Local Government | Level 3 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
State and Local Government | Other | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
State and Local Government | Other | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Other – Asset Backed | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 0.9	$ 1.3
Year End Allocation	0%	0%
Other – Asset Backed | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 0.2	$ 0.2
Year End Allocation	0%	0%
Other – Asset Backed | Level 1 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 0	$ 0
Other – Asset Backed | Level 1 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Other – Asset Backed | Level 2 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0.9	1.3
Other – Asset Backed | Level 2 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0.2	0.2
Other – Asset Backed | Level 3 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Other – Asset Backed | Level 3 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Other – Asset Backed | Other | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Other – Asset Backed | Other | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Infrastructure | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 112.9	$ 101.4
Year End Allocation	3.10%	2.50%
Infrastructure | Level 1 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 0	$ 0
Infrastructure | Level 2 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Infrastructure | Level 3 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Infrastructure | Other | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	112.9	101.4
Real Estate | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 227.9	$ 239.3
Year End Allocation	6.20%	5.80%
Real Estate | Level 1 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 0	$ 0
Real Estate | Level 2 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Real Estate | Level 3 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Real Estate | Other | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	227.9	239.3
Alternative Investments | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 223.8	$ 241.8
Year End Allocation	6.10%	5.80%
Alternative Investments | Level 1 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 0	$ 0
Alternative Investments | Level 2 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Alternative Investments | Level 3 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Alternative Investments | Other | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	223.8	241.8
Trusted Owned Life Insurance | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 141.3	$ 152.3
Year End Allocation	8%	9.10%
Trusted Owned Life Insurance | Level 1 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 0	$ 0
Trusted Owned Life Insurance | Level 2 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	141.3	152.3
Trusted Owned Life Insurance | Level 3 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Trusted Owned Life Insurance | Other | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
International Equities | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 23.1	$ 22.3
Year End Allocation	1.30%	1.30%
International Equities | Level 1 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 0	$ 0
International Equities | Level 2 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	23.1	22.3
International Equities | Level 3 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
International Equities | Other | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
United States Bonds | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 118.2	$ 130
Year End Allocation	6.70%	7.80%
United States Bonds | Level 1 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 0	$ 0
United States Bonds | Level 2 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	118.2	130
United States Bonds | Level 3 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
United States Bonds | Other | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Cash and Cash Equivalents | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 68.5	$ 84.8
Year End Allocation	1.90%	2.10%
Cash and Cash Equivalents | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 30.7	$ 28.8
Year End Allocation	1.70%	1.70%
Cash and Cash Equivalents | Level 1 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 0	$ 0
Cash and Cash Equivalents | Level 1 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	27.6	25.9
Cash and Cash Equivalents | Level 2 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	41.3	51
Cash and Cash Equivalents | Level 2 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Cash and Cash Equivalents | Level 3 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Cash and Cash Equivalents | Level 3 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Cash and Cash Equivalents | Other | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	27.2	33.8
Cash and Cash Equivalents | Other | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	3.1	2.9
Other Pending Transactions and Accrued Income | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 21.9	$ 19.5
Year End Allocation	0.60%	0.50%
Other Pending Transactions and Accrued Income | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 13.9	$ (6.9)
Year End Allocation	0.80%	(0.40%)
Other Pending Transactions and Accrued Income | Level 1 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 0	$ 0
Other Pending Transactions and Accrued Income | Level 1 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Other Pending Transactions and Accrued Income | Level 2 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Other Pending Transactions and Accrued Income | Level 2 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Other Pending Transactions and Accrued Income | Level 3 | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0.1
Other Pending Transactions and Accrued Income | Level 3 | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	0	0
Other Pending Transactions and Accrued Income | Other | Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	21.9	19.4
Other Pending Transactions and Accrued Income | Other | OPEB
Defined Benefit Plan Disclosure [Line Items]
Fair Value of Plan Assets	$ 13.9	$ (6.9)

BENEFIT PLANS - Schedule of Acc

BENEFIT PLANS - Schedule of Accumulated Benefit Obligation (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	$ 3,649.3	$ 3,933.5
Qualified Plans
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	3,602.4	3,878.7
Nonqualified Plans
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	46.9	54.8
AEP TEXAS INC.
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	302.7	323.2
AEP TEXAS INC. | Qualified Plans
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	300.6	321.1
AEP TEXAS INC. | Nonqualified Plans
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	2.1	2.1
APPALACHIAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	434.5	485.7
APPALACHIAN POWER COMPANY | Qualified Plans
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	434.3	485.6
APPALACHIAN POWER COMPANY | Nonqualified Plans
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	0.2	0.1
INDIANA MICHIGAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	423.2	451
INDIANA MICHIGAN POWER COMPANY | Qualified Plans
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	422.3	450.3
INDIANA MICHIGAN POWER COMPANY | Nonqualified Plans
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	0.9	0.7
OHIO POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	326.5	354.1
OHIO POWER COMPANY | Qualified Plans
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	326.4	354
OHIO POWER COMPANY | Nonqualified Plans
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	0.1	0.1
PUBLIC SERVICE COMPANY OF OKLAHOMA
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	175.7	187.8
PUBLIC SERVICE COMPANY OF OKLAHOMA | Qualified Plans
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	174.6	186.6
PUBLIC SERVICE COMPANY OF OKLAHOMA | Nonqualified Plans
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	1.1	1.2
SOUTHWESTERN ELECTRIC POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	210.5	242.9
SOUTHWESTERN ELECTRIC POWER COMPANY | Qualified Plans
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	209.5	241.9
SOUTHWESTERN ELECTRIC POWER COMPANY | Nonqualified Plans
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	$ 1	$ 1

BENEFIT PLANS - Schedule of O_2

BENEFIT PLANS - Schedule of Obligations in Excess of Fair Values Projected Benefit Obligation (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Defined Benefit Plan Disclosure [Line Items]
Projected Benefit Obligation	$ 3,871.8	$ 60.7
Fair Value of Plan Assets	3,666.2	0
Underfunded Projected Benefit Obligation	(205.6)	(60.7)
AEP TEXAS INC.
Defined Benefit Plan Disclosure [Line Items]
Projected Benefit Obligation	322.7	343.1
Fair Value of Plan Assets	288.1	332.7
Underfunded Projected Benefit Obligation	(34.6)	(10.4)
APPALACHIAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Projected Benefit Obligation	0.5	0.4
Fair Value of Plan Assets	0	0
Underfunded Projected Benefit Obligation	(0.5)	(0.4)
INDIANA MICHIGAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Projected Benefit Obligation	1.5	1.2
Fair Value of Plan Assets	0	0
Underfunded Projected Benefit Obligation	(1.5)	(1.2)
OHIO POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Projected Benefit Obligation	0.4	0.3
Fair Value of Plan Assets	0	0
Underfunded Projected Benefit Obligation	(0.4)	(0.3)
PUBLIC SERVICE COMPANY OF OKLAHOMA
Defined Benefit Plan Disclosure [Line Items]
Projected Benefit Obligation	1.4	1.4
Fair Value of Plan Assets	0	0
Underfunded Projected Benefit Obligation	(1.4)	(1.4)
SOUTHWESTERN ELECTRIC POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Projected Benefit Obligation	227.8	261.2
Fair Value of Plan Assets	188.8	227.5
Underfunded Projected Benefit Obligation	$ (39)	$ (33.7)

BENEFIT PLANS - Schedule of O_3

BENEFIT PLANS - Schedule of Obligations in Excess of Fair Values Accumulated Benefit Obligation (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	$ 46.9	$ 54.8
Fair Value of Plan Assets	0	0
Underfunded Accumulated Benefit Obligation	(46.9)	(54.8)
AEP TEXAS INC.
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	302.7	2.1
Fair Value of Plan Assets	288	0
Underfunded Accumulated Benefit Obligation	(14.7)	(2.1)
APPALACHIAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	0.2	0.1
Fair Value of Plan Assets	0	0
Underfunded Accumulated Benefit Obligation	(0.2)	(0.1)
INDIANA MICHIGAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	0.9	0.7
Fair Value of Plan Assets	0	0
Underfunded Accumulated Benefit Obligation	(0.9)	(0.7)
OHIO POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	0.1	0.1
Fair Value of Plan Assets	0	0
Underfunded Accumulated Benefit Obligation	(0.1)	(0.1)
PUBLIC SERVICE COMPANY OF OKLAHOMA
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	1.1	1.2
Fair Value of Plan Assets	0	0
Underfunded Accumulated Benefit Obligation	(1.1)	(1.2)
SOUTHWESTERN ELECTRIC POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Accumulated Benefit Obligation	210.5	242.9
Fair Value of Plan Assets	188.9	227.5
Underfunded Accumulated Benefit Obligation	$ (21.6)	$ (15.4)

BENEFIT PLANS - Schedule of Est

BENEFIT PLANS - Schedule of Estimated Future Benefit Payments and Contributions (Details) $ in Millions	Dec. 31, 2024 USD ($)
Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Expected contributions and payments during the next fiscal year	$ 101.2
Pension Plans | AEP TEXAS INC.
Defined Benefit Plan Disclosure [Line Items]
Expected contributions and payments during the next fiscal year	11.8
Pension Plans | APPALACHIAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Expected contributions and payments during the next fiscal year	0.5
Pension Plans | INDIANA MICHIGAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Expected contributions and payments during the next fiscal year	2.6
Pension Plans | OHIO POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Expected contributions and payments during the next fiscal year	0
Pension Plans | PUBLIC SERVICE COMPANY OF OKLAHOMA
Defined Benefit Plan Disclosure [Line Items]
Expected contributions and payments during the next fiscal year	2
Pension Plans | SOUTHWESTERN ELECTRIC POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Expected contributions and payments during the next fiscal year	8.8
OPEB
Defined Benefit Plan Disclosure [Line Items]
Expected contributions and payments during the next fiscal year	2.7
OPEB | AEP TEXAS INC.
Defined Benefit Plan Disclosure [Line Items]
Expected contributions and payments during the next fiscal year	0
OPEB | APPALACHIAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Expected contributions and payments during the next fiscal year	1.4
OPEB | INDIANA MICHIGAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Expected contributions and payments during the next fiscal year	0
OPEB | OHIO POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Expected contributions and payments during the next fiscal year	0
OPEB | PUBLIC SERVICE COMPANY OF OKLAHOMA
Defined Benefit Plan Disclosure [Line Items]
Expected contributions and payments during the next fiscal year	0
OPEB | SOUTHWESTERN ELECTRIC POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Expected contributions and payments during the next fiscal year	$ 0

BENEFIT PLANS - Schedule of Exp

BENEFIT PLANS - Schedule of Expected Benefit Payments (Details) $ in Millions	Dec. 31, 2024 USD ($)
Pension Plans
Pension Plans and OPEB Benefit Payments
2025	$ 341.5
2026	340.4
2027	334.8
2028	335.7
2029	322.7
Years 2030 to 2034, in Total	1,530.3
Pension Plans | AEP TEXAS INC.
Pension Plans and OPEB Benefit Payments
2025	32.2
2026	31
2027	28.8
2028	29.5
2029	27.8
Years 2030 to 2034, in Total	120.9
Pension Plans | APPALACHIAN POWER COMPANY
Pension Plans and OPEB Benefit Payments
2025	42.3
2026	42.1
2027	40
2028	40.2
2029	38.6
Years 2030 to 2034, in Total	181.6
Pension Plans | INDIANA MICHIGAN POWER COMPANY
Pension Plans and OPEB Benefit Payments
2025	40.1
2026	40.1
2027	39
2028	38.8
2029	37.1
Years 2030 to 2034, in Total	179
Pension Plans | OHIO POWER COMPANY
Pension Plans and OPEB Benefit Payments
2025	31.6
2026	31
2027	30.8
2028	30
2029	29.5
Years 2030 to 2034, in Total	137.8
Pension Plans | PUBLIC SERVICE COMPANY OF OKLAHOMA
Pension Plans and OPEB Benefit Payments
2025	17.3
2026	17.1
2027	17.1
2028	16.9
2029	15.1
Years 2030 to 2034, in Total	73.3
Pension Plans | SOUTHWESTERN ELECTRIC POWER COMPANY
Pension Plans and OPEB Benefit Payments
2025	20.7
2026	19.2
2027	20.4
2028	19.4
2029	19
Years 2030 to 2034, in Total	88.4
OPEB
Pension Plans and OPEB Benefit Payments
2025	117.6
2026	116.4
2027	114.6
2028	112.4
2029	109.7
Years 2030 to 2034, in Total	504.7
OPEB Medicare Subsidy Receipts
2025	0.2
2026	0.3
2027	0.3
2027	0.3
2029	0.3
Years 2030 to 2034, in Total	1.4
OPEB | AEP TEXAS INC.
Pension Plans and OPEB Benefit Payments
2025	9.5
2026	9.7
2027	9.7
2028	9.3
2029	8.9
Years 2030 to 2034, in Total	39.7
OPEB Medicare Subsidy Receipts
2025	0
2026	0
2027	0
2027	0
2029	0
Years 2030 to 2034, in Total	0
OPEB | APPALACHIAN POWER COMPANY
Pension Plans and OPEB Benefit Payments
2025	18.8
2026	18.4
2027	18.1
2028	17.9
2029	17.4
Years 2030 to 2034, in Total	78.1
OPEB Medicare Subsidy Receipts
2025	0.1
2026	0.1
2027	0.1
2027	0.1
2029	0.1
Years 2030 to 2034, in Total	0.4
OPEB | INDIANA MICHIGAN POWER COMPANY
Pension Plans and OPEB Benefit Payments
2025	14.5
2026	14.5
2027	14.2
2028	13.9
2029	13.6
Years 2030 to 2034, in Total	61
OPEB Medicare Subsidy Receipts
2025	0
2026	0
2027	0
2027	0
2029	0
Years 2030 to 2034, in Total	0
OPEB | OHIO POWER COMPANY
Pension Plans and OPEB Benefit Payments
2025	12
2026	11.7
2027	11.5
2028	11.4
2029	11
Years 2030 to 2034, in Total	50.6
OPEB Medicare Subsidy Receipts
2025	0
2026	0
2027	0
2027	0
2029	0
Years 2030 to 2034, in Total	0
OPEB | PUBLIC SERVICE COMPANY OF OKLAHOMA
Pension Plans and OPEB Benefit Payments
2025	6.6
2026	6.6
2027	6.3
2028	6
2029	5.9
Years 2030 to 2034, in Total	27.2
OPEB Medicare Subsidy Receipts
2025	0
2026	0
2027	0
2027	0
2029	0
Years 2030 to 2034, in Total	0
OPEB | SOUTHWESTERN ELECTRIC POWER COMPANY
Pension Plans and OPEB Benefit Payments
2025	8.6
2026	8.3
2027	8
2028	8
2029	7.8
Years 2030 to 2034, in Total	35.7
OPEB Medicare Subsidy Receipts
2025	0
2026	0
2027	0
2027	0
2029	0
Years 2030 to 2034, in Total	$ 0

BENEFIT PLANS - Schedule of Com

BENEFIT PLANS - Schedule of Components of Net Periodic Benefit Cost (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Service Cost	$ 100.6	$ 94.3	$ 123.1
Interest Cost	207.4	219.2	148.2
Expected Return on Plan Assets	(319.8)	(339.2)	(253.4)
Amortization of Net Actuarial Loss	4.5	1.4	63
Settlements	93.4
Net Periodic Benefit Cost (Credit)	86.1	(24.3)	80.9
Capitalized Portion	(46.6)	(43.6)	(53.8)
Net Periodic Benefit Cost (Credit) Recognized in Expense	39.5	(67.9)	27.1
Pension Plans | AEP TEXAS INC.
Defined Benefit Plan Disclosure [Line Items]
Service Cost	8.9	8.2	11.1
Interest Cost	17.3	18.3	12.1
Expected Return on Plan Assets	(25.7)	(28.1)	(21)
Amortization of Net Actuarial Loss	0.3	0.1	5.2
Settlements	9.8
Net Periodic Benefit Cost (Credit)	10.6	(1.5)	7.4
Capitalized Portion	(5.3)	(4.7)	(6.2)
Net Periodic Benefit Cost (Credit) Recognized in Expense	5.3	(6.2)	1.2
Pension Plans | APPALACHIAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Service Cost	9.5	9.1	11.4
Interest Cost	24.7	26.4	17.5
Expected Return on Plan Assets	(42.6)	(44.6)	(32.3)
Amortization of Net Actuarial Loss	0.4	0	7.4
Settlements	11.8
Net Periodic Benefit Cost (Credit)	3.8	(9.1)	4
Capitalized Portion	(4.4)	(4.2)	(5)
Net Periodic Benefit Cost (Credit) Recognized in Expense	(0.6)	(13.3)	(1)
Pension Plans | INDIANA MICHIGAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Service Cost	13	11.9	16.2
Interest Cost	23.9	24.9	17
Expected Return on Plan Assets	(42.9)	(44.2)	(32.4)
Amortization of Net Actuarial Loss	0.4	0.1	7.1
Settlements	9.3
Net Periodic Benefit Cost (Credit)	3.7	(7.3)	7.9
Capitalized Portion	(3.9)	(3.6)	(4.6)
Net Periodic Benefit Cost (Credit) Recognized in Expense	(0.2)	(10.9)	3.3
Pension Plans | OHIO POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Service Cost	9.2	8.4	11.2
Interest Cost	18.8	19.8	13.3
Expected Return on Plan Assets	(32.6)	(34)	(24.8)
Amortization of Net Actuarial Loss	0.3	0	5.5
Settlements	6.5
Net Periodic Benefit Cost (Credit)	2.2	(5.8)	5.2
Capitalized Portion	(5.5)	(4.7)	(6.1)
Net Periodic Benefit Cost (Credit) Recognized in Expense	(3.3)	(10.5)	(0.9)
Pension Plans | PUBLIC SERVICE COMPANY OF OKLAHOMA
Defined Benefit Plan Disclosure [Line Items]
Service Cost	5.9	5.5	7.4
Interest Cost	10.1	10.7	7
Expected Return on Plan Assets	(17.3)	(18.3)	(13.4)
Amortization of Net Actuarial Loss	0.2	0	2.9
Settlements	5.2
Net Periodic Benefit Cost (Credit)	4.1	(2.1)	3.9
Capitalized Portion	(2.8)	(2.5)	(3.2)
Net Periodic Benefit Cost (Credit) Recognized in Expense	1.3	(4.6)	0.7
Pension Plans | SOUTHWESTERN ELECTRIC POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Service Cost	7.8	7.7	10.6
Interest Cost	12.5	13.9	9.1
Expected Return on Plan Assets	(17.4)	(19.4)	(14.6)
Amortization of Net Actuarial Loss	0.1	0.1	3.8
Settlements	9.3
Net Periodic Benefit Cost (Credit)	12.3	2.3	8.9
Capitalized Portion	(3.1)	(3)	(4)
Net Periodic Benefit Cost (Credit) Recognized in Expense	9.2	(0.7)	4.9
OPEB
Defined Benefit Plan Disclosure [Line Items]
Service Cost	4.5	4.6	7.4
Interest Cost	42	46.2	29.2
Expected Return on Plan Assets	(111.3)	(109.6)	(110)
Amortization of Prior Service Credit	(12.7)	(63.1)	(71.4)
Amortization of Net Actuarial Loss	3	14.8
Special/Contractual Termination Benefits	3.5
Net Periodic Benefit Cost (Credit)	(71)	(107.1)	(144.8)
Capitalized Portion	(2.1)	(2.1)	(3.2)
Net Periodic Benefit Cost (Credit) Recognized in Expense	(73.1)	(109.2)	(148)
OPEB | AEP TEXAS INC.
Defined Benefit Plan Disclosure [Line Items]
Service Cost	0.3	0.3	0.5
Interest Cost	3.3	3.6	2.2
Expected Return on Plan Assets	(9.1)	(9)	(9.1)
Amortization of Prior Service Credit	(1)	(5.3)	(6.1)
Amortization of Net Actuarial Loss	0.2	1.2
Special/Contractual Termination Benefits	0.3
Net Periodic Benefit Cost (Credit)	(6)	(9.2)	(12.5)
Capitalized Portion	(0.2)	(0.2)	(0.3)
Net Periodic Benefit Cost (Credit) Recognized in Expense	(6.2)	(9.4)	(12.8)
OPEB | APPALACHIAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Service Cost	0.5	0.5	0.8
Interest Cost	6.6	7.4	4.7
Expected Return on Plan Assets	(16.3)	(16.1)	(16.3)
Amortization of Prior Service Credit	(1.9)	(9.2)	(10.4)
Amortization of Net Actuarial Loss	0.4	2.3
Special/Contractual Termination Benefits	0.6
Net Periodic Benefit Cost (Credit)	(10.1)	(15.1)	(21.2)
Capitalized Portion	(0.2)	(0.2)	(0.4)
Net Periodic Benefit Cost (Credit) Recognized in Expense	(10.3)	(15.3)	(21.6)
OPEB | INDIANA MICHIGAN POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Service Cost	0.6	0.6	0.9
Interest Cost	4.8	5.4	3.4
Expected Return on Plan Assets	(13.5)	(13.5)	(13.7)
Amortization of Prior Service Credit	(1.7)	(8.7)	(9.7)
Amortization of Net Actuarial Loss	0.5	1.9
Special/Contractual Termination Benefits	0.3
Net Periodic Benefit Cost (Credit)	(9)	(14.3)	(19.1)
Capitalized Portion	(0.2)	(0.2)	(0.3)
Net Periodic Benefit Cost (Credit) Recognized in Expense	(9.2)	(14.5)	(19.4)
OPEB | OHIO POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Service Cost	0.4	0.4	0.6
Interest Cost	4.2	4.7	3
Expected Return on Plan Assets	(11.8)	(11.8)	(12)
Amortization of Prior Service Credit	(1.3)	(6.3)	(7.1)
Amortization of Net Actuarial Loss	0.4	1.6
Special/Contractual Termination Benefits	0.2
Net Periodic Benefit Cost (Credit)	(7.9)	(11.4)	(15.5)
Capitalized Portion	(0.2)	(0.2)	(0.3)
Net Periodic Benefit Cost (Credit) Recognized in Expense	(8.1)	(11.6)	(15.8)
OPEB | PUBLIC SERVICE COMPANY OF OKLAHOMA
Defined Benefit Plan Disclosure [Line Items]
Service Cost	0.3	0.3	0.4
Interest Cost	2.1	2.4	1.5
Expected Return on Plan Assets	(6)	(5.9)	(6.1)
Amortization of Prior Service Credit	(0.7)	(4)	(4.4)
Amortization of Net Actuarial Loss	0.2	0.8
Special/Contractual Termination Benefits	0.2
Net Periodic Benefit Cost (Credit)	(3.9)	(6.4)	(8.6)
Capitalized Portion	(0.1)	(0.1)	(0.2)
Net Periodic Benefit Cost (Credit) Recognized in Expense	(4)	(6.5)	(8.8)
OPEB | SOUTHWESTERN ELECTRIC POWER COMPANY
Defined Benefit Plan Disclosure [Line Items]
Service Cost	0.4	0.4	0.6
Interest Cost	2.7	2.9	1.8
Expected Return on Plan Assets	(7.5)	(7.2)	(7.3)
Amortization of Prior Service Credit	(1.1)	(4.9)	(5.3)
Amortization of Net Actuarial Loss	0.3	1
Special/Contractual Termination Benefits	0.3
Net Periodic Benefit Cost (Credit)	(4.9)	(7.8)	(10.2)
Capitalized Portion	(0.2)	(0.2)	(0.2)
Net Periodic Benefit Cost (Credit) Recognized in Expense	$ (5.1)	$ (8)	$ (10.4)

BENEFIT PLANS - Schedule of Mat

BENEFIT PLANS - Schedule of Matching Contribution Costs (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Defined Contribution Plan Disclosure [Line Items]
Defined contribution plan, cost	$ 81.5	$ 87.9	$ 81.9
AEP TEXAS INC.
Defined Contribution Plan Disclosure [Line Items]
Defined contribution plan, cost	6.8	7.1	6.5
APPALACHIAN POWER COMPANY
Defined Contribution Plan Disclosure [Line Items]
Defined contribution plan, cost	8	8.4	7.8
INDIANA MICHIGAN POWER COMPANY
Defined Contribution Plan Disclosure [Line Items]
Defined contribution plan, cost	10.7	11	11.1
OHIO POWER COMPANY
Defined Contribution Plan Disclosure [Line Items]
Defined contribution plan, cost	7.9	8.2	7.7
PUBLIC SERVICE COMPANY OF OKLAHOMA
Defined Contribution Plan Disclosure [Line Items]
Defined contribution plan, cost	5.3	5.3	4.7
SOUTHWESTERN ELECTRIC POWER COMPANY
Defined Contribution Plan Disclosure [Line Items]
Defined contribution plan, cost	$ 6.5	$ 6.7	$ 6.4

BUSINESS SEGMENTS - Schedule of

BUSINESS SEGMENTS - Schedule of AEP's Reportable Segment Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Revenues from:
Total Revenues	$ 19,721.3	$ 18,982.3	$ 19,639.5
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	5,936.3	6,578.3	7,097.9
Other Operation and Maintenance	4,452.7	4,086.8	4,127.5
Loss on the Expected Sale of the Kentucky Operations	0	0	363.3
Asset Impairments and Other Related Charges	142.5	85.6	48.8
Loss on the Sale of the Competitive Contracted Renewables Portfolio	0	92.7	0
Gain on the Sale of Mineral Rights	0	0	(116.3)
Depreciation and Amortization	3,289.9	3,090.4	3,202.8
Taxes Other Than Income Taxes	1,596.3	1,492.3	1,469.8
Allowance for Equity Funds Used During Construction	211	174.9	133.7
Interest Expense	1,862.8	1,806.9	1,396.1
Income Tax Expense (Benefit)	(39.2)	54.6	5.4
Equity Earnings (Loss) of Unconsolidated Subsidiaries	93.7	58.5	(109.4)
Other Segment Items	(182.4)	(280)	(238.7)
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS, Basic	2,967.1	2,208.1	2,307.2
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS, Diluted	2,967.1	2,208.1	2,307.2
Gross Property Additions	8,030.2	7,533.5	7,879
Total Assets	103,078	96,684
Investments in Equity Method Investees	1,055.9	1,073.6	1,276.7
Related Party
Revenues from:
Total Revenues	0	0	0
Operating Segments
Revenues from:
Total Revenues	21,500.5	20,523.5	21,133.4
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	6,247.7	6,852.9	7,279.5
Other Operation and Maintenance	5,986.8	5,433.4	5,435.8
Loss on the Expected Sale of the Kentucky Operations			0
Asset Impairments and Other Related Charges	142.5	85.6	24.9
Loss on the Sale of the Competitive Contracted Renewables Portfolio		92.7
Gain on the Sale of Mineral Rights			(116.3)
Depreciation and Amortization	3,310.7	3,106.4	3,201.9
Taxes Other Than Income Taxes	1,576.4	1,477.2	1,453.5
Allowance for Equity Funds Used During Construction	211	174.9	133.7
Interest Expense	1,368.7	1,406.7	1,200
Income Tax Expense (Benefit)	112.9	138.1	133.6
Equity Earnings (Loss) of Unconsolidated Subsidiaries	100.1	67.8	(107)
Other Segment Items	(192.4)	(292.5)	(297.6)
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS, Basic	3,258.3	2,465.7	2,844.8
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS, Diluted	3,258.3	2,465.7	2,844.8
Gross Property Additions	7,594.7	7,495.5	7,881.9
Total Assets	101,506.6	95,814.6
Investments in Equity Method Investees	1,007.2	1,019.4	1,209
Operating Segments | Nonrelated Party
Revenues from:
Total Revenues	19,663.3	18,921.6	19,588.8
Operating Segments | Related Party
Revenues from:
Total Revenues	1,837.2	1,601.9	1,544.6
Corporate and Other
Revenues from:
Total Revenues	183.1	168	109.9
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	0	0	0
Other Operation and Maintenance	136.3	103.1	130
Loss on the Expected Sale of the Kentucky Operations			363.3
Asset Impairments and Other Related Charges	0	0	23.9
Loss on the Sale of the Competitive Contracted Renewables Portfolio		0
Gain on the Sale of Mineral Rights			0
Depreciation and Amortization	(20.8)	(16)	0.9
Taxes Other Than Income Taxes	0.4	0.2	0.2
Allowance for Equity Funds Used During Construction	0	0	0
Interest Expense	612.5	594.7	308.9
Income Tax Expense (Benefit)	(152.1)	(83.5)	(128.2)
Equity Earnings (Loss) of Unconsolidated Subsidiaries	(6.4)	(9.3)	(2.4)
Other Segment Items	(108.4)	(182.2)	(53.9)
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS, Basic	(291.2)	(257.6)	(537.6)
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS, Diluted	(291.2)	(257.6)	(537.6)
Gross Property Additions	466.6	36.6	25.9
Total Assets	5,550.8	5,194
Investments in Equity Method Investees	48.7	54.2	67.7
Corporate and Other | Nonrelated Party
Revenues from:
Total Revenues	58	60.7	50.7
Corporate and Other | Related Party
Revenues from:
Total Revenues	125.1	107.3	59.2
Reconciling Adjustments
Revenues from:
Total Revenues	(1,962.3)	(1,709.2)	(1,603.8)
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	(311.4)	(274.6)	(181.6)
Other Operation and Maintenance	(1,670.4)	(1,449.7)	(1,438.3)
Loss on the Expected Sale of the Kentucky Operations			0
Asset Impairments and Other Related Charges	0	0	0
Loss on the Sale of the Competitive Contracted Renewables Portfolio		0
Gain on the Sale of Mineral Rights			0
Depreciation and Amortization	0	0	0
Taxes Other Than Income Taxes	19.5	14.9	16.1
Allowance for Equity Funds Used During Construction	0	0	0
Interest Expense	(118.4)	(194.5)	(112.8)
Income Tax Expense (Benefit)	0	0	0
Equity Earnings (Loss) of Unconsolidated Subsidiaries	0	0	0
Other Segment Items	118.4	194.7	112.8
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS, Basic	0	0	0
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS, Diluted	0	0	0
Gross Property Additions	(31.1)	1.4	(28.8)
Total Assets	(3,979.4)	(4,324.6)
Investments in Equity Method Investees	0	0	0
Reconciling Adjustments | Nonrelated Party
Revenues from:
Total Revenues	0	0	0
Reconciling Adjustments | Related Party
Revenues from:
Total Revenues	(1,962.3)	(1,709.2)	(1,603.8)
VIU | Operating Segments
Revenues from:
Total Revenues	11,596.6	11,449.5	11,477.5
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	3,796.2	4,150.3	4,007.9
Other Operation and Maintenance	3,528	3,211.1	3,287.2
Loss on the Expected Sale of the Kentucky Operations			0
Asset Impairments and Other Related Charges	13.4	85.6	24.9
Loss on the Sale of the Competitive Contracted Renewables Portfolio		0
Gain on the Sale of Mineral Rights			0
Depreciation and Amortization	1,970.6	1,876.4	2,007.2
Taxes Other Than Income Taxes	535.3	512.5	504.9
Allowance for Equity Funds Used During Construction	52.4	46.3	29.5
Interest Expense	724.3	764.5	650.9
Income Tax Expense (Benefit)	(282.2)	(45.2)	(93.8)
Equity Earnings (Loss) of Unconsolidated Subsidiaries	1.4	1.4	1.4
Other Segment Items	(88.4)	(148.4)	(172.8)
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS, Basic	1,453.2	1,090.4	1,292
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS, Diluted	1,453.2	1,090.4	1,292
Gross Property Additions	3,643.5	3,486.8	4,164.6
Total Assets	54,996.5	51,802.1
Investments in Equity Method Investees	9.1	10	10.1
VIU | Operating Segments | Nonrelated Party
Revenues from:
Total Revenues	11,414	11,303.7	11,292.8
VIU | Operating Segments | Related Party
Revenues from:
Total Revenues	182.6	145.8	184.7
T&D | Operating Segments
Revenues from:
Total Revenues	5,907.7	5,713.3	5,512
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	909.1	1,214.8	1,287.3
Other Operation and Maintenance	2,166.1	1,947.8	1,864.2
Loss on the Expected Sale of the Kentucky Operations			0
Asset Impairments and Other Related Charges	52.9	0	0
Loss on the Sale of the Competitive Contracted Renewables Portfolio		0
Gain on the Sale of Mineral Rights			0
Depreciation and Amortization	879.5	784.7	746.7
Taxes Other Than Income Taxes	724.2	668	659.9
Allowance for Equity Funds Used During Construction	69.2	45.5	33.6
Interest Expense	405.5	363.6	328
Income Tax Expense (Benefit)	154.5	140.2	116.9
Equity Earnings (Loss) of Unconsolidated Subsidiaries	(1.1)	0	0.6
Other Segment Items	(41.7)	(59)	(52.5)
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS, Basic	725.7	698.7	595.7
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS, Diluted	725.7	698.7	595.7
Gross Property Additions	2,343.6	2,467.4	2,177.3
Total Assets	26,864.3	24,838.4
Investments in Equity Method Investees	2	3	3
T&D | Operating Segments | Nonrelated Party
Revenues from:
Total Revenues	5,879.6	5,677.2	5,489.6
T&D | Operating Segments | Related Party
Revenues from:
Total Revenues	28.1	36.1	22.4
AEPTHCo | Operating Segments
Revenues from:
Total Revenues	1,950.8	1,728.5	1,677
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	0	0	0
Other Operation and Maintenance	162.8	141.6	165.7
Loss on the Expected Sale of the Kentucky Operations			0
Asset Impairments and Other Related Charges	0	0	0
Loss on the Sale of the Competitive Contracted Renewables Portfolio		0
Gain on the Sale of Mineral Rights			0
Depreciation and Amortization	439.7	402.6	355
Taxes Other Than Income Taxes	314.9	290.1	277.6
Allowance for Equity Funds Used During Construction	89.4	83.1	70.6
Interest Expense	222.3	202.6	169.3
Income Tax Expense (Benefit)	214.7	166	193.6
Equity Earnings (Loss) of Unconsolidated Subsidiaries	98.9	82.9	83.4
Other Segment Items	(5.5)	(11.3)	(3.7)
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS, Basic	790.2	702.9	673.5
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS, Diluted	790.2	702.9	673.5
Gross Property Additions	1,572.5	1,528.7	1,470.8
Total Assets	18,011.9	16,575.6
Investments in Equity Method Investees	996.1	905.8	858.3
AEPTHCo | Operating Segments | Nonrelated Party
Revenues from:
Total Revenues	425	397.4	357.5
AEPTHCo | Operating Segments | Related Party
Revenues from:
Total Revenues	1,525.8	1,331.1	1,319.5
G&M
Revenues from:
Loss on the Sale of the Competitive Contracted Renewables Portfolio		93
G&M | Operating Segments
Revenues from:
Total Revenues	2,045.4	1,632.2	2,466.9
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation	1,542.4	1,487.8	1,984.3
Other Operation and Maintenance	129.9	132.9	118.7
Loss on the Expected Sale of the Kentucky Operations			0
Asset Impairments and Other Related Charges	76.2	0	0
Loss on the Sale of the Competitive Contracted Renewables Portfolio		92.7
Gain on the Sale of Mineral Rights			(116.3)
Depreciation and Amortization	20.9	42.7	93
Taxes Other Than Income Taxes	2	6.6	11.1
Allowance for Equity Funds Used During Construction	0	0	0
Interest Expense	16.6	76	51.8
Income Tax Expense (Benefit)	25.9	(122.9)	(83.1)
Equity Earnings (Loss) of Unconsolidated Subsidiaries	0.9	(16.5)	(192.4)
Other Segment Items	(56.8)	(73.8)	(68.6)
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS, Basic	289.2	(26.3)	283.6
EARNINGS ATTRIBUTABLE TO COMMON SHAREHOLDERS, Diluted	289.2	(26.3)	283.6
Gross Property Additions	35.1	12.6	69.2
Total Assets	1,633.9	2,598.5
Investments in Equity Method Investees	0	100.6	337.6
G&M | Operating Segments | Nonrelated Party
Revenues from:
Total Revenues	1,944.7	1,543.3	2,448.9
G&M | Operating Segments | Related Party
Revenues from:
Total Revenues	$ 100.7	$ 88.9	$ 18

BUSINESS SEGMENTS - Narrative (

BUSINESS SEGMENTS - Narrative (Details)	12 Months Ended
	Dec. 31, 2024 segment company
Segment Reporting Information [Line Items]
Number of Reportable Segments	1
AEP TEXAS INC.
Segment Reporting Information [Line Items]
Number of Reportable Segments	1
APPALACHIAN POWER COMPANY
Segment Reporting Information [Line Items]
Number of Reportable Segments	1
INDIANA MICHIGAN POWER COMPANY
Segment Reporting Information [Line Items]
Number of Reportable Segments	1
OHIO POWER COMPANY
Segment Reporting Information [Line Items]
Number of Reportable Segments	1
PUBLIC SERVICE COMPANY OF OKLAHOMA
Segment Reporting Information [Line Items]
Number of Reportable Segments	1
SOUTHWESTERN ELECTRIC POWER COMPANY
Segment Reporting Information [Line Items]
Number of Reportable Segments	1
AEP TRANSMISSION COMPANY, LLC
Segment Reporting Information [Line Items]
Number of Reportable Segments	1
Number of Operating Segments	7
Number Of FERC-Regulated Transmission-Only Electric Utilities | company	7

BUSINESS SEGMENTS - Schedule _2

BUSINESS SEGMENTS - Schedule of AEPTCo's Reportable Segment Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Segment Reporting Information [Line Items]
Total Revenues	$ 19,721.3	$ 18,982.3	$ 19,639.5
Other Operation and Maintenance	4,452.7	4,086.8	4,127.5
Depreciation and Amortization	3,289.9	3,090.4	3,202.8
Taxes Other Than Income Taxes	1,596.3	1,492.3	1,469.8
Allowance for equity funds used during construction	211	174.9	133.7
Interest Expense	1,862.8	1,806.9	1,396.1
Income Tax Expense (Benefit)	(39.2)	54.6	5.4
Gross Property Additions	8,030.2	7,533.5	7,879
Total Assets	103,078	96,684
Operating Segments
Segment Reporting Information [Line Items]
Total Revenues	21,500.5	20,523.5	21,133.4
Other Operation and Maintenance	5,986.8	5,433.4	5,435.8
Depreciation and Amortization	3,310.7	3,106.4	3,201.9
Taxes Other Than Income Taxes	1,576.4	1,477.2	1,453.5
Allowance for equity funds used during construction	211	174.9	133.7
Interest Expense	1,368.7	1,406.7	1,200
Income Tax Expense (Benefit)	112.9	138.1	133.6
Gross Property Additions	7,594.7	7,495.5	7,881.9
Total Assets	101,506.6	95,814.6
Operating Segments | Nonrelated Party
Segment Reporting Information [Line Items]
Total Revenues	19,663.3	18,921.6	19,588.8
Corporate and Other
Segment Reporting Information [Line Items]
Total Revenues	183.1	168	109.9
Other Operation and Maintenance	136.3	103.1	130
Depreciation and Amortization	(20.8)	(16)	0.9
Taxes Other Than Income Taxes	0.4	0.2	0.2
Allowance for equity funds used during construction	0	0	0
Interest Expense	612.5	594.7	308.9
Income Tax Expense (Benefit)	(152.1)	(83.5)	(128.2)
Gross Property Additions	466.6	36.6	25.9
Total Assets	5,550.8	5,194
Corporate and Other | Nonrelated Party
Segment Reporting Information [Line Items]
Total Revenues	58	60.7	50.7
Reconciling Adjustments
Segment Reporting Information [Line Items]
Total Revenues	(1,962.3)	(1,709.2)	(1,603.8)
Other Operation and Maintenance	(1,670.4)	(1,449.7)	(1,438.3)
Depreciation and Amortization	0	0	0
Taxes Other Than Income Taxes	19.5	14.9	16.1
Allowance for equity funds used during construction	0	0	0
Interest Expense	(118.4)	(194.5)	(112.8)
Income Tax Expense (Benefit)	0	0	0
Gross Property Additions	(31.1)	1.4	(28.8)
Total Assets	(3,979.4)	(4,324.6)
Reconciling Adjustments | Nonrelated Party
Segment Reporting Information [Line Items]
Total Revenues	0	0	0
AEP TRANSMISSION COMPANY, LLC
Segment Reporting Information [Line Items]
Total Revenues	1,890.9	1,672	1,624.5
Other Revenues			(0.2)
Other Operation and Maintenance	158.3	129.4	153.5
Depreciation and Amortization	430.9	393.8	346.2
Taxes Other Than Income Taxes	308.7	283.2	271.1
Interest Income	10.5	7	1.6
Allowance for equity funds used during construction	89.4	83.2	70.7
Interest Expense	214.2	194.5	162.7
Income Tax Expense (Benefit)	190.3	147.1	169.1
NET INCOME	688.4	614.2	594.2
Gross Property Additions	1,481.8	1,503.1	1,468.3
Total Assets	16,370.3	15,072.5
AEP TRANSMISSION COMPANY, LLC | Nonrelated Party
Segment Reporting Information [Line Items]
Total Revenues	378.6	354.2	340.9
AEP TRANSMISSION COMPANY, LLC | Affiliated Entity
Segment Reporting Information [Line Items]
Total Revenues	1,512.3	1,317.8	1,283.8
AEP TRANSMISSION COMPANY, LLC | Operating Segments
Segment Reporting Information [Line Items]
Total Revenues	1,890.9	1,672	1,624.5
Other Operation and Maintenance	156.6	129.2	152.8
Taxes Other Than Income Taxes	308.7	283.2	271.1
AEP TRANSMISSION COMPANY, LLC | Corporate and Other
Segment Reporting Information [Line Items]
Total Revenues	0	0	0
Other Revenues			0
Other Operation and Maintenance	1.7	0.2	0.7
Depreciation and Amortization	0	0	0
Taxes Other Than Income Taxes	0	0	0
Interest Income	241.1	218	177.8
Allowance for equity funds used during construction	0	0	0
Interest Expense	238.7	215.1	177.1
Income Tax Expense (Benefit)	0.1	1.4	0
NET INCOME	0.6	1.3	0
Gross Property Additions	0	0	0
Total Assets	8,670.4	5,486.6
AEP TRANSMISSION COMPANY, LLC | Corporate and Other | Nonrelated Party
Segment Reporting Information [Line Items]
Total Revenues	0	0	0
AEP TRANSMISSION COMPANY, LLC | Corporate and Other | Affiliated Entity
Segment Reporting Information [Line Items]
Total Revenues	0	0	0
AEP TRANSMISSION COMPANY, LLC | Reconciling Adjustments
Segment Reporting Information [Line Items]
Total Revenues	0	0	0
Other Revenues			0
Other Operation and Maintenance	0	0	0
Depreciation and Amortization	0	0	0
Taxes Other Than Income Taxes	0	0	0
Interest Income	(238.5)	(214.8)	(176.9)
Allowance for equity funds used during construction	0	0	0
Interest Expense	(238.5)	(214.8)	(176.9)
Income Tax Expense (Benefit)	0	0	0
NET INCOME	0	0	0
Gross Property Additions	0	0	0
Total Assets	(9,187.8)	(5,534.7)
AEP TRANSMISSION COMPANY, LLC | Reconciling Adjustments | Nonrelated Party
Segment Reporting Information [Line Items]
Total Revenues	0	0	0
AEP TRANSMISSION COMPANY, LLC | Reconciling Adjustments | Affiliated Entity
Segment Reporting Information [Line Items]
Total Revenues	0	0	0
State Transcos | AEP TRANSMISSION COMPANY, LLC | Operating Segments
Segment Reporting Information [Line Items]
Other Revenues			(0.2)
Depreciation and Amortization	430.9	393.8	346.2
Interest Income	7.9	3.8	0.7
Allowance for equity funds used during construction	89.4	83.2	70.7
Interest Expense	214	194.2	162.5
Income Tax Expense (Benefit)	190.2	145.7	169.1
NET INCOME	687.8	612.9	594.2
Gross Property Additions	1,481.8	1,503.1	1,468.3
Total Assets	16,887.7	15,120.6
State Transcos | AEP TRANSMISSION COMPANY, LLC | Operating Segments | Nonrelated Party
Segment Reporting Information [Line Items]
Total Revenues	378.6	354.2	340.9
State Transcos | AEP TRANSMISSION COMPANY, LLC | Operating Segments | Affiliated Entity
Segment Reporting Information [Line Items]
Total Revenues	$ 1,512.3	$ 1,317.8	$ 1,283.8

DERIVATIVES AND HEDGING - Sched

DERIVATIVES AND HEDGING - Schedule of the Notional Volume of Derivative Instruments (Details) gal in Millions, MWh in Millions, MMBTU in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2024 USD ($) MMBTU MWh gal	Dec. 31, 2023 USD ($) MWh MMBTU gal
Power (MWhs)
Derivative [Line Items]
Notional amount, energy measure | MWh	282.4	246.8
Power (MWhs) | AEP Texas
Derivative [Line Items]
Notional amount, energy measure | MWh	0	0
Power (MWhs) | APCo
Derivative [Line Items]
Notional amount, energy measure | MWh	23.6	16.8
Power (MWhs) | I&M
Derivative [Line Items]
Notional amount, energy measure | MWh	7.7	5.9
Power (MWhs) | OPCo
Derivative [Line Items]
Notional amount, energy measure | MWh	2	2.2
Power (MWhs) | PSO
Derivative [Line Items]
Notional amount, energy measure | MWh	5	4.1
Power (MWhs) | SWEPCo
Derivative [Line Items]
Notional amount, energy measure | MWh	4.6	2.9
Natural Gas (MMBtus)
Derivative [Line Items]
Notional amount, energy measure | MMBTU	152.8	151.6
Natural Gas (MMBtus) | AEP Texas
Derivative [Line Items]
Notional amount, energy measure | MMBTU	0	0
Natural Gas (MMBtus) | APCo
Derivative [Line Items]
Notional amount, energy measure | MMBTU	42.2	37.3
Natural Gas (MMBtus) | I&M
Derivative [Line Items]
Notional amount, energy measure | MMBTU	0	0
Natural Gas (MMBtus) | OPCo
Derivative [Line Items]
Notional amount, energy measure | MMBTU	0	0
Natural Gas (MMBtus) | PSO
Derivative [Line Items]
Notional amount, energy measure | MMBTU	46.2	34.9
Natural Gas (MMBtus) | SWEPCo
Derivative [Line Items]
Notional amount, energy measure | MMBTU	15.4	17.9
Heating Oil and Gasoline (Gallons)
Derivative [Line Items]
Notional amount, volume | gal	7.9	6.5
Heating Oil and Gasoline (Gallons) | AEP Texas
Derivative [Line Items]
Notional amount, volume | gal	2	1.8
Heating Oil and Gasoline (Gallons) | APCo
Derivative [Line Items]
Notional amount, volume | gal	0.9	1
Heating Oil and Gasoline (Gallons) | I&M
Derivative [Line Items]
Notional amount, volume | gal	2	0.6
Heating Oil and Gasoline (Gallons) | OPCo
Derivative [Line Items]
Notional amount, volume | gal	1.1	1.2
Heating Oil and Gasoline (Gallons) | PSO
Derivative [Line Items]
Notional amount, volume | gal	0.7	0.7
Heating Oil and Gasoline (Gallons) | SWEPCo
Derivative [Line Items]
Notional amount, volume | gal	0.9	0.9
Interest Rate (USD)
Derivative [Line Items]
Notional amount	$ 59.3	$ 80.1
Interest Rate (USD) | AEP Texas
Derivative [Line Items]
Notional amount	0	0
Interest Rate (USD) | APCo
Derivative [Line Items]
Notional amount	0	0
Interest Rate (USD) | I&M
Derivative [Line Items]
Notional amount	0	0
Interest Rate (USD) | OPCo
Derivative [Line Items]
Notional amount	0	0
Interest Rate (USD) | PSO
Derivative [Line Items]
Notional amount	0	0
Interest Rate (USD) | SWEPCo
Derivative [Line Items]
Notional amount	0	0
Interest Rate on Long-term Debt (USD)
Derivative [Line Items]
Notional amount	950	1,300
Interest Rate on Long-term Debt (USD) | AEP Texas
Derivative [Line Items]
Notional amount	0	150
Interest Rate on Long-term Debt (USD) | APCo
Derivative [Line Items]
Notional amount	0	0
Interest Rate on Long-term Debt (USD) | I&M
Derivative [Line Items]
Notional amount	0	0
Interest Rate on Long-term Debt (USD) | OPCo
Derivative [Line Items]
Notional amount	0	0
Interest Rate on Long-term Debt (USD) | PSO
Derivative [Line Items]
Notional amount	0	0
Interest Rate on Long-term Debt (USD) | SWEPCo
Derivative [Line Items]
Notional amount	$ 0	$ 0

DERIVATIVES AND HEDGING - Narra

DERIVATIVES AND HEDGING - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Cash collateral received from third-parties	$ 87	$ 46
Fair value of derivative liability subject to cross-acceleration	72	107
Fair value of derivative liability, subject to cross-default provision	164	242
APCo
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Fair value of derivative liability, subject to cross-default provision	1	22
PSO
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Fair value of derivative liability, subject to cross-default provision	4	29
SWEPCo
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Fair value of derivative liability, subject to cross-default provision	$ 2	$ 15
Commodity
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Maximum length of time to hedge exposure to variability	10 years
Cross-acceleration provisions, maximum third-party obligation, amount	$ 50
Cross-default trigger, maximum third party obligation, amount	$ 50

DERIVATIVES AND HEDGING - Sch_2

DERIVATIVES AND HEDGING - Schedule of Location and Fair Value of Derivative Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Derivative [Line Items]
Total Assets	$ 1,039.1	$ 1,167.4
Total Liabilities	780.4	1,083.4
Total MTM Derivative Contract Net Assets (Liabilities) Recognized	258.7	84
Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	479.1	611.8
Other Noncurrent Assets
Derivative [Line Items]
Total Assets	560	555.6
Other Current Liabilities
Derivative [Line Items]
Total Liabilities	351.7	646.7
Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	428.7	436.7
AEP Texas
Derivative [Line Items]
Total Assets	0	0
Total Liabilities	0.3	2.9
Total MTM Derivative Contract Net Assets (Liabilities) Recognized	(0.3)	(2.9)
AEP Texas | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	0	0
AEP Texas | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	0	0
AEP Texas | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	0.3	2.9
AEP Texas | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	0	0
APCo
Derivative [Line Items]
Total Assets	42.2	24.9
Total Liabilities	7.4	25.4
Total MTM Derivative Contract Net Assets (Liabilities) Recognized	34.8	(0.5)
APCo | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	40.2	24.6
APCo | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	2	0.3
APCo | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	6.6	18.5
APCo | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	0.8	6.9
I&M
Derivative [Line Items]
Total Assets	29.7	42.1
Total Liabilities	12.6	5.6
Total MTM Derivative Contract Net Assets (Liabilities) Recognized	17.1	36.5
I&M | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	28.5	30.1
I&M | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	1.2	12
I&M | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	10.5	5.4
I&M | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	2.1	0.2
OPCo
Derivative [Line Items]
Total Assets	0	0
Total Liabilities	47.7	50.8
Total MTM Derivative Contract Net Assets (Liabilities) Recognized	(47.7)	(50.8)
OPCo | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	0	0
OPCo | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	0	0
OPCo | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	7.5	6.9
OPCo | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	40.2	43.9
PSO
Derivative [Line Items]
Total Assets	23.9	19.7
Total Liabilities	7.8	30.7
Total MTM Derivative Contract Net Assets (Liabilities) Recognized	16.1	(11)
PSO | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	22.3	19.7
PSO | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	1.6	0
PSO | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	7.6	29.7
PSO | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	0.2	1
SWEPCo
Derivative [Line Items]
Total Assets	19.1	12.5
Total Liabilities	3.4	16.6
Total MTM Derivative Contract Net Assets (Liabilities) Recognized	15.7	(4.1)
SWEPCo | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	19.1	12
SWEPCo | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	0	0.5
SWEPCo | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	3.4	14.9
SWEPCo | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	0	1.7
Commodity | Not Designated as Hedging Instrument | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	425	555.1
Commodity | Not Designated as Hedging Instrument | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	475.4	468.8
Commodity | Not Designated as Hedging Instrument | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	304.1	588
Commodity | Not Designated as Hedging Instrument | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	390.7	377.6
Commodity | Not Designated as Hedging Instrument | AEP Texas | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	0	0
Commodity | Not Designated as Hedging Instrument | AEP Texas | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	0	0
Commodity | Not Designated as Hedging Instrument | AEP Texas | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	0.3	0.2
Commodity | Not Designated as Hedging Instrument | AEP Texas | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	0	0
Commodity | Not Designated as Hedging Instrument | APCo | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	40.2	24.6
Commodity | Not Designated as Hedging Instrument | APCo | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	2	0.3
Commodity | Not Designated as Hedging Instrument | APCo | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	6.6	18.5
Commodity | Not Designated as Hedging Instrument | APCo | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	0.8	6.9
Commodity | Not Designated as Hedging Instrument | I&M | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	28.5	30.1
Commodity | Not Designated as Hedging Instrument | I&M | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	1.2	12
Commodity | Not Designated as Hedging Instrument | I&M | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	10.5	5.4
Commodity | Not Designated as Hedging Instrument | I&M | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	2.1	0.2
Commodity | Not Designated as Hedging Instrument | OPCo | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	0	0
Commodity | Not Designated as Hedging Instrument | OPCo | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	0	0
Commodity | Not Designated as Hedging Instrument | OPCo | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	7.5	6.9
Commodity | Not Designated as Hedging Instrument | OPCo | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	40.2	43.9
Commodity | Not Designated as Hedging Instrument | PSO | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	22.3	19.7
Commodity | Not Designated as Hedging Instrument | PSO | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	1.6	0
Commodity | Not Designated as Hedging Instrument | PSO | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	7.6	29.7
Commodity | Not Designated as Hedging Instrument | PSO | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	0.2	1
Commodity | Not Designated as Hedging Instrument | SWEPCo | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	19.1	12
Commodity | Not Designated as Hedging Instrument | SWEPCo | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	0	0.5
Commodity | Not Designated as Hedging Instrument | SWEPCo | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	3.4	14.9
Commodity | Not Designated as Hedging Instrument | SWEPCo | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	0	1.7
Commodity | Designated as Hedging Instrument | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	54.1	56.7
Commodity | Designated as Hedging Instrument | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	84.6	86.8
Commodity | Designated as Hedging Instrument | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	11.3	8.2
Commodity | Designated as Hedging Instrument | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	2.7	2.2
Commodity | Designated as Hedging Instrument | AEP Texas | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	0	0
Commodity | Designated as Hedging Instrument | AEP Texas | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	0	0
Commodity | Designated as Hedging Instrument | AEP Texas | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	0	0
Commodity | Designated as Hedging Instrument | AEP Texas | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	0	0
Commodity | Designated as Hedging Instrument | APCo | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	0	0
Commodity | Designated as Hedging Instrument | APCo | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	0	0
Commodity | Designated as Hedging Instrument | APCo | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	0	0
Commodity | Designated as Hedging Instrument | APCo | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	0	0
Commodity | Designated as Hedging Instrument | I&M | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	0	0
Commodity | Designated as Hedging Instrument | I&M | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	0	0
Commodity | Designated as Hedging Instrument | I&M | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	0	0
Commodity | Designated as Hedging Instrument | I&M | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	0	0
Commodity | Designated as Hedging Instrument | OPCo | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	0	0
Commodity | Designated as Hedging Instrument | OPCo | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	0	0
Commodity | Designated as Hedging Instrument | OPCo | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	0	0
Commodity | Designated as Hedging Instrument | OPCo | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	0	0
Commodity | Designated as Hedging Instrument | PSO | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	0	0
Commodity | Designated as Hedging Instrument | PSO | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	0	0
Commodity | Designated as Hedging Instrument | PSO | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	0	0
Commodity | Designated as Hedging Instrument | PSO | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	0	0
Commodity | Designated as Hedging Instrument | SWEPCo | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	0	0
Commodity | Designated as Hedging Instrument | SWEPCo | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	0	0
Commodity | Designated as Hedging Instrument | SWEPCo | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	0	0
Commodity | Designated as Hedging Instrument | SWEPCo | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	0	0
Interest Rate (USD) | Designated as Hedging Instrument | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	0	0
Interest Rate (USD) | Designated as Hedging Instrument | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	0	0
Interest Rate (USD) | Designated as Hedging Instrument | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	36.3	50.5
Interest Rate (USD) | Designated as Hedging Instrument | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	35.3	56.9
Interest Rate (USD) | Designated as Hedging Instrument | AEP Texas | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	0	0
Interest Rate (USD) | Designated as Hedging Instrument | AEP Texas | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	0	0
Interest Rate (USD) | Designated as Hedging Instrument | AEP Texas | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	0	2.7
Interest Rate (USD) | Designated as Hedging Instrument | AEP Texas | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	0	0
Interest Rate (USD) | Designated as Hedging Instrument | APCo | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	0	0
Interest Rate (USD) | Designated as Hedging Instrument | APCo | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	0	0
Interest Rate (USD) | Designated as Hedging Instrument | APCo | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	0	0
Interest Rate (USD) | Designated as Hedging Instrument | APCo | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	0	0
Interest Rate (USD) | Designated as Hedging Instrument | I&M | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	0	0
Interest Rate (USD) | Designated as Hedging Instrument | I&M | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	0	0
Interest Rate (USD) | Designated as Hedging Instrument | I&M | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	0	0
Interest Rate (USD) | Designated as Hedging Instrument | I&M | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	0	0
Interest Rate (USD) | Designated as Hedging Instrument | OPCo | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	0	0
Interest Rate (USD) | Designated as Hedging Instrument | OPCo | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	0	0
Interest Rate (USD) | Designated as Hedging Instrument | OPCo | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	0	0
Interest Rate (USD) | Designated as Hedging Instrument | OPCo | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	0	0
Interest Rate (USD) | Designated as Hedging Instrument | PSO | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	0	0
Interest Rate (USD) | Designated as Hedging Instrument | PSO | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	0	0
Interest Rate (USD) | Designated as Hedging Instrument | PSO | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	0	0
Interest Rate (USD) | Designated as Hedging Instrument | PSO | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	0	0
Interest Rate (USD) | Designated as Hedging Instrument | SWEPCo | Prepaid Expenses and Other Current Assets
Derivative [Line Items]
Total Assets	0	0
Interest Rate (USD) | Designated as Hedging Instrument | SWEPCo | Other Noncurrent Assets
Derivative [Line Items]
Total Assets	0	0
Interest Rate (USD) | Designated as Hedging Instrument | SWEPCo | Other Current Liabilities
Derivative [Line Items]
Total Liabilities	0	0
Interest Rate (USD) | Designated as Hedging Instrument | SWEPCo | Other Noncurrent Liabilities
Derivative [Line Items]
Total Liabilities	$ 0	$ 0

DERIVATIVES AND HEDGING - Sch_3

DERIVATIVES AND HEDGING - Schedule of Offsetting Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Total Assets
Gross Amounts Recognized	$ 1,039.1	$ 1,167.4
Current Risk Management Assets	210.4	217.5
Long-term Risk Management Assets	289.1	321.2
Total Risk Management Assets	499.5	538.7
Total Liabilities
Gross Amounts Recognized	780.4	1,083.4
Current Risk Management Liabilities	100	229.6
Long-term Risk Management Liabilities	224.4	241.8
Total Risk Management Liabilities	324.4	471.4
Total MTM Derivative Contract Net Assets (Liabilities)	175.1	67.3
Prepaid Expenses and Other Current Assets
Total Assets
Gross Amounts Recognized	479.1	611.8
Gross Amounts Offset	(268.7)	(394.3)
Other Noncurrent Assets
Total Assets
Gross Amounts Recognized	560	555.6
Gross Amounts Offset	(270.9)	(234.4)
Other Current Liabilities
Total Liabilities
Gross Amounts Recognized	351.7	646.7
Gross Amounts Offset	(251.7)	(417.1)
Other Noncurrent Liabilities
Total Liabilities
Gross Amounts Recognized	428.7	436.7
Gross Amounts Offset	(204.3)	(194.9)
AEP Texas
Total Assets
Gross Amounts Recognized	0	0
Current Risk Management Assets	0	0
Long-term Risk Management Assets	0	0
Total Risk Management Assets	0	0
Total Liabilities
Gross Amounts Recognized	0.3	2.9
Current Risk Management Liabilities	0	2.7
Long-term Risk Management Liabilities	0	0
Total Risk Management Liabilities	0	2.7
Total MTM Derivative Contract Net Assets (Liabilities)	0	(2.7)
AEP Texas | Prepaid Expenses and Other Current Assets
Total Assets
Gross Amounts Recognized	0	0
Gross Amounts Offset	0	0
AEP Texas | Other Noncurrent Assets
Total Assets
Gross Amounts Recognized	0	0
Gross Amounts Offset	0	0
AEP Texas | Other Current Liabilities
Total Liabilities
Gross Amounts Recognized	0.3	2.9
Gross Amounts Offset	(0.3)	(0.2)
AEP Texas | Other Noncurrent Liabilities
Total Liabilities
Gross Amounts Recognized	0	0
Gross Amounts Offset	0	0
APCo
Total Assets
Gross Amounts Recognized	42.2	24.9
Current Risk Management Assets	35.7	22.4
Long-term Risk Management Assets	1.4	0
Total Risk Management Assets	37.1	22.4
Total Liabilities
Gross Amounts Recognized	7.4	25.4
Current Risk Management Liabilities	2	15.9
Long-term Risk Management Liabilities	0.2	6.6
Total Risk Management Liabilities	2.2	22.5
Total MTM Derivative Contract Net Assets (Liabilities)	34.9	(0.1)
APCo | Prepaid Expenses and Other Current Assets
Total Assets
Gross Amounts Recognized	40.2	24.6
Gross Amounts Offset	(4.5)	(2.2)
APCo | Other Noncurrent Assets
Total Assets
Gross Amounts Recognized	2	0.3
Gross Amounts Offset	(0.6)	(0.3)
APCo | Other Current Liabilities
Total Liabilities
Gross Amounts Recognized	6.6	18.5
Gross Amounts Offset	(4.6)	(2.6)
APCo | Other Noncurrent Liabilities
Total Liabilities
Gross Amounts Recognized	0.8	6.9
Gross Amounts Offset	(0.6)	(0.3)
I&M
Total Assets
Gross Amounts Recognized	29.7	42.1
Current Risk Management Assets	18.4	27.8
Long-term Risk Management Assets	0	11.8
Total Risk Management Assets	18.4	39.6
Total Liabilities
Gross Amounts Recognized	12.6	5.6
Current Risk Management Liabilities	0.3	2
Long-term Risk Management Liabilities	0.4	0
Total Risk Management Liabilities	0.7	2
Total MTM Derivative Contract Net Assets (Liabilities)	17.7	37.6
I&M | Prepaid Expenses and Other Current Assets
Total Assets
Gross Amounts Recognized	28.5	30.1
Gross Amounts Offset	(10.1)	(2.3)
I&M | Other Noncurrent Assets
Total Assets
Gross Amounts Recognized	1.2	12
Gross Amounts Offset	(1.2)	(0.2)
I&M | Other Current Liabilities
Total Liabilities
Gross Amounts Recognized	10.5	5.4
Gross Amounts Offset	(10.2)	(3.4)
I&M | Other Noncurrent Liabilities
Total Liabilities
Gross Amounts Recognized	2.1	0.2
Gross Amounts Offset	(1.7)	(0.2)
OPCo
Total Assets
Gross Amounts Recognized	0	0
Current Risk Management Assets	0	0
Long-term Risk Management Assets	0	0
Total Risk Management Assets	0	0
Total Liabilities
Gross Amounts Recognized	47.7	50.8
Current Risk Management Liabilities	7.3	6.8
Long-term Risk Management Liabilities	40.2	43.9
Total Risk Management Liabilities	47.5	50.7
Total MTM Derivative Contract Net Assets (Liabilities)	(47.5)	(50.7)
OPCo | Prepaid Expenses and Other Current Assets
Total Assets
Gross Amounts Recognized	0	0
Gross Amounts Offset	0	0
OPCo | Other Noncurrent Assets
Total Assets
Gross Amounts Recognized	0	0
Gross Amounts Offset	0	0
OPCo | Other Current Liabilities
Total Liabilities
Gross Amounts Recognized	7.5	6.9
Gross Amounts Offset	(0.2)	(0.1)
OPCo | Other Noncurrent Liabilities
Total Liabilities
Gross Amounts Recognized	40.2	43.9
Gross Amounts Offset	0	0
PSO
Total Assets
Gross Amounts Recognized	23.9	19.7
Current Risk Management Assets	20.6	19
Long-term Risk Management Assets	1.4	0
Total Risk Management Assets	22	19
Total Liabilities
Gross Amounts Recognized	7.8	30.7
Current Risk Management Liabilities	5.8	28.9
Long-term Risk Management Liabilities	0	1
Total Risk Management Liabilities	5.8	29.9
Total MTM Derivative Contract Net Assets (Liabilities)	16.2	(10.9)
PSO | Prepaid Expenses and Other Current Assets
Total Assets
Gross Amounts Recognized	22.3	19.7
Gross Amounts Offset	(1.7)	(0.7)
PSO | Other Noncurrent Assets
Total Assets
Gross Amounts Recognized	1.6	0
Gross Amounts Offset	(0.2)	0
PSO | Other Current Liabilities
Total Liabilities
Gross Amounts Recognized	7.6	29.7
Gross Amounts Offset	(1.8)	(0.8)
PSO | Other Noncurrent Liabilities
Total Liabilities
Gross Amounts Recognized	0.2	1
Gross Amounts Offset	(0.2)	0
SWEPCo
Total Assets
Gross Amounts Recognized	19.1	12.5
Current Risk Management Assets	18.1	11.6
Long-term Risk Management Assets	0	0
Total Risk Management Assets	18.1	11.6
Total Liabilities
Gross Amounts Recognized	3.4	16.6
Current Risk Management Liabilities	2.3	14.4
Long-term Risk Management Liabilities	0	1.2
Total Risk Management Liabilities	2.3	15.6
Total MTM Derivative Contract Net Assets (Liabilities)	15.8	(4)
SWEPCo | Prepaid Expenses and Other Current Assets
Total Assets
Gross Amounts Recognized	19.1	12
Gross Amounts Offset	(1)	(0.4)
SWEPCo | Other Noncurrent Assets
Total Assets
Gross Amounts Recognized	0	0.5
Gross Amounts Offset	0	(0.5)
SWEPCo | Other Current Liabilities
Total Liabilities
Gross Amounts Recognized	3.4	14.9
Gross Amounts Offset	(1.1)	(0.5)
SWEPCo | Other Noncurrent Liabilities
Total Liabilities
Gross Amounts Recognized	0	1.7
Gross Amounts Offset	$ 0	$ (0.5)

DERIVATIVES AND HEDGING - Sch_4

DERIVATIVES AND HEDGING - Schedule of Gain (Loss) Recognized on Risk Management Contracts (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	$ 151.1	$ (322.8)	$ 693.7
Regulatory Assets
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	73	(94.8)	52.6
Regulatory Liabilities
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	270.7	169.7	299.7
Revenues | Vertically Integrated Utilities Revenues
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	(23.7)	24.6	11.1
Revenues | Generation & Marketing
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	(171.5)	(423.8)	313.8
Revenues | Electric Generation, Transmission and Distribution Revenues
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	3	2.5	5
Other Operation
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	(0.2)	(0.2)	4.8
Maintenance
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	(0.2)	(0.8)	6.7
AEP Texas
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	(0.2)	(0.6)	2.8
AEP Texas | Regulatory Assets
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	(0.1)	(0.2)	0.1
AEP Texas | Regulatory Liabilities
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	(0.6)
AEP Texas | Revenues | Vertically Integrated Utilities Revenues
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0
AEP Texas | Revenues | Generation & Marketing
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0
AEP Texas | Revenues | Electric Generation, Transmission and Distribution Revenues
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0
AEP Texas | Purchased Electricity, Fuel and Other Consumables Used for Electric Generation
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0
AEP Texas | Other Operation
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	(0.1)	1.5
AEP Texas | Maintenance
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	(0.1)	(0.3)	1.8
APCo
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	78	(18.6)	88.6
APCo | Regulatory Assets
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	21.7	(21.9)	(0.1)
APCo | Regulatory Liabilities
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	53.4	1	82.4
APCo | Revenues | Vertically Integrated Utilities Revenues
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0
APCo | Revenues | Generation & Marketing
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0
APCo | Revenues | Electric Generation, Transmission and Distribution Revenues
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0.2	0.1	0.5
APCo | Purchased Electricity, Fuel and Other Consumables Used for Electric Generation
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	2.7	2.3	4.5
APCo | Other Operation
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0.4
APCo | Maintenance
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	(0.1)	0.9
I&M
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	(7.5)	29.2	19.6
I&M | Regulatory Assets
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	2.8	(3.1)	(0.8)
I&M | Regulatory Liabilities
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	13.4	7.8	8.6
I&M | Revenues | Vertically Integrated Utilities Revenues
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0
I&M | Revenues | Generation & Marketing
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0
I&M | Revenues | Electric Generation, Transmission and Distribution Revenues
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	(23.9)	24.5	10.6
I&M | Purchased Electricity, Fuel and Other Consumables Used for Electric Generation
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0.2	0.1	0.1
I&M | Other Operation
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0.5
I&M | Maintenance
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	(0.1)	0.6
OPCo
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	(1.8)	(14.1)	57.8
OPCo | Regulatory Assets
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	(1.8)	(14)	52.1
OPCo | Regulatory Liabilities
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	3.7
OPCo | Revenues | Vertically Integrated Utilities Revenues
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0
OPCo | Revenues | Generation & Marketing
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0
OPCo | Revenues | Electric Generation, Transmission and Distribution Revenues
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0
OPCo | Purchased Electricity, Fuel and Other Consumables Used for Electric Generation
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0
OPCo | Other Operation
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0.8
OPCo | Maintenance
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	(0.1)	1.2
PSO
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	119.6	58.8	103.7
PSO | Regulatory Assets
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	26	(29.8)	3.6
PSO | Regulatory Liabilities
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	93.6	88.7	98.5
PSO | Revenues | Vertically Integrated Utilities Revenues
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0
PSO | Revenues | Generation & Marketing
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0
PSO | Revenues | Electric Generation, Transmission and Distribution Revenues
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0
PSO | Purchased Electricity, Fuel and Other Consumables Used for Electric Generation
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0.2
PSO | Other Operation
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0.6
PSO | Maintenance
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	(0.1)	0.8
SWEPCo
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	109.1	55	77.7
SWEPCo | Regulatory Assets
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	14.2	(15.5)	(2.1)
SWEPCo | Regulatory Liabilities
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	95	70.7	77.9
SWEPCo | Revenues | Vertically Integrated Utilities Revenues
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0
SWEPCo | Revenues | Generation & Marketing
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0
SWEPCo | Revenues | Electric Generation, Transmission and Distribution Revenues
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0
SWEPCo | Purchased Electricity, Fuel and Other Consumables Used for Electric Generation
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	0	0	0
SWEPCo | Other Operation
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	(0.1)	0	0.8
SWEPCo | Maintenance
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Total Gain (Loss) on Risk Management Contracts	$ 0	$ (0.2)	$ 1.1

DERIVATIVES AND HEDGING - Sch_5

DERIVATIVES AND HEDGING - Schedule of Hedged Items Recognized on the Balance Sheet (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Carrying Amount of the Hedged Liabilities	$ (898.6)	$ (878.2)
Hedged liability, statement of financial position	Long-term Debt Due Within One Year – Nonaffiliated, Long-term Debt – Nonaffiliated	Long-term Debt Due Within One Year – Nonaffiliated, Long-term Debt – Nonaffiliated
Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of the Hedged Liabilities	$ 49.3	$ 68.4
Discontinued fair value hedge, cumulative decrease	$ (22)	$ (30)

DERIVATIVES AND HEDGING - Sch_6

DERIVATIVES AND HEDGING - Schedule of Pretax Effects of Fair Value Hedge Accounting on Income (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Gain (Loss) on Interest Rate Contracts:
Fair Value Hedging Instruments	$ 26.8	$ 29	$ (90.4)
Derivative, gain (loss), statement of income or comprehensive income	Interest Expense	Interest Expense	Interest Expense
Fair Value Portion of Long-term Debt	$ (26.8)	$ (29)	$ 90.4

DERIVATIVES AND HEDGING - Sch_7

DERIVATIVES AND HEDGING - Schedule of Cash Flow Hedges Included in Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Commodity
Derivative Instruments and Hedging Activities Disclosures [Line Items]
AOCI Gain (Loss) Net of Tax	$ 98.5	$ 104.9
Portion Expected to be Reclassed to Net Income During the Next Twelve Months	33.9	38.3
Commodity | AEP Texas
Derivative Instruments and Hedging Activities Disclosures [Line Items]
AOCI Gain (Loss) Net of Tax	0	0
Portion Expected to be Reclassed to Net Income During the Next Twelve Months	0	0
Commodity | APCo
Derivative Instruments and Hedging Activities Disclosures [Line Items]
AOCI Gain (Loss) Net of Tax	0	0
Portion Expected to be Reclassed to Net Income During the Next Twelve Months	0	0
Commodity | I&M
Derivative Instruments and Hedging Activities Disclosures [Line Items]
AOCI Gain (Loss) Net of Tax	0	0
Portion Expected to be Reclassed to Net Income During the Next Twelve Months	0	0
Commodity | PSO
Derivative Instruments and Hedging Activities Disclosures [Line Items]
AOCI Gain (Loss) Net of Tax	0	0
Portion Expected to be Reclassed to Net Income During the Next Twelve Months	0	0
Commodity | SWEPCo
Derivative Instruments and Hedging Activities Disclosures [Line Items]
AOCI Gain (Loss) Net of Tax	0	0
Portion Expected to be Reclassed to Net Income During the Next Twelve Months	0	0
Interest Rate on Long-term Debt (USD)
Derivative Instruments and Hedging Activities Disclosures [Line Items]
AOCI Gain (Loss) Net of Tax	3.3	(8.1)
Portion Expected to be Reclassed to Net Income During the Next Twelve Months	2.8	3.2
Interest Rate on Long-term Debt (USD) | AEP Texas
Derivative Instruments and Hedging Activities Disclosures [Line Items]
AOCI Gain (Loss) Net of Tax	6.3	0.5
Portion Expected to be Reclassed to Net Income During the Next Twelve Months	0.7	0.2
Interest Rate on Long-term Debt (USD) | APCo
Derivative Instruments and Hedging Activities Disclosures [Line Items]
AOCI Gain (Loss) Net of Tax	5.1	5.9
Portion Expected to be Reclassed to Net Income During the Next Twelve Months	0.8	0.8
Interest Rate on Long-term Debt (USD) | I&M
Derivative Instruments and Hedging Activities Disclosures [Line Items]
AOCI Gain (Loss) Net of Tax	(5.1)	(5.5)
Portion Expected to be Reclassed to Net Income During the Next Twelve Months	(0.4)	(0.4)
Interest Rate on Long-term Debt (USD) | PSO
Derivative Instruments and Hedging Activities Disclosures [Line Items]
AOCI Gain (Loss) Net of Tax	3.6	(0.2)
Portion Expected to be Reclassed to Net Income During the Next Twelve Months	0.2	0
Interest Rate on Long-term Debt (USD) | SWEPCo
Derivative Instruments and Hedging Activities Disclosures [Line Items]
AOCI Gain (Loss) Net of Tax	1	1.3
Portion Expected to be Reclassed to Net Income During the Next Twelve Months	$ 0.3	$ 0.3

FAIR VALUE MEASUREMENTS - Debt

FAIR VALUE MEASUREMENTS - Debt Fair Value (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Book Value	$ 42,642.8	$ 40,143.2
Fair Value	38,964.7	37,325.7
AEP TEXAS INC.
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Book Value	6,441.6	5,889.8
Fair Value	5,831.4	5,400.7
AEP TRANSMISSION COMPANY, LLC
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Book Value	5,768.1	5,414.4
Fair Value	4,853.1	4,796.9
APPALACHIAN POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Book Value	5,660.3	5,588.3
Fair Value	5,346	5,390.1
INDIANA MICHIGAN POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Book Value	3,494.3	3,499.4
Fair Value	3,153.8	3,291.6
OHIO POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Book Value	3,715.7	3,366.8
Fair Value	3,203.4	2,992.1
PUBLIC SERVICE COMPANY OF OKLAHOMA
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Book Value	2,855.6	2,384.6
Fair Value	2,562.1	2,154.3
SOUTHWESTERN ELECTRIC POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Book Value	3,980.8	3,646.9
Fair Value	$ 3,431.5	$ 3,209.7

FAIR VALUE MEASUREMENTS - Fair

FAIR VALUE MEASUREMENTS - Fair Value of Other Temporary Investments and Cash (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value	$ 4,395.1	$ 3,860.2
Other Temporary Investments And Restricted Cash
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cost	236.9	243.5
Gross unrealized gains	26.9	25.9
Gross unrealized losses	(5.3)	(6.2)
Fair value	258.5	263.2
Restricted Cash
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cost	43.1	48.9
Gross unrealized gains	0	0
Gross unrealized losses	0	0
Fair value	43.1	48.9
Other Cash Deposits
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cost	13.9	13.9
Gross unrealized gains	0	0
Gross unrealized losses	0	0
Fair value	13.9	13.9
Fixed Income Securities – Mutual Funds
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cost	167.2	165.9
Gross unrealized gains	0	0
Gross unrealized losses	(5.3)	(6.2)
Fair value	161.9	159.7
Equity Securities – Mutual Funds
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cost	12.7	14.8
Gross unrealized gains	26.9	25.9
Gross unrealized losses	0	0
Fair value	$ 39.6	$ 40.7

FAIR VALUE MEASUREMENTS - Activ

FAIR VALUE MEASUREMENTS - Activity for Investments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Fair Value Disclosures [Abstract]
Proceeds from Investment Sales	$ 26.8	$ 7.6	$ 30.2
Purchases of Investments	20.1	18.5	18.8
Gross Realized Gains on Investment Sales	6.3	1.1	6.1
Gross Realized Losses on Investment Sales	$ 0.8	$ 0.3	$ 1.3

FAIR VALUE MEASUREMENTS - Summa

FAIR VALUE MEASUREMENTS - Summary of Nuclear Trust Investments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value	$ 4,395.1	$ 3,860.2
Spent Nuclear Fuel and Decommissioning Trusts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross unrealized gains	2,297.8	1,902.9
Gross unrealized losses	(15.5)	(10)
Other than temporary impairments	(26)	(41.8)
INDIANA MICHIGAN POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value	4,395.1	3,860.2
INDIANA MICHIGAN POWER COMPANY | Spent Nuclear Fuel and Decommissioning Trusts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross unrealized gains	2,297.8	1,902.9
Gross unrealized losses	(15.5)	(10)
Other than temporary impairments	(26)	(41.8)
Cash and Cash Equivalents
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value	23.3	16.8
Cash and Cash Equivalents | Spent Nuclear Fuel and Decommissioning Trusts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross unrealized gains	0	0
Gross unrealized losses	0	0
Other than temporary impairments	0	0
Cash and Cash Equivalents | INDIANA MICHIGAN POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value	23.3	16.8
Cash and Cash Equivalents | INDIANA MICHIGAN POWER COMPANY | Spent Nuclear Fuel and Decommissioning Trusts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross unrealized gains	0	0
Gross unrealized losses	0	0
Other than temporary impairments	0	0
United States Government
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value	1,322.8	1,273
United States Government | Spent Nuclear Fuel and Decommissioning Trusts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross unrealized gains	8.2	28.6
Gross unrealized losses	(5.3)	(3.9)
Other than temporary impairments	(20.2)	(33.2)
United States Government | INDIANA MICHIGAN POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value	1,322.8	1,273
United States Government | INDIANA MICHIGAN POWER COMPANY | Spent Nuclear Fuel and Decommissioning Trusts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross unrealized gains	8.2	28.6
Gross unrealized losses	(5.3)	(3.9)
Other than temporary impairments	(20.2)	(33.2)
Corporate Debt
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value	211.3	132.1
Corporate Debt | Spent Nuclear Fuel and Decommissioning Trusts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross unrealized gains	0.7	4.8
Gross unrealized losses	(9.8)	(5.2)
Other than temporary impairments	(5.8)	(8.6)
Corporate Debt | INDIANA MICHIGAN POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value	211.3	132.1
Corporate Debt | INDIANA MICHIGAN POWER COMPANY | Spent Nuclear Fuel and Decommissioning Trusts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross unrealized gains	0.7	4.8
Gross unrealized losses	(9.8)	(5.2)
Other than temporary impairments	(5.8)	(8.6)
State and Local Government
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value	0	1.7
State and Local Government | Spent Nuclear Fuel and Decommissioning Trusts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross unrealized gains	0	0
Gross unrealized losses	0	0
Other than temporary impairments	0	0
State and Local Government | INDIANA MICHIGAN POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value	0	1.7
State and Local Government | INDIANA MICHIGAN POWER COMPANY | Spent Nuclear Fuel and Decommissioning Trusts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross unrealized gains	0	0
Gross unrealized losses	0	0
Other than temporary impairments	0	0
Subtotal Fixed Income Securities
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value	1,534.1	1,406.8
Subtotal Fixed Income Securities | Spent Nuclear Fuel and Decommissioning Trusts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross unrealized gains	8.9	33.4
Gross unrealized losses	(15.1)	(9.1)
Other than temporary impairments	(26)	(41.8)
Subtotal Fixed Income Securities | INDIANA MICHIGAN POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value	1,534.1	1,406.8
Subtotal Fixed Income Securities | INDIANA MICHIGAN POWER COMPANY | Spent Nuclear Fuel and Decommissioning Trusts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross unrealized gains	8.9	33.4
Gross unrealized losses	(15.1)	(9.1)
Other than temporary impairments	(26)	(41.8)
Equity Securities - Domestic
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value	2,837.7	2,436.6
Equity Securities - Domestic | Spent Nuclear Fuel and Decommissioning Trusts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross unrealized gains	2,288.9	1,869.5
Gross unrealized losses	(0.4)	(0.9)
Other than temporary impairments	0	0
Equity Securities - Domestic | INDIANA MICHIGAN POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value	2,837.7	2,436.6
Equity Securities - Domestic | INDIANA MICHIGAN POWER COMPANY | Spent Nuclear Fuel and Decommissioning Trusts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross unrealized gains	2,288.9	1,869.5
Gross unrealized losses	(0.4)	(0.9)
Other than temporary impairments	$ 0	$ 0

FAIR VALUE MEASUREMENTS - Secur

FAIR VALUE MEASUREMENTS - Securities Activity (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Purchases of Investments	$ 2,922.5	$ 2,863.6	$ 2,784.2
INDIANA MICHIGAN POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Purchases of Investments	2,902.4	2,845.1	2,765.4
Spent Nuclear Fuel and Decommissioning Trusts
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Proceeds from Investment Sales	2,851.2	2,787.5	2,713.6
Purchases of Investments	2,902.4	2,845.1	2,765.4
Gross Realized Gains on Investment Sales	125.5	99	52.4
Gross Realized Losses on Investment Sales	11.5	26.6	42.6
Spent Nuclear Fuel and Decommissioning Trusts | INDIANA MICHIGAN POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Proceeds from Investment Sales	2,851.2	2,787.5	2,713.6
Purchases of Investments	2,902.4	2,845.1	2,765.4
Gross Realized Gains on Investment Sales	125.5	99	52.4
Gross Realized Losses on Investment Sales	$ 11.5	$ 26.6	$ 42.6

FAIR VALUE MEASUREMENTS - Narra

FAIR VALUE MEASUREMENTS - Narrative (Details) - Spent Nuclear Fuel and Decommissioning Trusts - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Adjusted cost of debt securities	$ 1,500	$ 1,400
Adjusted cost of equity securities	549	568
INDIANA MICHIGAN POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Adjusted cost of debt securities	1,500	1,400
Adjusted cost of equity securities	$ 549	$ 568

FAIR VALUE MEASUREMENTS - Fixed

FAIR VALUE MEASUREMENTS - Fixed Income Securities Held in Nuclear Trusts (Details) - Spent Nuclear Fuel and Decommissioning Trusts $ in Millions	Dec. 31, 2024 USD ($)
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Within 1 year	$ 376.4
After 1 year through 5 years	598.8
After 5 years through 10 years	236.2
After 10 years	322.7
Total	1,534.1
INDIANA MICHIGAN POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Within 1 year	376.4
After 1 year through 5 years	598.8
After 5 years through 10 years	236.2
After 10 years	322.7
Total	$ 1,534.1

FAIR VALUE MEASUREMENTS - Fai_2

FAIR VALUE MEASUREMENTS - Fair Value of Assets and Liabilities on a Recurring Basis (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Other Temporary Investments and Restricted Cash
Total Other Temporary Investments and Restricted Cash	$ 258.5	$ 263.2
Risk Management Assets
Total Risk Management Assets	499.5	538.7
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	4,395.1	3,860.2
Total Assets	5,153.1	4,662.1
Risk Management Liabilities
Total Risk Management Liabilities	324.4	471.4
AEP TEXAS INC.
Other Temporary Investments and Restricted Cash
Restricted Cash	23.5	34
Risk Management Assets
Total Risk Management Assets	0	0
Risk Management Liabilities
Total Risk Management Liabilities	0	2.7
APPALACHIAN POWER COMPANY
Other Temporary Investments and Restricted Cash
Restricted Cash	16.2	14.9
Risk Management Assets
Total Risk Management Assets	37.1	22.4
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets	53.3	37.3
Risk Management Liabilities
Total Risk Management Liabilities	2.2	22.5
INDIANA MICHIGAN POWER COMPANY
Risk Management Assets
Total Risk Management Assets	18.4	39.6
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	4,395.1	3,860.2
Total Assets	4,413.5	3,899.8
Risk Management Liabilities
Total Risk Management Liabilities	0.7	2
OHIO POWER COMPANY
Risk Management Assets
Total Risk Management Assets	0	0
Risk Management Liabilities
Total Risk Management Liabilities	47.5	50.7
PUBLIC SERVICE COMPANY OF OKLAHOMA
Risk Management Assets
Total Risk Management Assets	22	19
Risk Management Liabilities
Total Risk Management Liabilities	5.8	29.9
SOUTHWESTERN ELECTRIC POWER COMPANY
Other Temporary Investments and Restricted Cash
Restricted Cash	3.4
Risk Management Assets
Total Risk Management Assets	18.1	11.6
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets	21.5
Risk Management Liabilities
Total Risk Management Liabilities	2.3	15.6
Risk Management Commodity Contracts
Risk Management Assets
Total Risk Management Assets	374.6	403.9
Risk Management Liabilities
Total Risk Management Liabilities	252.6	362.3
Risk Management Commodity Contracts | AEP TEXAS INC.
Risk Management Liabilities
Total Risk Management Liabilities	0	0
Risk Management Commodity Contracts | APPALACHIAN POWER COMPANY
Risk Management Assets
Total Risk Management Assets	37.1	22.4
Risk Management Liabilities
Total Risk Management Liabilities	2.2	22.5
Risk Management Commodity Contracts | INDIANA MICHIGAN POWER COMPANY
Risk Management Assets
Total Risk Management Assets	18.4	39.6
Risk Management Liabilities
Total Risk Management Liabilities	0.7	2
Risk Management Commodity Contracts | OHIO POWER COMPANY
Risk Management Liabilities
Total Risk Management Liabilities	47.5	50.7
Risk Management Commodity Contracts | PUBLIC SERVICE COMPANY OF OKLAHOMA
Risk Management Assets
Total Risk Management Assets	22	19
Risk Management Liabilities
Total Risk Management Liabilities	5.8	29.9
Risk Management Commodity Contracts | SOUTHWESTERN ELECTRIC POWER COMPANY
Risk Management Assets
Total Risk Management Assets	18.1	11.6
Risk Management Liabilities
Total Risk Management Liabilities	2.3	15.6
Commodity Hedges
Risk Management Assets
Total Risk Management Assets	124.9	134.8
Risk Management Liabilities
Total Risk Management Liabilities	0.2	1.7
Interest Rate Hedges
Risk Management Liabilities
Total Risk Management Liabilities		9
Interest Rate Hedges | AEP TEXAS INC.
Risk Management Liabilities
Total Risk Management Liabilities		2.7
Fair Value Hedges
Risk Management Liabilities
Total Risk Management Liabilities	71.6	98.4
Other
Other Temporary Investments and Restricted Cash
Total Other Temporary Investments and Restricted Cash	13.9	13.9
Risk Management Assets
Total Risk Management Assets	(529.8)	(625.5)
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	13.7	9
Total Assets	(502.2)	(602.6)
Risk Management Liabilities
Total Risk Management Liabilities	(446.2)
Total Risk Management Liabilities		(608.8)
Other | AEP TEXAS INC.
Other Temporary Investments and Restricted Cash
Restricted Cash	0	0
Risk Management Liabilities
Total Risk Management Liabilities		(0.2)
Other | APPALACHIAN POWER COMPANY
Other Temporary Investments and Restricted Cash
Restricted Cash	0	0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets	(4.6)	(2.2)
Other | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	13.7	9
Total Assets	5.3	6.7
Other | SOUTHWESTERN ELECTRIC POWER COMPANY
Other Temporary Investments and Restricted Cash
Restricted Cash	0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets	(1)
Other | Risk Management Commodity Contracts
Risk Management Assets
Total Risk Management Assets	(517.2)	(617)
Risk Management Liabilities
Total Risk Management Liabilities	(433.6)
Total Risk Management Liabilities		(600.3)
Other | Risk Management Commodity Contracts | AEP TEXAS INC.
Risk Management Liabilities
Total Risk Management Liabilities	(0.3)	(0.2)
Other | Risk Management Commodity Contracts | APPALACHIAN POWER COMPANY
Risk Management Assets
Total Risk Management Assets	(4.6)	(2.2)
Risk Management Liabilities
Total Risk Management Liabilities	(4.7)	(2.6)
Other | Risk Management Commodity Contracts | INDIANA MICHIGAN POWER COMPANY
Risk Management Assets
Total Risk Management Assets	(8.4)	(2.3)
Risk Management Liabilities
Total Risk Management Liabilities	(9)	(3.4)
Other | Risk Management Commodity Contracts | OHIO POWER COMPANY
Risk Management Liabilities
Total Risk Management Liabilities	(0.2)	(0.1)
Other | Risk Management Commodity Contracts | PUBLIC SERVICE COMPANY OF OKLAHOMA
Risk Management Assets
Total Risk Management Assets	(1.9)	(0.7)
Risk Management Liabilities
Total Risk Management Liabilities	(2)	(0.8)
Other | Risk Management Commodity Contracts | SOUTHWESTERN ELECTRIC POWER COMPANY
Risk Management Assets
Total Risk Management Assets	(1)	(0.9)
Risk Management Liabilities
Total Risk Management Liabilities	(1.1)	(1)
Other | Commodity Hedges
Risk Management Assets
Total Risk Management Assets	(12.6)	(8.5)
Risk Management Liabilities
Total Risk Management Liabilities	(12.6)
Total Risk Management Liabilities		(8.5)
Other | Interest Rate Hedges
Risk Management Liabilities
Total Risk Management Liabilities		0
Other | Interest Rate Hedges | AEP TEXAS INC.
Risk Management Liabilities
Total Risk Management Liabilities		0
Other | Fair Value Hedges
Risk Management Liabilities
Total Risk Management Liabilities	0
Total Risk Management Liabilities		0
Restricted Cash
Other Temporary Investments and Restricted Cash
Restricted Cash	43.1	48.9
Restricted Cash | Other
Other Temporary Investments and Restricted Cash
Restricted Cash	0	0
Other Cash Deposits
Other Temporary Investments and Restricted Cash
Total Other Temporary Investments and Restricted Cash	13.9	13.9
Other Cash Deposits | Other
Other Temporary Investments and Restricted Cash
Total Other Temporary Investments and Restricted Cash	13.9	13.9
Fixed Income Securities – Mutual Funds
Other Temporary Investments and Restricted Cash
Total Other Temporary Investments and Restricted Cash	161.9	159.7
Fixed Income Securities – Mutual Funds | Other
Other Temporary Investments and Restricted Cash
Total Other Temporary Investments and Restricted Cash	0	0
Equity Securities - Mutual Funds
Other Temporary Investments and Restricted Cash
Total Other Temporary Investments and Restricted Cash	39.6	40.7
Equity Securities - Mutual Funds | Other
Other Temporary Investments and Restricted Cash
Total Other Temporary Investments and Restricted Cash	0	0
Cash and Cash Equivalents
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	23.3	16.8
Cash and Cash Equivalents | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	23.3	16.8
Cash and Cash Equivalents | Other
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	13.7	9
Cash and Cash Equivalents | Other | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	13.7	9
United States Government
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	1,322.8	1,273
United States Government | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	1,322.8	1,273
United States Government | Other
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
United States Government | Other | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Corporate Debt
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	211.3	132.1
Corporate Debt | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	211.3	132.1
Corporate Debt | Other
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Corporate Debt | Other | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
State and Local Government
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	1.7
State and Local Government | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	1.7
State and Local Government | Other
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
State and Local Government | Other | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Subtotal Fixed Income Securities
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	1,534.1	1,406.8
Subtotal Fixed Income Securities | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	1,534.1	1,406.8
Subtotal Fixed Income Securities | Other
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Subtotal Fixed Income Securities | Other | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Equity Securities - Domestic
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	2,837.7	2,436.6
Equity Securities - Domestic | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	2,837.7	2,436.6
Equity Securities - Domestic | Other
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Equity Securities - Domestic | Other | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 1
Other Temporary Investments and Restricted Cash
Total Other Temporary Investments and Restricted Cash	244.6	249.3
Risk Management Assets
Total Risk Management Assets	2.9	9.7
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	2,847.3	2,444.4
Total Assets	3,094.8	2,703.4
Risk Management Liabilities
Total Risk Management Liabilities	4.4	24.7
Level 1 | 2025
Risk Management Liabilities
Maturities of net fair value of risk management contracts	(1)
Level 1 | 2024
Risk Management Liabilities
Maturities of net fair value of risk management contracts		(11)
Level 1 | 2025 - 2027
Risk Management Liabilities
Maturities of net fair value of risk management contracts		(4)
Level 1 | AEP TEXAS INC.
Other Temporary Investments and Restricted Cash
Restricted Cash	23.5	34
Risk Management Liabilities
Total Risk Management Liabilities		0
Level 1 | APPALACHIAN POWER COMPANY
Other Temporary Investments and Restricted Cash
Restricted Cash	16.2	14.9
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets	16.2	14.9
Level 1 | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	2,847.3	2,444.4
Total Assets	2,847.3	2,444.4
Level 1 | SOUTHWESTERN ELECTRIC POWER COMPANY
Other Temporary Investments and Restricted Cash
Restricted Cash	3.4
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		3.4
Level 1 | Risk Management Commodity Contracts
Risk Management Assets
Total Risk Management Assets	2.9	9.7
Risk Management Liabilities
Total Risk Management Liabilities	4.4	24.7
Level 1 | Risk Management Commodity Contracts | AEP TEXAS INC.
Risk Management Liabilities
Total Risk Management Liabilities	0	0
Level 1 | Risk Management Commodity Contracts | APPALACHIAN POWER COMPANY
Risk Management Assets
Total Risk Management Assets	0	0
Risk Management Liabilities
Total Risk Management Liabilities	0	0
Level 1 | Risk Management Commodity Contracts | INDIANA MICHIGAN POWER COMPANY
Risk Management Assets
Total Risk Management Assets	0	0
Risk Management Liabilities
Total Risk Management Liabilities	0	0
Level 1 | Risk Management Commodity Contracts | OHIO POWER COMPANY
Risk Management Liabilities
Total Risk Management Liabilities	0	0
Level 1 | Risk Management Commodity Contracts | PUBLIC SERVICE COMPANY OF OKLAHOMA
Risk Management Assets
Total Risk Management Assets	0	0
Risk Management Liabilities
Total Risk Management Liabilities	0	0
Level 1 | Risk Management Commodity Contracts | SOUTHWESTERN ELECTRIC POWER COMPANY
Risk Management Assets
Total Risk Management Assets	0	0
Risk Management Liabilities
Total Risk Management Liabilities	0	0
Level 1 | Commodity Hedges
Risk Management Assets
Total Risk Management Assets	0	0
Risk Management Liabilities
Total Risk Management Liabilities	0	0
Level 1 | Interest Rate Hedges
Risk Management Liabilities
Total Risk Management Liabilities		0
Level 1 | Interest Rate Hedges | AEP TEXAS INC.
Risk Management Liabilities
Total Risk Management Liabilities		0
Level 1 | Fair Value Hedges
Risk Management Liabilities
Total Risk Management Liabilities	0	0
Level 1 | Restricted Cash
Other Temporary Investments and Restricted Cash
Restricted Cash	43.1	48.9
Level 1 | Other Cash Deposits
Other Temporary Investments and Restricted Cash
Total Other Temporary Investments and Restricted Cash	0	0
Level 1 | Fixed Income Securities – Mutual Funds
Other Temporary Investments and Restricted Cash
Total Other Temporary Investments and Restricted Cash	161.9	159.7
Level 1 | Equity Securities - Mutual Funds
Other Temporary Investments and Restricted Cash
Total Other Temporary Investments and Restricted Cash	39.6	40.7
Level 1 | Cash and Cash Equivalents
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	9.6	7.8
Level 1 | Cash and Cash Equivalents | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	9.6	7.8
Level 1 | United States Government
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 1 | United States Government | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 1 | Corporate Debt
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 1 | Corporate Debt | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 1 | State and Local Government
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 1 | State and Local Government | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 1 | Subtotal Fixed Income Securities
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 1 | Subtotal Fixed Income Securities | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 1 | Equity Securities - Domestic
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	2,837.7	2,436.6
Level 1 | Equity Securities - Domestic | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	2,837.7	2,436.6
Level 2
Other Temporary Investments and Restricted Cash
Total Other Temporary Investments and Restricted Cash	0	0
Risk Management Assets
Total Risk Management Assets	712.9	860.4
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	1,534.1	1,406.8
Total Assets	2,247	2,267.2
Risk Management Liabilities
Total Risk Management Liabilities	618.3	900.8
Level 2 | 2025
Risk Management Liabilities
Maturities of net fair value of risk management contracts	16
Level 2 | 2026 - 2028
Risk Management Liabilities
Maturities of net fair value of risk management contracts	43
Level 2 | 2029-2030
Risk Management Liabilities
Maturities of net fair value of risk management contracts	4
Level 2 | 2024
Risk Management Liabilities
Maturities of net fair value of risk management contracts		(99)
Level 2 | 2025 - 2027
Risk Management Liabilities
Maturities of net fair value of risk management contracts		(44)
Level 2 | 2028 - 2029
Risk Management Liabilities
Maturities of net fair value of risk management contracts		7
Level 2 | 2030 - 2033
Risk Management Liabilities
Maturities of net fair value of risk management contracts		2
Level 2 | AEP TEXAS INC.
Other Temporary Investments and Restricted Cash
Restricted Cash	0	0
Risk Management Liabilities
Total Risk Management Liabilities		2.9
Level 2 | APPALACHIAN POWER COMPANY
Other Temporary Investments and Restricted Cash
Restricted Cash	0	0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets	6.5	1.1
Level 2 | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	1,534.1	1,406.8
Total Assets	1,554	1,444.2
Level 2 | SOUTHWESTERN ELECTRIC POWER COMPANY
Other Temporary Investments and Restricted Cash
Restricted Cash	0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets	1
Level 2 | Risk Management Commodity Contracts
Risk Management Assets
Total Risk Management Assets	597.3	736.9
Risk Management Liabilities
Total Risk Management Liabilities	534.1	783.8
Level 2 | Risk Management Commodity Contracts | AEP TEXAS INC.
Risk Management Liabilities
Total Risk Management Liabilities	0.3	0.2
Level 2 | Risk Management Commodity Contracts | APPALACHIAN POWER COMPANY
Risk Management Assets
Total Risk Management Assets	6.5	1.1
Risk Management Liabilities
Total Risk Management Liabilities	6.9	24
Level 2 | Risk Management Commodity Contracts | INDIANA MICHIGAN POWER COMPANY
Risk Management Assets
Total Risk Management Assets	19.9	37.4
Risk Management Liabilities
Total Risk Management Liabilities	9.2	3.7
Level 2 | Risk Management Commodity Contracts | OHIO POWER COMPANY
Risk Management Liabilities
Total Risk Management Liabilities	0.2	0.2
Level 2 | Risk Management Commodity Contracts | PUBLIC SERVICE COMPANY OF OKLAHOMA
Risk Management Assets
Total Risk Management Assets	3.1	0
Risk Management Liabilities
Total Risk Management Liabilities	7	29.6
Level 2 | Risk Management Commodity Contracts | SOUTHWESTERN ELECTRIC POWER COMPANY
Risk Management Assets
Total Risk Management Assets	1	0.5
Risk Management Liabilities
Total Risk Management Liabilities	2.8	15.7
Level 2 | Commodity Hedges
Risk Management Assets
Total Risk Management Assets	115.6	123.5
Risk Management Liabilities
Total Risk Management Liabilities	12.6	9.6
Level 2 | Interest Rate Hedges
Risk Management Liabilities
Total Risk Management Liabilities		9
Level 2 | Interest Rate Hedges | AEP TEXAS INC.
Risk Management Liabilities
Total Risk Management Liabilities		2.7
Level 2 | Fair Value Hedges
Risk Management Liabilities
Total Risk Management Liabilities	71.6	98.4
Level 2 | Restricted Cash
Other Temporary Investments and Restricted Cash
Restricted Cash	0	0
Level 2 | Other Cash Deposits
Other Temporary Investments and Restricted Cash
Total Other Temporary Investments and Restricted Cash	0	0
Level 2 | Fixed Income Securities – Mutual Funds
Other Temporary Investments and Restricted Cash
Total Other Temporary Investments and Restricted Cash	0	0
Level 2 | Equity Securities - Mutual Funds
Other Temporary Investments and Restricted Cash
Total Other Temporary Investments and Restricted Cash	0	0
Level 2 | Cash and Cash Equivalents
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 2 | Cash and Cash Equivalents | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 2 | United States Government
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	1,322.8	1,273
Level 2 | United States Government | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	1,322.8	1,273
Level 2 | Corporate Debt
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	211.3	132.1
Level 2 | Corporate Debt | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	211.3	132.1
Level 2 | State and Local Government
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	1.7
Level 2 | State and Local Government | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	1.7
Level 2 | Subtotal Fixed Income Securities
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	1,534.1	1,406.8
Level 2 | Subtotal Fixed Income Securities | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	1,534.1	1,406.8
Level 2 | Equity Securities - Domestic
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 2 | Equity Securities - Domestic | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 3
Other Temporary Investments and Restricted Cash
Total Other Temporary Investments and Restricted Cash	0	0
Risk Management Assets
Total Risk Management Assets	313.5	294.1
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Total Assets	313.5	294.1
Risk Management Liabilities
Total Risk Management Liabilities	147.9	154.7
Level 3 | 2025
Risk Management Liabilities
Maturities of net fair value of risk management contracts	106
Level 3 | 2026 - 2028
Risk Management Liabilities
Maturities of net fair value of risk management contracts	45
Level 3 | 2029-2030
Risk Management Liabilities
Maturities of net fair value of risk management contracts	9
Level 3 | 2031 - 2034
Risk Management Liabilities
Maturities of net fair value of risk management contracts	(16)
Level 3 | 2024
Risk Management Liabilities
Maturities of net fair value of risk management contracts		74
Level 3 | 2025 - 2027
Risk Management Liabilities
Maturities of net fair value of risk management contracts		43
Level 3 | 2028 - 2029
Risk Management Liabilities
Maturities of net fair value of risk management contracts		18
Level 3 | 2030 - 2033
Risk Management Liabilities
Maturities of net fair value of risk management contracts		(16)
Level 3 | AEP TEXAS INC.
Other Temporary Investments and Restricted Cash
Restricted Cash	0	0
Risk Management Liabilities
Total Risk Management Liabilities		0
Level 3 | APPALACHIAN POWER COMPANY
Other Temporary Investments and Restricted Cash
Restricted Cash	0	0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets	35.2	23.5
Level 3 | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Total Assets	6.9	4.5
Level 3 | SOUTHWESTERN ELECTRIC POWER COMPANY
Other Temporary Investments and Restricted Cash
Restricted Cash	0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets	18.1
Level 3 | Risk Management Commodity Contracts
Risk Management Assets
Total Risk Management Assets	291.6	274.3
Risk Management Liabilities
Total Risk Management Liabilities	147.7	154.1
Level 3 | Risk Management Commodity Contracts | AEP TEXAS INC.
Risk Management Liabilities
Total Risk Management Liabilities	0	0
Level 3 | Risk Management Commodity Contracts | APPALACHIAN POWER COMPANY
Risk Management Assets
Total Risk Management Assets	35.2	23.5
Risk Management Liabilities
Total Risk Management Liabilities	0	1.1
Level 3 | Risk Management Commodity Contracts | INDIANA MICHIGAN POWER COMPANY
Risk Management Assets
Total Risk Management Assets	6.9	4.5
Risk Management Liabilities
Total Risk Management Liabilities	0.5	1.7
Level 3 | Risk Management Commodity Contracts | OHIO POWER COMPANY
Risk Management Liabilities
Total Risk Management Liabilities	47.5	50.6
Level 3 | Risk Management Commodity Contracts | PUBLIC SERVICE COMPANY OF OKLAHOMA
Risk Management Assets
Total Risk Management Assets	20.8	19.7
Risk Management Liabilities
Total Risk Management Liabilities	0.8	1.1
Level 3 | Risk Management Commodity Contracts | SOUTHWESTERN ELECTRIC POWER COMPANY
Risk Management Assets
Total Risk Management Assets	18.1	12
Risk Management Liabilities
Total Risk Management Liabilities	0.6	0.9
Level 3 | Commodity Hedges
Risk Management Assets
Total Risk Management Assets	21.9	19.8
Risk Management Liabilities
Total Risk Management Liabilities	0.2	0.6
Level 3 | Interest Rate Hedges
Risk Management Liabilities
Total Risk Management Liabilities		0
Level 3 | Interest Rate Hedges | AEP TEXAS INC.
Risk Management Liabilities
Total Risk Management Liabilities		0
Level 3 | Fair Value Hedges
Risk Management Liabilities
Total Risk Management Liabilities	0	0
Level 3 | Restricted Cash
Other Temporary Investments and Restricted Cash
Restricted Cash	0	0
Level 3 | Other Cash Deposits
Other Temporary Investments and Restricted Cash
Total Other Temporary Investments and Restricted Cash	0	0
Level 3 | Fixed Income Securities – Mutual Funds
Other Temporary Investments and Restricted Cash
Total Other Temporary Investments and Restricted Cash	0	0
Level 3 | Equity Securities - Mutual Funds
Other Temporary Investments and Restricted Cash
Total Other Temporary Investments and Restricted Cash	0	0
Level 3 | Cash and Cash Equivalents
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 3 | Cash and Cash Equivalents | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 3 | United States Government
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 3 | United States Government | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 3 | Corporate Debt
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 3 | Corporate Debt | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 3 | State and Local Government
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 3 | State and Local Government | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 3 | Subtotal Fixed Income Securities
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 3 | Subtotal Fixed Income Securities | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 3 | Equity Securities - Domestic
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	0	0
Level 3 | Equity Securities - Domestic | INDIANA MICHIGAN POWER COMPANY
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	$ 0	$ 0

FAIR VALUE MEASUREMENTS - Chang

FAIR VALUE MEASUREMENTS - Changes in Fair Value (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	$ 139.4	$ 160.4	$ 103.1
Realized gain (loss) included in net income (or changes in net assets)	$ 90.3	$ 52.1	$ 69.5
Fair value, net derivative asset (liability), recurring basis, unobservable input reconciliation, gain (loss), statement of income or comprehensive income	Total Revenues	Total Revenues	Total Revenues
Unrealized gain (loss) included in net income (or changes in net assets) relating to assets still held at the reporting date	$ 14.8	$ 71.1	$ (34.9)
Fair value, net derivative asset (liability), recurring basis, still held, unrealized gain (loss), statement of income or comprehensive income	Total Revenues	Total Revenues	Total Revenues
Realized and unrealized gains (losses) included in other comprehensive income	$ 3.9	$ (17.4)	$ 9.6
Fair Value, Net Derivative Asset (Liability), Recurring Basis, Unobservable Input Reconciliation, Gain (Loss), Statement of Other Comprehensive Income or Comprehensive Income [Extensible Enumeration]	Cash Flow Hedges, Net of Tax	Cash Flow Hedges, Net of Tax	Cash Flow Hedges, Net of Tax
Settlements	$ (167.6)	$ (172.2)	$ (154.6)
Transfers into Level 3	6.8	(6.1)	1.7
Transfers out of Level 3	(6.4)	3.8	0.1
Changes in fair value allocated to regulated jurisdictions	84.4	47.7	165.9
Ending balance	165.6	139.4	160.4
APPALACHIAN POWER COMPANY
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	22.4	69.1	41.7
Realized gain (loss) included in net income (or changes in net assets)	24.1	(11.7)	3
Unrealized gain (loss) included in net income (or changes in net assets) relating to assets still held at the reporting date	0	0	0
Realized and unrealized gains (losses) included in other comprehensive income	0	0	0
Settlements	(46.5)	(57.3)	(44.7)
Transfers into Level 3	0	0	0
Transfers out of Level 3	0	0	0
Changes in fair value allocated to regulated jurisdictions	35.2	22.3	69.1
Ending balance	35.2	22.4	69.1
INDIANA MICHIGAN POWER COMPANY
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	2.8	4.6	(0.7)
Realized gain (loss) included in net income (or changes in net assets)	7.3	4.2	3.7
Unrealized gain (loss) included in net income (or changes in net assets) relating to assets still held at the reporting date	0	0	0
Realized and unrealized gains (losses) included in other comprehensive income	0	0	0
Settlements	(10)	(8.8)	(3)
Transfers into Level 3	0	0	0
Transfers out of Level 3	0	0	0
Changes in fair value allocated to regulated jurisdictions	6.3	2.8	4.6
Ending balance	6.4	2.8	4.6
OHIO POWER COMPANY
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	(50.6)	(40)	(92.5)
Realized gain (loss) included in net income (or changes in net assets)	(1.1)	(3.6)	6.5
Unrealized gain (loss) included in net income (or changes in net assets) relating to assets still held at the reporting date	0	0	0
Realized and unrealized gains (losses) included in other comprehensive income	0	0	0
Settlements	7.9	5.6	0.3
Transfers into Level 3	0	0	0
Transfers out of Level 3	0	0	0
Changes in fair value allocated to regulated jurisdictions	(3.7)	(12.6)	45.7
Ending balance	(47.5)	(50.6)	(40)
PUBLIC SERVICE COMPANY OF OKLAHOMA
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	18.6	23.7	12.1
Realized gain (loss) included in net income (or changes in net assets)	26.2	29.8	24.2
Unrealized gain (loss) included in net income (or changes in net assets) relating to assets still held at the reporting date	0	0	0
Realized and unrealized gains (losses) included in other comprehensive income	0	0	0
Settlements	(44.8)	(53.4)	(36.3)
Transfers into Level 3	0	0	0
Transfers out of Level 3	0	0	0
Changes in fair value allocated to regulated jurisdictions	20	18.5	23.7
Ending balance	20	18.6	23.7
SOUTHWESTERN ELECTRIC POWER COMPANY
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	11.1	14.2	10.9
Realized gain (loss) included in net income (or changes in net assets)	23.6	20	35.8
Unrealized gain (loss) included in net income (or changes in net assets) relating to assets still held at the reporting date	0	0	0
Realized and unrealized gains (losses) included in other comprehensive income	0	0	0
Settlements	(36)	(34.2)	(45)
Transfers into Level 3	0	0	0
Transfers out of Level 3	0.5	0	6.9
Changes in fair value allocated to regulated jurisdictions	18.3	11.1	5.6
Ending balance	$ 17.5	$ 11.1	$ 14.2

FAIR VALUE MEASUREMENTS - Signi

FAIR VALUE MEASUREMENTS - Significant Unobservable Inputs (Details) - USD ($)	Dec. 31, 2024	Dec. 31, 2023
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, assets	$ 499,500,000	$ 538,700,000
Fair value, liabilities	324,400,000	471,400,000
APPALACHIAN POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, assets	37,100,000	22,400,000
Fair value, liabilities	2,200,000	22,500,000
INDIANA MICHIGAN POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, assets	18,400,000	39,600,000
Fair value, liabilities	700,000	2,000,000
OHIO POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, assets	0	0
Fair value, liabilities	47,500,000	50,700,000
PUBLIC SERVICE COMPANY OF OKLAHOMA
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, assets	22,000,000	19,000,000
Fair value, liabilities	5,800,000	29,900,000
SOUTHWESTERN ELECTRIC POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, assets	18,100,000	11,600,000
Fair value, liabilities	2,300,000	15,600,000
Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, assets	313,500,000	294,100,000
Fair value, liabilities	147,900,000	154,700,000
Energy Contracts | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, assets	221,200,000	225,500,000
Fair value, liabilities	144,600,000	144,900,000
Energy Contracts | Level 3 | OHIO POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, assets	0	0
Fair value, liabilities	$ 47,500,000	$ 50,600,000
Energy Contracts | Level 3 | Low | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range	2.75	5.21
Input/Range	2.75	5.21
Energy Contracts | Level 3 | Low | OHIO POWER COMPANY | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range	14.53	22.92
Input/Range	14.53	22.92
Energy Contracts | Level 3 | High | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range	149.30	153.77
Input/Range	149.30	153.77
Energy Contracts | Level 3 | High | OHIO POWER COMPANY | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range	72.40	67.53
Input/Range	72.40	67.53
Energy Contracts | Level 3 | Weighted Average | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range	49.34	45.05
Input/Range	49.34	45.05
Energy Contracts | Level 3 | Weighted Average | OHIO POWER COMPANY | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range	42.44	42.85
Input/Range	42.44	42.85
FTRs | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, assets	$ 92,300,000	$ 68,600,000
Fair value, liabilities	3,300,000	9,300,000
FTRs | Level 3 | APPALACHIAN POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, assets	35,200,000	23,500,000
Fair value, liabilities	0	1,100,000
FTRs | Level 3 | INDIANA MICHIGAN POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, assets	6,900,000	4,500,000
Fair value, liabilities	500,000	1,700,000
FTRs | Level 3 | PUBLIC SERVICE COMPANY OF OKLAHOMA
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, assets	20,800,000	19,700,000
Fair value, liabilities	800,000	1,100,000
FTRs | Level 3 | SOUTHWESTERN ELECTRIC POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, assets	18,100,000	12,000,000
Fair value, liabilities	$ 600,000	$ 400,000
FTRs | Level 3 | Low | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range	(29.48)	(25.45)
Input/Range	(29.48)	(25.45)
FTRs | Level 3 | Low | APPALACHIAN POWER COMPANY | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range	(0.25)	(1.04)
Input/Range	(0.25)	(1.04)
FTRs | Level 3 | Low | INDIANA MICHIGAN POWER COMPANY | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range	(4.07)	(1.48)
Input/Range	(4.07)	(1.48)
FTRs | Level 3 | Low | PUBLIC SERVICE COMPANY OF OKLAHOMA | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range	(29.48)	(25.45)
Input/Range	(29.48)	(25.45)
FTRs | Level 3 | Low | SOUTHWESTERN ELECTRIC POWER COMPANY | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range	(29.48)	(25.45)
Input/Range	(29.48)	(25.45)
FTRs | Level 3 | High | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range	19.70	17.07
Input/Range	19.70	17.07
FTRs | Level 3 | High | APPALACHIAN POWER COMPANY | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range	9.32	6.45
Input/Range	9.32	6.45
FTRs | Level 3 | High | INDIANA MICHIGAN POWER COMPANY | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range	9.32	8.40
Input/Range	9.32	8.40
FTRs | Level 3 | High | PUBLIC SERVICE COMPANY OF OKLAHOMA | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range	10.54	4.80
Input/Range	10.54	4.80
FTRs | Level 3 | High | SOUTHWESTERN ELECTRIC POWER COMPANY | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range	10.54	4.80
Input/Range	10.54	4.80
FTRs | Level 3 | Weighted Average | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range	0.24	0
Input/Range	0.24	0
FTRs | Level 3 | Weighted Average | APPALACHIAN POWER COMPANY | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range	1.56	1.36
Input/Range	1.56	1.36
FTRs | Level 3 | Weighted Average | INDIANA MICHIGAN POWER COMPANY | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range	1.34	0.85
Input/Range	1.34	0.85
FTRs | Level 3 | Weighted Average | PUBLIC SERVICE COMPANY OF OKLAHOMA | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range	(3.88)	(4.33)
Input/Range	(3.88)	(4.33)
FTRs | Level 3 | Weighted Average | SOUTHWESTERN ELECTRIC POWER COMPANY | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range	(3.88)	(4.33)
Input/Range	(3.88)	(4.33)
Natural Gas (MMBtus) | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, assets		$ 0
Fair value, liabilities		500,000
Natural Gas (MMBtus) | Level 3 | SOUTHWESTERN ELECTRIC POWER COMPANY
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value, assets		0
Fair value, liabilities		$ 500,000
Natural Gas (MMBtus) | Level 3 | Low | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range		3.11
Input/Range		3.11
Natural Gas (MMBtus) | Level 3 | Low | SOUTHWESTERN ELECTRIC POWER COMPANY | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range		3.11
Input/Range		3.11
Natural Gas (MMBtus) | Level 3 | High | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range		3.11
Input/Range		3.11
Natural Gas (MMBtus) | Level 3 | High | SOUTHWESTERN ELECTRIC POWER COMPANY | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range		3.11
Input/Range		3.11
Natural Gas (MMBtus) | Level 3 | Weighted Average | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range		3.11
Input/Range		3.11
Natural Gas (MMBtus) | Level 3 | Weighted Average | SOUTHWESTERN ELECTRIC POWER COMPANY | Forward Market Price
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Input/Range		3.11
Input/Range		3.11

INCOME TAXES - Income Tax Expen

INCOME TAXES - Income Tax Expense (Benefit) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Federal:
Current	$ (2.8)	$ (116.7)	$ 113.1
Deferred	(57.9)	115.9	(88.8)
Total Federal	(60.7)	(0.8)	24.3
State and Local:
Current	(5.2)	69	26.6
Deferred	26.7	(13.6)	(45.5)
Total State and Local	21.5	55.4	(18.9)
Income Tax Expense (Benefit)	(39.2)	54.6	5.4
AEP TEXAS INC.
Federal:
Current	22.1	19.8	29
Deferred	77.1	63.5	41.4
Total Federal	99.2	83.3	70.4
State and Local:
Current	2.9	2.7	2.2
Deferred	0	(0.1)	0
Total State and Local	2.9	2.6	2.2
Income Tax Expense (Benefit)	102.1	85.9	72.6
AEP TRANSMISSION COMPANY, LLC
Federal:
Current	75.1	93.9	98
Deferred	89.1	52.3	46
Total Federal	164.2	146.2	144
State and Local:
Current	5.6	9.1	8.8
Deferred	20.5	(8.2)	16.3
Total State and Local	26.1	0.9	25.1
Income Tax Expense (Benefit)	190.3	147.1	169.1
APPALACHIAN POWER COMPANY
Federal:
Current	79.9	62.2	(61)
Deferred	(17.8)	(60.5)	86.6
Total Federal	62.1	1.7	25.6
State and Local:
Current	12.6	6.3	(0.4)
Deferred	0.4	6.2	(7)
Total State and Local	13	12.5	(7.4)
Income Tax Expense (Benefit)	75.1	14.2	18.2
INDIANA MICHIGAN POWER COMPANY
Federal:
Current	16.6	93.2	43.4
Deferred	(118.8)	(56.9)	(51.3)
Total Federal	(102.2)	36.3	(7.9)
State and Local:
Current	7	21.1	10.9
Deferred	0	1.2	1.2
Total State and Local	7	22.3	12.1
Income Tax Expense (Benefit)	(95.2)	58.6	4.2
OHIO POWER COMPANY
Federal:
Current	41.5	46.6	(27)
Deferred	(2.7)	2.8	73.3
Total Federal	38.8	49.4	46.3
State and Local:
Current	3.1	(0.3)	(0.3)
Deferred	10.5	5.2	(1.8)
Total State and Local	13.6	4.9	(2.1)
Income Tax Expense (Benefit)	52.4	54.3	44.2
PUBLIC SERVICE COMPANY OF OKLAHOMA
Federal:
Current	(119)	(60.8)	(3.3)
Deferred	20.1	2.9	(50.5)
Total Federal	(98.9)	(57.9)	(53.8)
State and Local:
Current	(0.2)	0.3	0
Deferred	(0.5)	4	4.6
Total State and Local	(0.7)	4.3	4.6
Income Tax Expense (Benefit)	(99.6)	(53.6)	(49.2)
SOUTHWESTERN ELECTRIC POWER COMPANY
Federal:
Current	(111.4)	(88.1)	(32.3)
Deferred	(86.1)	59.9	13.4
Total Federal	(197.5)	(28.2)	(18.9)
State and Local:
Current	1.8	1	(1.8)
Deferred	11.7	(6.1)	(4.5)
Total State and Local	13.5	(5.1)	(6.3)
Income Tax Expense (Benefit)	$ (184)	$ (33.3)	$ (25.2)

INCOME TAXES - Reconciliations

INCOME TAXES - Reconciliations to Federal Income Tax (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Effective Income Tax Rate Reconciliation [Line Items]
Net Income	$ 2,975.8	$ 2,212.6	$ 2,305.6
Less: Equity Earnings	(93.7)	(58.5)	109.4
Income Tax Expense (Benefit)	(39.2)	54.6	5.4
Pretax Income	2,935.2	2,265.8	2,309.6
Income Taxes on Pretax Income at Statutory Rate (21%)	$ 616.5	$ 475.8	$ 485
Statutory rate	21%	21%	21%
Increase (Decrease) in Income Taxes Resulting from the Following Items:
Reversal of Origination Flow-Through	$ 20.5	$ 26	$ 17.1
Investment Tax Credit Amortization	(58.4)	(50.3)	(14.3)
Production Tax Credits	(214.2)	(175.2)	(197.1)
State and Local Income Taxes, Net	16.7	43.7	(14)
Removal Costs	(14.6)	(22)	(26.5)
AFUDC Equity	(46.5)	(39.8)	(29.3)
Tax Reform Excess ADIT Reversal	(91.6)	(151.1)	(214.5)
Remeasurement of Excess ADIT	(262.2)	(46)
Federal Return to Provision		0	(17.4)
Disallowance Cost		0
Other	(5.4)	(6.5)	16.4
Income Tax Expense (Benefit)	$ (39.2)	$ 54.6	$ 5.4
Effective Income Tax Rate	(1.30%)	2.40%	0.20%
Dolet Hills Lignite Co, LLC
Effective Income Tax Rate Reconciliation [Line Items]
Less: Equity Earnings	$ (1.4)	$ (1.4)	$ (1.4)
AEP TEXAS INC.
Effective Income Tax Rate Reconciliation [Line Items]
Net Income	420.1	370.4	307.9
Income Tax Expense (Benefit)	102.1	85.9	72.6
Pretax Income	522.2	456.3	380.5
Income Taxes on Pretax Income at Statutory Rate (21%)	109.7	95.8	79.9
Increase (Decrease) in Income Taxes Resulting from the Following Items:
Reversal of Origination Flow-Through	0.8	0.6	0
Investment Tax Credit Amortization	(0.9)	(0.7)	0
Production Tax Credits	0	0	0
State and Local Income Taxes, Net	2.3	2.1	1.7
Removal Costs	0	0	0
AFUDC Equity	(9.6)	(6)	(4.1)
Tax Reform Excess ADIT Reversal	(5.1)	(6)	(5.5)
Remeasurement of Excess ADIT	6.4	0
Federal Return to Provision		(0.1)	0
Disallowance Cost		0
Other	(1.5)	0.2	0.6
Income Tax Expense (Benefit)	$ 102.1	$ 85.9	$ 72.6
Effective Income Tax Rate	19.60%	18.80%	19.10%
AEP TEXAS INC. | Investment funds
Effective Income Tax Rate Reconciliation [Line Items]
Less: Equity Earnings	$ 0	$ 0	$ 0
AEP TRANSMISSION COMPANY, LLC
Effective Income Tax Rate Reconciliation [Line Items]
Net Income	688.4	614.2	594.2
Income Tax Expense (Benefit)	190.3	147.1	169.1
Pretax Income	878.7	761.3	763.3
Income Taxes on Pretax Income at Statutory Rate (21%)	184.5	159.9	160.3
Increase (Decrease) in Income Taxes Resulting from the Following Items:
Reversal of Origination Flow-Through	2.7	2.4	0
Investment Tax Credit Amortization	0	0	0
Production Tax Credits	0	0	0
State and Local Income Taxes, Net	20.5	0.7	19.8
Removal Costs	0	0	0
AFUDC Equity	(18.8)	(17.5)	(14.8)
Tax Reform Excess ADIT Reversal	1.6	1.7	0
Remeasurement of Excess ADIT	0	0
Federal Return to Provision		0	0
Disallowance Cost		0
Other	(0.2)	(0.1)	3.8
Income Tax Expense (Benefit)	$ 190.3	$ 147.1	$ 169.1
Effective Income Tax Rate	21.70%	19.30%	22.20%
AEP TRANSMISSION COMPANY, LLC | Investment funds
Effective Income Tax Rate Reconciliation [Line Items]
Less: Equity Earnings	$ 0	$ 0	$ 0
APPALACHIAN POWER COMPANY
Effective Income Tax Rate Reconciliation [Line Items]
Net Income	421.7	294.4	394.2
Income Tax Expense (Benefit)	75.1	14.2	18.2
Pretax Income	496.8	308.6	412.4
Income Taxes on Pretax Income at Statutory Rate (21%)	104.3	64.8	86.6
Increase (Decrease) in Income Taxes Resulting from the Following Items:
Reversal of Origination Flow-Through	6.6	9.9	4.7
Investment Tax Credit Amortization	0.1	0	0
Production Tax Credits	(0.3)	(0.1)	0
State and Local Income Taxes, Net	10.3	9.9	(5.9)
Removal Costs	(11.2)	(5.1)	(9.8)
AFUDC Equity	(5.3)	(5.5)	(3.7)
Tax Reform Excess ADIT Reversal	(30.1)	(17.3)	(50.9)
Remeasurement of Excess ADIT	0	(46)
Federal Return to Provision		3.4	(2.8)
Disallowance Cost		0
Other	0.7	0.2	0
Income Tax Expense (Benefit)	$ 75.1	$ 14.2	$ 18.2
Effective Income Tax Rate	15.10%	4.60%	4.40%
APPALACHIAN POWER COMPANY | Investment funds
Effective Income Tax Rate Reconciliation [Line Items]
Less: Equity Earnings	$ 0	$ 0	$ 0
INDIANA MICHIGAN POWER COMPANY
Effective Income Tax Rate Reconciliation [Line Items]
Net Income	391.4	335.9	324.7
Income Tax Expense (Benefit)	(95.2)	58.6	4.2
Pretax Income	296.2	394.5	328.9
Income Taxes on Pretax Income at Statutory Rate (21%)	62.2	82.8	69.1
Increase (Decrease) in Income Taxes Resulting from the Following Items:
Reversal of Origination Flow-Through	4	6.4	2.9
Investment Tax Credit Amortization	(2)	(1.6)	(3.1)
Production Tax Credits	(69)	0	0
State and Local Income Taxes, Net	5.5	17.5	9.6
Removal Costs	(3.7)	(11.8)	(12.4)
AFUDC Equity	(2.8)	(2.3)	(2.1)
Tax Reform Excess ADIT Reversal	(15.5)	(30)	(54)
Remeasurement of Excess ADIT	(73.3)	0
Federal Return to Provision		(2.5)	(6.2)
Disallowance Cost		0
Other	(0.6)	0.1	0.4
Income Tax Expense (Benefit)	$ (95.2)	$ 58.6	$ 4.2
Effective Income Tax Rate	(32.10%)	14.90%	1.30%
INDIANA MICHIGAN POWER COMPANY | Investment funds
Effective Income Tax Rate Reconciliation [Line Items]
Less: Equity Earnings	$ 0	$ 0	$ 0
OHIO POWER COMPANY
Effective Income Tax Rate Reconciliation [Line Items]
Net Income	305.6	328.2	287.8
Less: Equity Earnings	1.1	0	(0.6)
Income Tax Expense (Benefit)	52.4	54.3	44.2
Pretax Income	358	382.5	331.4
Income Taxes on Pretax Income at Statutory Rate (21%)	75.2	80.3	69.6
Increase (Decrease) in Income Taxes Resulting from the Following Items:
Reversal of Origination Flow-Through	2.7	2.6	3
Investment Tax Credit Amortization	0.1	0	0
Production Tax Credits	0	0	0
State and Local Income Taxes, Net	10.7	3.9	(1.6)
Removal Costs	0	0	0
AFUDC Equity	(4.9)	(3.6)	(2.9)
Tax Reform Excess ADIT Reversal	(31.1)	(28.9)	(27.5)
Remeasurement of Excess ADIT	0	0
Federal Return to Provision		(0.4)	3.5
Disallowance Cost		0
Other	(0.3)	0.4	0.1
Income Tax Expense (Benefit)	$ 52.4	$ 54.3	$ 44.2
Effective Income Tax Rate	14.60%	14.20%	13.30%
OHIO POWER COMPANY | Investment funds
Effective Income Tax Rate Reconciliation [Line Items]
Less: Equity Earnings	$ 0	$ 0	$ (0.6)
PUBLIC SERVICE COMPANY OF OKLAHOMA
Effective Income Tax Rate Reconciliation [Line Items]
Net Income	249.3	208.8	167.6
Income Tax Expense (Benefit)	(99.6)	(53.6)	(49.2)
Pretax Income	149.7	155.2	118.4
Income Taxes on Pretax Income at Statutory Rate (21%)	31.4	32.6	24.9
Increase (Decrease) in Income Taxes Resulting from the Following Items:
Reversal of Origination Flow-Through	0.4	0.4	0
Investment Tax Credit Amortization	(1.4)	(1.4)	(1.6)
Production Tax Credits	(73.8)	(64.3)	(47.7)
State and Local Income Taxes, Net	(0.6)	3.5	4.3
Removal Costs	0	0	0
AFUDC Equity	(1.6)	(1.8)	0
Tax Reform Excess ADIT Reversal	(5.5)	(23.3)	(25.4)
Remeasurement of Excess ADIT	(48.6)	0
Federal Return to Provision		0.6	(3.7)
Disallowance Cost		0
Other	0.1	0.1	0
Income Tax Expense (Benefit)	$ (99.6)	$ (53.6)	$ (49.2)
Effective Income Tax Rate	(66.50%)	(34.50%)	(41.60%)
PUBLIC SERVICE COMPANY OF OKLAHOMA | Investment funds
Effective Income Tax Rate Reconciliation [Line Items]
Less: Equity Earnings	$ 0	$ 0	$ 0
SOUTHWESTERN ELECTRIC POWER COMPANY
Effective Income Tax Rate Reconciliation [Line Items]
Net Income	325.7	223.8	294.3
Less: Equity Earnings	(1.4)	(1.4)	(1.4)
Income Tax Expense (Benefit)	(184)	(33.3)	(25.2)
Pretax Income	140.3	189.1	267.7
Income Taxes on Pretax Income at Statutory Rate (21%)	29.5	39.7	56.2
Increase (Decrease) in Income Taxes Resulting from the Following Items:
Reversal of Origination Flow-Through	2.1	2.1	2.3
Investment Tax Credit Amortization	(0.1)	(0.2)	0
Production Tax Credits	(70.7)	(67.1)	(57.1)
State and Local Income Taxes, Net	10.6	(4)	(4.9)
Removal Costs	0	0	0
AFUDC Equity	(2.8)	(2.4)	0
Tax Reform Excess ADIT Reversal	(4)	(12.6)	(14.8)
Remeasurement of Excess ADIT	(146.8)	0
Federal Return to Provision		1	0
Disallowance Cost		12
Other	(1.8)	(1.8)	(6.9)
Income Tax Expense (Benefit)	$ (184)	$ (33.3)	$ (25.2)
Effective Income Tax Rate	(131.10%)	(17.60%)	(9.40%)
SOUTHWESTERN ELECTRIC POWER COMPANY | Dolet Hills Lignite Co, LLC
Effective Income Tax Rate Reconciliation [Line Items]
Less: Equity Earnings	$ (1.4)	$ (1.4)	$ (1.4)

INCOME TAXES - Deferred Tax Ass

INCOME TAXES - Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Effective Income Tax Rate Reconciliation [Line Items]
Deferred Tax Assets	$ 2,651.9	$ 3,216.1
Deferred Tax Liabilities	(12,624.3)	(12,631.8)
Net Deferred Tax Liabilities	(9,972.4)	(9,415.7)
Property Related Temporary Differences	(8,939.7)	(8,809)
Amounts Due to Customers for Future Income Taxes	779.6	898.1
Securitized Assets	(133.4)	(81.8)
Regulatory Assets	(966.2)	(825.9)
Accrued Nuclear Decommissioning	(1,052.2)	(923.5)
Net Operating Loss Carryforward	110.3	155.6
Valuation Allowance	(35)	(37.4)
Tax Credit Carryforward	197.5	321.4
Operating Lease Liability	145.3	154.7
Investment in Partnership	(302.1)	(296.3)
Net Deferred Tax Liabilities	223.5	28.4
AEP TEXAS INC.
Effective Income Tax Rate Reconciliation [Line Items]
Deferred Tax Assets	139.1	173.6
Deferred Tax Liabilities	(1,461.8)	(1,401.4)
Net Deferred Tax Liabilities	(1,322.7)	(1,227.8)
Property Related Temporary Differences	(1,364)	(1,274)
Amounts Due to Customers for Future Income Taxes	109.3	109.3
Securitized Assets	(26.5)	(46.7)
Regulatory Assets	(63.2)	(56.2)
Accrued Nuclear Decommissioning	0	0
Net Operating Loss Carryforward	0	0
Valuation Allowance	0	0
Tax Credit Carryforward	4.3	13.7
Operating Lease Liability	12.3	17.3
Investment in Partnership	0	0
Net Deferred Tax Liabilities	5.1	8.8
AEP TRANSMISSION COMPANY, LLC
Effective Income Tax Rate Reconciliation [Line Items]
Deferred Tax Assets	172.6	188
Deferred Tax Liabilities	(1,451.2)	(1,335.7)
Net Deferred Tax Liabilities	(1,278.6)	(1,147.7)
Property Related Temporary Differences	(1,416.6)	(1,304.2)
Amounts Due to Customers for Future Income Taxes	121.4	120.8
Securitized Assets	0	0
Regulatory Assets	(0.2)	(0.7)
Accrued Nuclear Decommissioning	0	0
Net Operating Loss Carryforward	2.5	3.9
Valuation Allowance	(0.1)	(0.1)
Tax Credit Carryforward	0	0
Operating Lease Liability	0.3	0.4
Investment in Partnership	0	0
Net Deferred Tax Liabilities	14.1	32.2
APPALACHIAN POWER COMPANY
Effective Income Tax Rate Reconciliation [Line Items]
Deferred Tax Assets	379.1	472.9
Deferred Tax Liabilities	(2,412.6)	(2,484.8)
Net Deferred Tax Liabilities	(2,033.5)	(2,011.9)
Property Related Temporary Differences	(1,784.8)	(1,805.9)
Amounts Due to Customers for Future Income Taxes	119	128
Securitized Assets	(25.7)	(32.6)
Regulatory Assets	(302.4)	(284.3)
Accrued Nuclear Decommissioning	0	0
Net Operating Loss Carryforward	0.4	0.2
Valuation Allowance	0	0
Tax Credit Carryforward	0.1	0.1
Operating Lease Liability	16.2	18
Investment in Partnership	(0.1)	(0.1)
Net Deferred Tax Liabilities	(56.2)	(35.3)
INDIANA MICHIGAN POWER COMPANY
Effective Income Tax Rate Reconciliation [Line Items]
Deferred Tax Assets	1,072.2	1,014
Deferred Tax Liabilities	(2,248)	(2,183.9)
Net Deferred Tax Liabilities	(1,175.8)	(1,169.9)
Property Related Temporary Differences	(189.9)	(315.6)
Amounts Due to Customers for Future Income Taxes	73.1	103.2
Securitized Assets	0	0
Regulatory Assets	(49.2)	(27.7)
Accrued Nuclear Decommissioning	(1,052.2)	(923.5)
Net Operating Loss Carryforward	0	0
Valuation Allowance	0	0
Tax Credit Carryforward	39.6	7.2
Operating Lease Liability	13.5	14.1
Investment in Partnership	0	0
Net Deferred Tax Liabilities	(10.7)	(27.6)
OHIO POWER COMPANY
Effective Income Tax Rate Reconciliation [Line Items]
Deferred Tax Assets	186.5	271.5
Deferred Tax Liabilities	(1,387.6)	(1,424.2)
Net Deferred Tax Liabilities	(1,201.1)	(1,152.7)
Property Related Temporary Differences	(1,290.9)	(1,243.2)
Amounts Due to Customers for Future Income Taxes	95.6	104.6
Securitized Assets	0	(5.3)
Regulatory Assets	(45.3)	(50.1)
Accrued Nuclear Decommissioning	0	0
Net Operating Loss Carryforward	2.9	2.6
Valuation Allowance	0	0
Tax Credit Carryforward	38.5	41
Operating Lease Liability	13.3	15.4
Investment in Partnership	(0.8)	(0.7)
Net Deferred Tax Liabilities	(14.4)	(17)
PUBLIC SERVICE COMPANY OF OKLAHOMA
Effective Income Tax Rate Reconciliation [Line Items]
Deferred Tax Assets	266.9	282.4
Deferred Tax Liabilities	(1,197.5)	(1,113.6)
Net Deferred Tax Liabilities	(930.6)	(831.2)
Property Related Temporary Differences	(1,009.8)	(941.9)
Amounts Due to Customers for Future Income Taxes	80.7	99
Securitized Assets	0	0
Regulatory Assets	(53.1)	(67.2)
Accrued Nuclear Decommissioning	0	0
Net Operating Loss Carryforward	27.8	25.3
Valuation Allowance	0	0
Tax Credit Carryforward	26.5	53.8
Operating Lease Liability	27.1	28.2
Investment in Partnership	0	0
Net Deferred Tax Liabilities	(29.8)	(28.4)
SOUTHWESTERN ELECTRIC POWER COMPANY
Effective Income Tax Rate Reconciliation [Line Items]
Deferred Tax Assets	292.8	441.5
Deferred Tax Liabilities	(1,564.1)	(1,620.8)
Net Deferred Tax Liabilities	(1,271.3)	(1,179.3)
Property Related Temporary Differences	(1,353.1)	(1,306)
Amounts Due to Customers for Future Income Taxes	90.2	142.5
Securitized Assets	(81.1)	2.8
Regulatory Assets	(87)	(146.9)
Accrued Nuclear Decommissioning	0	0
Net Operating Loss Carryforward	36.5	47.5
Valuation Allowance	0	(1.8)
Tax Credit Carryforward	31.7	68.6
Operating Lease Liability	35.7	33.3
Investment in Partnership	(1.5)	(1.5)
Net Deferred Tax Liabilities	$ 57.3	$ (17.8)

INCOME TAXES - Operating Loss C

INCOME TAXES - Operating Loss Carryforwards (Details) $ in Millions	Dec. 31, 2024 USD ($)
Effective Income Tax Rate Reconciliation [Line Items]
State net income tax operating loss carryforward	$ 110.3
OHIO POWER COMPANY
Effective Income Tax Rate Reconciliation [Line Items]
State net income tax operating loss carryforward	2.7
PUBLIC SERVICE COMPANY OF OKLAHOMA
Effective Income Tax Rate Reconciliation [Line Items]
State net income tax operating loss carryforward	27.8
SOUTHWESTERN ELECTRIC POWER COMPANY
Effective Income Tax Rate Reconciliation [Line Items]
State net income tax operating loss carryforward	36.1
Arkansas
Effective Income Tax Rate Reconciliation [Line Items]
State net income tax operating loss carryforward	273.9
Arkansas | SOUTHWESTERN ELECTRIC POWER COMPANY
Effective Income Tax Rate Reconciliation [Line Items]
State net income tax operating loss carryforward	273.5
Colorado
Effective Income Tax Rate Reconciliation [Line Items]
State net income tax operating loss carryforward	70.5
Illinois
Effective Income Tax Rate Reconciliation [Line Items]
State net income tax operating loss carryforward	53.9
Kentucky
Effective Income Tax Rate Reconciliation [Line Items]
State net income tax operating loss carryforward	186.7
Louisiana
Effective Income Tax Rate Reconciliation [Line Items]
State net income tax operating loss carryforward	644.8
Louisiana | SOUTHWESTERN ELECTRIC POWER COMPANY
Effective Income Tax Rate Reconciliation [Line Items]
State net income tax operating loss carryforward	634.5
Michigan
Effective Income Tax Rate Reconciliation [Line Items]
State net income tax operating loss carryforward	30.9
Ohio Municipal
Effective Income Tax Rate Reconciliation [Line Items]
State net income tax operating loss carryforward	2,155.8
Ohio Municipal | OHIO POWER COMPANY
Effective Income Tax Rate Reconciliation [Line Items]
State net income tax operating loss carryforward	93.7
Oklahoma
Effective Income Tax Rate Reconciliation [Line Items]
State net income tax operating loss carryforward	889.8
Oklahoma | PUBLIC SERVICE COMPANY OF OKLAHOMA
Effective Income Tax Rate Reconciliation [Line Items]
State net income tax operating loss carryforward	1,010
Pennsylvania
Effective Income Tax Rate Reconciliation [Line Items]
State net income tax operating loss carryforward	61.2
Tennessee
Effective Income Tax Rate Reconciliation [Line Items]
State net income tax operating loss carryforward	$ 46.1

INCOME TAXES - Tax Credit Carry

INCOME TAXES - Tax Credit Carryforwards (Details) $ in Millions	Dec. 31, 2024 USD ($)
Federal
Effective Income Tax Rate Reconciliation [Line Items]
Tax credit carryforward	$ 197.9
Federal | INDIANA MICHIGAN POWER COMPANY
Effective Income Tax Rate Reconciliation [Line Items]
Tax credit carryforward	37.5
Federal | PUBLIC SERVICE COMPANY OF OKLAHOMA
Effective Income Tax Rate Reconciliation [Line Items]
Tax credit carryforward	26.5
Federal | SOUTHWESTERN ELECTRIC POWER COMPANY
Effective Income Tax Rate Reconciliation [Line Items]
Tax credit carryforward	31.7
State and Local Government
Effective Income Tax Rate Reconciliation [Line Items]
Tax credit carryforward	40.2
State and Local Government | INDIANA MICHIGAN POWER COMPANY
Effective Income Tax Rate Reconciliation [Line Items]
Tax credit carryforward	0
State and Local Government | PUBLIC SERVICE COMPANY OF OKLAHOMA
Effective Income Tax Rate Reconciliation [Line Items]
Tax credit carryforward	40.2
State and Local Government | SOUTHWESTERN ELECTRIC POWER COMPANY
Effective Income Tax Rate Reconciliation [Line Items]
Tax credit carryforward	$ 0

INCOME TAXES - Narrative (Detai

INCOME TAXES - Narrative (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Income Tax Disclosure [Abstract]
Unrecognized tax benefits that would impact the effective tax rate	$ 19	$ 13	$ 23

LEASES - Lease Rental Costs (De

LEASES - Lease Rental Costs (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Lessee, Lease, Description [Line Items]
Operating Lease Cost	$ 145.9	$ 149.9	$ 157.5
Finance Lease Cost:
Amortization of Right-of-Use Assets	63.7	69.1	205.5
Interest on Lease Liabilities	11.9	11.9	13.4
Total Lease Rental Costs	221.5	230.9	376.4
AEP TEXAS INC.
Lessee, Lease, Description [Line Items]
Operating Lease Cost	32.3	34	18.4
Finance Lease Cost:
Amortization of Right-of-Use Assets	7.5	7.4	6.8
Interest on Lease Liabilities	1.4	1.4	1.3
Total Lease Rental Costs	41.2	42.8	26.5
AEP TRANSMISSION COMPANY, LLC
Lessee, Lease, Description [Line Items]
Operating Lease Cost	1.3	1.3	1.1
Finance Lease Cost:
Amortization of Right-of-Use Assets	0	0	0
Interest on Lease Liabilities	0	0	0
Total Lease Rental Costs	1.3	1.3	1.1
APPALACHIAN POWER COMPANY
Lessee, Lease, Description [Line Items]
Operating Lease Cost	18.4	18.5	17.9
Finance Lease Cost:
Amortization of Right-of-Use Assets	8.7	8.3	7.9
Interest on Lease Liabilities	1.5	1.8	2
Total Lease Rental Costs	28.6	28.6	27.8
INDIANA MICHIGAN POWER COMPANY
Lessee, Lease, Description [Line Items]
Operating Lease Cost	19.6	19.6	29.5
Finance Lease Cost:
Amortization of Right-of-Use Assets	7.2	7.3	78.7
Interest on Lease Liabilities	2.2	2.5	3.1
Total Lease Rental Costs	29	29.4	111.3
OHIO POWER COMPANY
Lessee, Lease, Description [Line Items]
Operating Lease Cost	16.8	17.3	16.9
Finance Lease Cost:
Amortization of Right-of-Use Assets	5.3	5	4.9
Interest on Lease Liabilities	0.9	0.9	0.8
Total Lease Rental Costs	23	23.2	22.6
PUBLIC SERVICE COMPANY OF OKLAHOMA
Lessee, Lease, Description [Line Items]
Operating Lease Cost	13.5	13.5	11.8
Finance Lease Cost:
Amortization of Right-of-Use Assets	3.3	3.3	3.2
Interest on Lease Liabilities	0.7	0.7	0.6
Total Lease Rental Costs	17.5	17.5	15.6
SOUTHWESTERN ELECTRIC POWER COMPANY
Lessee, Lease, Description [Line Items]
Operating Lease Cost	17.8	17.5	15.3
Finance Lease Cost:
Amortization of Right-of-Use Assets	13	19.9	10.8
Interest on Lease Liabilities	1.6	1.4	2.1
Total Lease Rental Costs	$ 32.4	$ 38.8	$ 28.2

LEASES - Supplemental Lease Inf

LEASES - Supplemental Lease Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Weighted-Average Remaining Lease Term (years):
Operating Leases	12 years 9 months 18 days	12 years 6 months 29 days
Finance Leases	4 years 9 months 21 days	4 years 7 months 17 days
Weighted-Average Discount Rate:
Operating Leases	3.89%	3.73%
Finance Leases	6.43%	6.19%
Cash paid for amounts included in the measurement of lease liabilities:
Operating Cash Flows Used for Operating Leases	$ 143.9	$ 146.8
Operating Cash Flows Used for Finance Leases	12	11.9
Financing Cash Flows Used for Finance Leases	64.8	68.3	$ 309.5
Non-cash Acquisitions Under Operating Leases	$ 82.3	$ 99.8
AEP TEXAS INC.
Weighted-Average Remaining Lease Term (years):
Operating Leases	4 years 5 months 12 days	3 years 11 months 26 days
Finance Leases	5 years 14 days	5 years 1 month 17 days
Weighted-Average Discount Rate:
Operating Leases	4.29%	4.23%
Finance Leases	5.73%	5.27%
Cash paid for amounts included in the measurement of lease liabilities:
Operating Cash Flows Used for Operating Leases	$ 32.2	$ 33.6
Operating Cash Flows Used for Finance Leases	1.4	1.4
Financing Cash Flows Used for Finance Leases	7.5	7.4	6.8
Non-cash Acquisitions Under Operating Leases	$ 6	$ 12.4
AEP TRANSMISSION COMPANY, LLC
Weighted-Average Remaining Lease Term (years):
Operating Leases	2 years 3 months 14 days	2 years 9 months 3 days
Finance Leases	0 years	0 years
Weighted-Average Discount Rate:
Operating Leases	4.55%	3.61%
Finance Leases	0%	0%
Cash paid for amounts included in the measurement of lease liabilities:
Operating Cash Flows Used for Operating Leases	$ 1.3	$ 1.3
Operating Cash Flows Used for Finance Leases	0	0
Financing Cash Flows Used for Finance Leases	0	0
Non-cash Acquisitions Under Operating Leases	$ 1	$ 1.2
APPALACHIAN POWER COMPANY
Weighted-Average Remaining Lease Term (years):
Operating Leases	5 years 4 months 20 days	6 years 3 days
Finance Leases	4 years 1 month 2 days	4 years 1 month 28 days
Weighted-Average Discount Rate:
Operating Leases	4.20%	3.50%
Finance Leases	6.69%	7.04%
Cash paid for amounts included in the measurement of lease liabilities:
Operating Cash Flows Used for Operating Leases	$ 18.4	$ 18.3
Operating Cash Flows Used for Finance Leases	1.5	1.8
Financing Cash Flows Used for Finance Leases	8.7	8.3	7.9
Non-cash Acquisitions Under Operating Leases	$ 9.3	$ 15.7
INDIANA MICHIGAN POWER COMPANY
Weighted-Average Remaining Lease Term (years):
Operating Leases	4 years 5 months 4 days	4 years 6 months 10 days
Finance Leases	4 years 9 months 29 days	4 years 11 months 12 days
Weighted-Average Discount Rate:
Operating Leases	4.11%	3.89%
Finance Leases	9.07%	8.62%
Cash paid for amounts included in the measurement of lease liabilities:
Operating Cash Flows Used for Operating Leases	$ 19.6	$ 19.5
Operating Cash Flows Used for Finance Leases	2.2	2.5
Financing Cash Flows Used for Finance Leases	7.1	7.4	130.7
Non-cash Acquisitions Under Operating Leases	$ 15	$ 7.9
OHIO POWER COMPANY
Weighted-Average Remaining Lease Term (years):
Operating Leases	4 years 7 months 20 days	5 years 4 months 9 days
Finance Leases	4 years 6 months 29 days	4 years 11 months 19 days
Weighted-Average Discount Rate:
Operating Leases	4.17%	3.93%
Finance Leases	5.59%	5.32%
Cash paid for amounts included in the measurement of lease liabilities:
Operating Cash Flows Used for Operating Leases	$ 16.8	$ 17
Operating Cash Flows Used for Finance Leases	0.9	0.9
Financing Cash Flows Used for Finance Leases	5.3	5	4.9
Non-cash Acquisitions Under Operating Leases	$ 4.6	$ 10.2
PUBLIC SERVICE COMPANY OF OKLAHOMA
Weighted-Average Remaining Lease Term (years):
Operating Leases	23 years 8 months 4 days	23 years 10 months 6 days
Finance Leases	5 years 5 months 8 days	5 years 9 months 3 days
Weighted-Average Discount Rate:
Operating Leases	3.76%	3.72%
Finance Leases	5.48%	5.14%
Cash paid for amounts included in the measurement of lease liabilities:
Operating Cash Flows Used for Operating Leases	$ 12.5	$ 12.5
Operating Cash Flows Used for Finance Leases	0.7	0.7
Financing Cash Flows Used for Finance Leases	3.3	3.3	3.2
Non-cash Acquisitions Under Operating Leases	$ 2.5	$ 15.5
SOUTHWESTERN ELECTRIC POWER COMPANY
Weighted-Average Remaining Lease Term (years):
Operating Leases	21 years 11 months 19 days	22 years 6 months
Finance Leases	6 years 1 month 20 days	4 years 9 months 10 days
Weighted-Average Discount Rate:
Operating Leases	3.60%	3.53%
Finance Leases	5.73%	5.22%
Cash paid for amounts included in the measurement of lease liabilities:
Operating Cash Flows Used for Operating Leases	$ 16.8	$ 16.5
Operating Cash Flows Used for Finance Leases	1.7	1.4
Financing Cash Flows Used for Finance Leases	14	19.1	$ 10.8
Non-cash Acquisitions Under Operating Leases	$ 26.9	$ 14.3

LEASES - Balance Sheet Informat

LEASES - Balance Sheet Information (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Lessee, Lease, Description [Line Items]
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other Current Liabilities	Other Current Liabilities
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Other Liabilities, Noncurrent	Other Liabilities, Noncurrent
Finance Lease, Liability, Statement of Financial Position [Extensible Enumeration]	Other Current Liabilities, Other Liabilities, Noncurrent	Other Current Liabilities, Other Liabilities, Noncurrent
Net Property, Plant and Equipment Under Finance Leases	$ 163.6	$ 204.5
Obligations Under Finance Leases:
Noncurrent Liability	117.1	139.9
Liability Due Within One Year	46.5	65.7
Total Obligations Under Finance Leases	163.6	205.6
Operating Lease Assets	580.1	620.2
Obligations Under Operating Leases:
Obligations Under Operating Leases	504.3	519.4
Obligations Under Operating Leases	91.9	115.7
Total Obligations Under Operating Leases	$ 596.2	$ 635.1
AEP TEXAS INC.
Lessee, Lease, Description [Line Items]
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other Current Liabilities	Other Current Liabilities
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Other Liabilities, Noncurrent	Other Liabilities, Noncurrent
Finance Lease, Liability, Statement of Financial Position [Extensible Enumeration]	Other Current Liabilities, Other Liabilities, Noncurrent	Other Current Liabilities, Other Liabilities, Noncurrent
Net Property, Plant and Equipment Under Finance Leases	$ 24.7	$ 27.6
Obligations Under Finance Leases:
Noncurrent Liability	18.2	20.6
Liability Due Within One Year	6.5	7
Total Obligations Under Finance Leases	24.7	27.6
Operating Lease Assets	54.4	77.6
Obligations Under Operating Leases:
Obligations Under Operating Leases	43.4	50.9
Obligations Under Operating Leases	13.1	28.7
Total Obligations Under Operating Leases	$ 56.5	$ 79.6
AEP TRANSMISSION COMPANY, LLC
Lessee, Lease, Description [Line Items]
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other Current Liabilities	Other Current Liabilities
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Other Liabilities, Noncurrent	Other Liabilities, Noncurrent
Finance Lease, Liability, Statement of Financial Position [Extensible Enumeration]	Other Current Liabilities, Other Liabilities, Noncurrent	Other Current Liabilities, Other Liabilities, Noncurrent
Net Property, Plant and Equipment Under Finance Leases	$ 0	$ 0
Obligations Under Finance Leases:
Noncurrent Liability	0	0
Liability Due Within One Year	0	0
Total Obligations Under Finance Leases	0	0
Operating Lease Assets	2.3	2.6
Obligations Under Operating Leases:
Obligations Under Operating Leases	1.2	1.4
Obligations Under Operating Leases	1.3	1.3
Total Obligations Under Operating Leases	$ 2.5	$ 2.7
APPALACHIAN POWER COMPANY
Lessee, Lease, Description [Line Items]
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other Current Liabilities	Other Current Liabilities
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Other Liabilities, Noncurrent	Other Liabilities, Noncurrent
Finance Lease, Liability, Statement of Financial Position [Extensible Enumeration]	Other Current Liabilities, Other Liabilities, Noncurrent	Other Current Liabilities, Other Liabilities, Noncurrent
Net Property, Plant and Equipment Under Finance Leases	$ 19	$ 26
Obligations Under Finance Leases:
Noncurrent Liability	11.2	17.8
Liability Due Within One Year	7.8	8.2
Total Obligations Under Finance Leases	19	26
Operating Lease Assets	67	73.7
Obligations Under Operating Leases:
Obligations Under Operating Leases	54	59.8
Obligations Under Operating Leases	13.7	14.6
Total Obligations Under Operating Leases	$ 67.7	$ 74.4
INDIANA MICHIGAN POWER COMPANY
Lessee, Lease, Description [Line Items]
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other Current Liabilities	Other Current Liabilities
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Other Liabilities, Noncurrent	Other Liabilities, Noncurrent
Finance Lease, Liability, Statement of Financial Position [Extensible Enumeration]	Other Current Liabilities, Other Liabilities, Noncurrent	Other Current Liabilities, Other Liabilities, Noncurrent
Net Property, Plant and Equipment Under Finance Leases	$ 22	$ 31.5
Obligations Under Finance Leases:
Noncurrent Liability	15.9	20.8
Liability Due Within One Year	6.1	10.7
Total Obligations Under Finance Leases	22	31.5
Operating Lease Assets	51.5	53.8
Obligations Under Operating Leases:
Obligations Under Operating Leases	40.1	37.7
Obligations Under Operating Leases	12.3	16.8
Total Obligations Under Operating Leases	$ 52.4	$ 54.5
OHIO POWER COMPANY
Lessee, Lease, Description [Line Items]
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other Current Liabilities	Other Current Liabilities
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Other Liabilities, Noncurrent	Other Liabilities, Noncurrent
Finance Lease, Liability, Statement of Financial Position [Extensible Enumeration]	Other Current Liabilities, Other Liabilities, Noncurrent	Other Current Liabilities, Other Liabilities, Noncurrent
Net Property, Plant and Equipment Under Finance Leases	$ 14.3	$ 18.2
Obligations Under Finance Leases:
Noncurrent Liability	10.2	13.2
Liability Due Within One Year	4.1	5
Total Obligations Under Finance Leases	14.3	18.2
Operating Lease Assets	60.4	69.9
Obligations Under Operating Leases:
Obligations Under Operating Leases	48.4	56.7
Obligations Under Operating Leases	12.3	13.5
Total Obligations Under Operating Leases	$ 60.7	$ 70.2
PUBLIC SERVICE COMPANY OF OKLAHOMA
Lessee, Lease, Description [Line Items]
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other Current Liabilities	Other Current Liabilities
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Other Liabilities, Noncurrent	Other Liabilities, Noncurrent
Finance Lease, Liability, Statement of Financial Position [Extensible Enumeration]	Other Current Liabilities, Other Liabilities, Noncurrent	Other Current Liabilities, Other Liabilities, Noncurrent
Net Property, Plant and Equipment Under Finance Leases	$ 12.3	$ 13.8
Obligations Under Finance Leases:
Noncurrent Liability	9.5	10.7
Liability Due Within One Year	2.8	3.1
Total Obligations Under Finance Leases	12.3	13.8
Operating Lease Assets	106.2	112.8
Obligations Under Operating Leases:
Obligations Under Operating Leases	101.9	106.8
Obligations Under Operating Leases	10.4	10.1
Total Obligations Under Operating Leases	$ 112.3	$ 116.9
SOUTHWESTERN ELECTRIC POWER COMPANY
Lessee, Lease, Description [Line Items]
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other Current Liabilities	Other Current Liabilities
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Other Liabilities, Noncurrent	Other Liabilities, Noncurrent
Finance Lease, Liability, Statement of Financial Position [Extensible Enumeration]	Other Current Liabilities, Other Liabilities, Noncurrent	Other Current Liabilities, Other Liabilities, Noncurrent
Net Property, Plant and Equipment Under Finance Leases	$ 18.5	$ 29
Obligations Under Finance Leases:
Noncurrent Liability	14.8	18.8
Liability Due Within One Year	3.7	11.3
Total Obligations Under Finance Leases	18.5	30.1
Operating Lease Assets	141	126.3
Obligations Under Operating Leases:
Obligations Under Operating Leases	137.5	122.5
Obligations Under Operating Leases	8.2	9
Total Obligations Under Operating Leases	145.7	131.5
Generation
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	73.8	120.1
Generation | AEP TEXAS INC.
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	0	0
Generation | AEP TRANSMISSION COMPANY, LLC
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	0	0
Generation | APPALACHIAN POWER COMPANY
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	41.6	41
Generation | INDIANA MICHIGAN POWER COMPANY
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	16.6	28.2
Generation | OHIO POWER COMPANY
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	0	0
Generation | PUBLIC SERVICE COMPANY OF OKLAHOMA
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	0.6	0.6
Generation | SOUTHWESTERN ELECTRIC POWER COMPANY
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	2	25.3
Other Property, Plant and Equipment
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	283.7	305.9
Other Property, Plant and Equipment | AEP TEXAS INC.
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	52.4	53.9
Other Property, Plant and Equipment | AEP TRANSMISSION COMPANY, LLC
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	0	0
Other Property, Plant and Equipment | APPALACHIAN POWER COMPANY
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	19.4	22.1
Other Property, Plant and Equipment | INDIANA MICHIGAN POWER COMPANY
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	38.8	42.3
Other Property, Plant and Equipment | OHIO POWER COMPANY
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	30.4	33.7
Other Property, Plant and Equipment | PUBLIC SERVICE COMPANY OF OKLAHOMA
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	23	25.5
Other Property, Plant and Equipment | SOUTHWESTERN ELECTRIC POWER COMPANY
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	29.8	32
Total Property, Plant and Equipment
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	357.5	426
Total Property, Plant and Equipment | AEP TEXAS INC.
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	52.4	53.9
Total Property, Plant and Equipment | AEP TRANSMISSION COMPANY, LLC
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	0	0
Total Property, Plant and Equipment | APPALACHIAN POWER COMPANY
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	61	63.1
Total Property, Plant and Equipment | INDIANA MICHIGAN POWER COMPANY
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	55.4	70.5
Total Property, Plant and Equipment | OHIO POWER COMPANY
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	30.4	33.7
Total Property, Plant and Equipment | PUBLIC SERVICE COMPANY OF OKLAHOMA
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	23.6	26.1
Total Property, Plant and Equipment | SOUTHWESTERN ELECTRIC POWER COMPANY
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	31.8	57.3
Accumulated Amortization
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	193.9	221.5
Accumulated Amortization | AEP TEXAS INC.
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	27.7	26.3
Accumulated Amortization | AEP TRANSMISSION COMPANY, LLC
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	0	0
Accumulated Amortization | APPALACHIAN POWER COMPANY
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	42	37.1
Accumulated Amortization | INDIANA MICHIGAN POWER COMPANY
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	33.4	39
Accumulated Amortization | OHIO POWER COMPANY
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	16.1	15.5
Accumulated Amortization | PUBLIC SERVICE COMPANY OF OKLAHOMA
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	11.3	12.3
Accumulated Amortization | SOUTHWESTERN ELECTRIC POWER COMPANY
Lessee, Lease, Description [Line Items]
Net Property, Plant and Equipment Under Finance Leases	$ 13.3	$ 28.3

LEASES - Future Minimum Lease P

LEASES - Future Minimum Lease Payments (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Finance Leases
2025	$ 55.6
2026	39.8
2027	30.5
2028	23.1
2029	15.5
After 2029	26.4
Total Future Minimum Lease Payments	190.9
Less: Imputed Interest	27.3
Estimated Present Value of Future Minimum Lease Payments	163.6	$ 205.6
Operating Leases
2025	123
2026	107.8
2027	94
2028	78.5
2029	52.3
After 2029	340
Total Future Minimum Lease Payments	795.6
Less: Imputed Interest	199.4
Estimated Present Value of Future Minimum Lease Payments	596.2	635.1
AEP TEXAS INC.
Finance Leases
2025	7.8
2026	6.2
2027	4.5
2028	3.1
2029	2.4
After 2029	4.7
Total Future Minimum Lease Payments	28.7
Less: Imputed Interest	4
Estimated Present Value of Future Minimum Lease Payments	24.7	27.6
Operating Leases
2025	16.7
2026	14.5
2027	11.9
2028	8.9
2029	4.9
After 2029	6.5
Total Future Minimum Lease Payments	63.4
Less: Imputed Interest	6.9
Estimated Present Value of Future Minimum Lease Payments	56.5	79.6
AEP TRANSMISSION COMPANY, LLC
Finance Leases
2025	0
2026	0
2027	0
2028	0
2029	0
After 2029	0
Total Future Minimum Lease Payments	0
Less: Imputed Interest	0
Estimated Present Value of Future Minimum Lease Payments	0	0
Operating Leases
2025	1.3
2026	0.7
2027	0.3
2028	0.3
2029	0
After 2029	0
Total Future Minimum Lease Payments	2.6
Less: Imputed Interest	0.1
Estimated Present Value of Future Minimum Lease Payments	2.5	2.7
APPALACHIAN POWER COMPANY
Finance Leases
2025	8.9
2026	4
2027	2.5
2028	2
2029	1.6
After 2029	2.5
Total Future Minimum Lease Payments	21.5
Less: Imputed Interest	2.5
Estimated Present Value of Future Minimum Lease Payments	19	26
Operating Leases
2025	17.3
2026	15.3
2027	13.6
2028	11.4
2029	8.2
After 2029	10.2
Total Future Minimum Lease Payments	76
Less: Imputed Interest	8.3
Estimated Present Value of Future Minimum Lease Payments	67.7	74.4
INDIANA MICHIGAN POWER COMPANY
Finance Leases
2025	7.7
2026	4.9
2027	4.1
2028	3.4
2029	2.8
After 2029	4.7
Total Future Minimum Lease Payments	27.6
Less: Imputed Interest	5.6
Estimated Present Value of Future Minimum Lease Payments	22	31.5
Operating Leases
2025	15.9
2026	15
2027	11
2028	9
2029	4.4
After 2029	2.4
Total Future Minimum Lease Payments	57.7
Less: Imputed Interest	5.3
Estimated Present Value of Future Minimum Lease Payments	52.4	54.5
OHIO POWER COMPANY
Finance Leases
2025	4.8
2026	3.6
2027	2.6
2028	2
2029	1.4
After 2029	1.9
Total Future Minimum Lease Payments	16.3
Less: Imputed Interest	2
Estimated Present Value of Future Minimum Lease Payments	14.3	18.2
Operating Leases
2025	16.3
2026	15.1
2027	13.5
2028	11.3
2029	6.6
After 2029	4.9
Total Future Minimum Lease Payments	67.7
Less: Imputed Interest	7
Estimated Present Value of Future Minimum Lease Payments	60.7	70.2
PUBLIC SERVICE COMPANY OF OKLAHOMA
Finance Leases
2025	3.4
2026	2.9
2027	2.3
2028	1.8
2029	1.3
After 2029	2.6
Total Future Minimum Lease Payments	14.3
Less: Imputed Interest	2
Estimated Present Value of Future Minimum Lease Payments	12.3	13.8
Operating Leases
2025	11.6
2026	10.8
2027	9.8
2028	8.4
2029	6.5
After 2029	123.7
Total Future Minimum Lease Payments	170.8
Less: Imputed Interest	58.5
Estimated Present Value of Future Minimum Lease Payments	112.3	116.9
SOUTHWESTERN ELECTRIC POWER COMPANY
Finance Leases
2025	4.7
2026	4
2027	3.3
2028	2.7
2029	2.4
After 2029	5
Total Future Minimum Lease Payments	22.1
Less: Imputed Interest	3.6
Estimated Present Value of Future Minimum Lease Payments	18.5	30.1
Operating Leases
2025	17.6
2026	15.5
2027	14.1
2028	12.1
2029	9
After 2029	178.1
Total Future Minimum Lease Payments	246.4
Less: Imputed Interest	100.7
Estimated Present Value of Future Minimum Lease Payments	$ 145.7	$ 131.5

LEASES - Master Lease Agreement

LEASES - Master Lease Agreements (Details) $ in Millions	Dec. 31, 2024 USD ($)
Lessee, Lease, Description [Line Items]
Maximum Potential Loss	$ 41.3
AEP TEXAS INC.
Lessee, Lease, Description [Line Items]
Maximum Potential Loss	9.4
APPALACHIAN POWER COMPANY
Lessee, Lease, Description [Line Items]
Maximum Potential Loss	5.4
INDIANA MICHIGAN POWER COMPANY
Lessee, Lease, Description [Line Items]
Maximum Potential Loss	3.9
OHIO POWER COMPANY
Lessee, Lease, Description [Line Items]
Maximum Potential Loss	6.8
PUBLIC SERVICE COMPANY OF OKLAHOMA
Lessee, Lease, Description [Line Items]
Maximum Potential Loss	3.9
SOUTHWESTERN ELECTRIC POWER COMPANY
Lessee, Lease, Description [Line Items]
Maximum Potential Loss	$ 4.7

VOLUNTARY SEVERANCE PROGRAM - N

VOLUNTARY SEVERANCE PROGRAM - Narrative (Details) $ in Millions	1 Months Ended
	Nov. 30, 2024 USD ($)	Apr. 30, 2024 wk
Restructuring and Related Activities [Abstract]
Number of eligible employees		7,400
Total number of employees		16,800
Employees participating in voluntary severance program		1,000
Restructuring Cost and Reserve [Line Items]
Voluntary severance program, number of weeks of base pay, annual service benchmark		2
Settlement charge | $	$ 90
Minimum
Restructuring Cost and Reserve [Line Items]
Voluntary severance program, number of base pay, payout period		4
Maximum
Restructuring Cost and Reserve [Line Items]
Voluntary severance program, number of base pay, payout period		52

VOLUNTARY SEVERANCE PROGRAM - S

VOLUNTARY SEVERANCE PROGRAM - Summary From Program (Details) $ in Millions	9 Months Ended
	Dec. 31, 2024 USD ($)
Restructuring Cost and Reserve [Line Items]
Severance Expense Incurred	$ 122
Settled	117.6
Remaining Balance of Severance Costs	4.4
AEP TEXAS INC.
Restructuring Cost and Reserve [Line Items]
Severance Expense Incurred	19.8
Settled	19.8
Remaining Balance of Severance Costs	0
AEP TRANSMISSION COMPANY, LLC
Restructuring Cost and Reserve [Line Items]
Severance Expense Incurred	10.7
Settled	10.7
Remaining Balance of Severance Costs	0
APPALACHIAN POWER COMPANY
Restructuring Cost and Reserve [Line Items]
Severance Expense Incurred	26.5
Settled	26.3
Remaining Balance of Severance Costs	0.2
INDIANA MICHIGAN POWER COMPANY
Restructuring Cost and Reserve [Line Items]
Severance Expense Incurred	14.8
Settled	14.6
Remaining Balance of Severance Costs	0.2
OHIO POWER COMPANY
Restructuring Cost and Reserve [Line Items]
Severance Expense Incurred	14.8
Settled	14.6
Remaining Balance of Severance Costs	0.2
PUBLIC SERVICE COMPANY OF OKLAHOMA
Restructuring Cost and Reserve [Line Items]
Severance Expense Incurred	10.1
Settled	10.1
Remaining Balance of Severance Costs	0
SOUTHWESTERN ELECTRIC POWER COMPANY
Restructuring Cost and Reserve [Line Items]
Severance Expense Incurred	16.9
Settled	16.3
Remaining Balance of Severance Costs	$ 0.6

FINANCING ACTIVITIES - Reconcil

FINANCING ACTIVITIES - Reconciliation of Common Stock Share Activity (Details) - shares	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Issued
Beginning balance (in shares)	527,369,157	525,099,321	524,416,175
Issued (in shares)	6,725,373	2,269,836	683,146
Ending balance (in shares)	534,094,530	527,369,157	525,099,321
Held in Treasury
Beginning balance (in shares)	1,184,572	11,233,240	20,204,160
Treasury Stock Reissued (in shares)		(10,048,668)	(8,970,920)
Treasury Stock Reacquired (in shares)	2,243
Ending balance (in shares)	1,186,815	1,184,572	11,233,240

FINANCING ACTIVITIES - ATM Offe

FINANCING ACTIVITIES - ATM Offering Program Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Subsidiary or Equity Method Investee [Line Items]
Issued (in shares)	6,725,373	2,269,836	683,146
Proceeds from issuance of common stock	$ 552.1	$ 999.6	$ 826.5
ATM Offering Program
Subsidiary or Equity Method Investee [Line Items]
Maximum value of shares to be issued under ATM Program		$ 1,700
Maximum percentage paid to selling agents		2%
Issued (in shares)	4,437,136
Proceeds from issuance of common stock	$ 397
Common stock, capital shares reserved for future issuance (in shares)	1,300,000,000

FINANCING ACTIVITIES - Schedule

FINANCING ACTIVITIES - Schedule of Long-Term Debt Information (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Debt Instrument [Line Items]
Total Long-term Debt Outstanding	$ 42,642.8	$ 40,143.2
AEP TEXAS INC.
Debt Instrument [Line Items]
Total Long-term Debt Outstanding	6,441.6	5,889.8
AEP TRANSMISSION COMPANY, LLC
Debt Instrument [Line Items]
Total Long-term Debt Outstanding	5,768.1	5,414.4
APPALACHIAN POWER COMPANY
Debt Instrument [Line Items]
Total Long-term Debt Outstanding	5,660.3	5,588.3
INDIANA MICHIGAN POWER COMPANY
Debt Instrument [Line Items]
Total Long-term Debt Outstanding	3,494.3	3,499.4
OHIO POWER COMPANY
Debt Instrument [Line Items]
Total Long-term Debt Outstanding	3,715.7	3,366.8
PUBLIC SERVICE COMPANY OF OKLAHOMA
Debt Instrument [Line Items]
Total Long-term Debt Outstanding	2,855.6	2,384.6
SOUTHWESTERN ELECTRIC POWER COMPANY
Debt Instrument [Line Items]
Total Long-term Debt Outstanding	$ 3,980.8	3,646.9
Senior Unsecured Notes
Debt Instrument [Line Items]
Weighted Average Interest Rate	4.32%
Senior Unsecured Notes	$ 36,410.9	$ 33,779.4
Senior Unsecured Notes | Minimum
Debt Instrument [Line Items]
Interest Rate	1%	1%
Senior Unsecured Notes | Maximum
Debt Instrument [Line Items]
Interest Rate	8.13%	8.13%
Senior Unsecured Notes | AEP TEXAS INC.
Debt Instrument [Line Items]
Weighted Average Interest Rate	4.39%
Senior Unsecured Notes	$ 5,873.8	$ 5,027.2
Senior Unsecured Notes | AEP TEXAS INC. | Minimum
Debt Instrument [Line Items]
Interest Rate	2.10%	2.10%
Senior Unsecured Notes | AEP TEXAS INC. | Maximum
Debt Instrument [Line Items]
Interest Rate	6.76%	6.76%
Senior Unsecured Notes | AEP TRANSMISSION COMPANY, LLC
Debt Instrument [Line Items]
Weighted Average Interest Rate	4.12%
Senior Unsecured Notes	$ 5,768.1	$ 5,414.4
Senior Unsecured Notes | AEP TRANSMISSION COMPANY, LLC | Minimum
Debt Instrument [Line Items]
Interest Rate	2.75%	2.75%
Senior Unsecured Notes | AEP TRANSMISSION COMPANY, LLC | Maximum
Debt Instrument [Line Items]
Interest Rate	5.52%	5.52%
Senior Unsecured Notes | APPALACHIAN POWER COMPANY
Debt Instrument [Line Items]
Weighted Average Interest Rate	4.75%
Senior Unsecured Notes	$ 4,984.1	$ 4,584.9
Senior Unsecured Notes | APPALACHIAN POWER COMPANY | Minimum
Debt Instrument [Line Items]
Interest Rate	2.70%	2.70%
Senior Unsecured Notes | APPALACHIAN POWER COMPANY | Maximum
Debt Instrument [Line Items]
Interest Rate	7%	7%
Senior Unsecured Notes | INDIANA MICHIGAN POWER COMPANY
Debt Instrument [Line Items]
Weighted Average Interest Rate	4.52%
Senior Unsecured Notes	$ 2,845.2	$ 2,843.6
Senior Unsecured Notes | INDIANA MICHIGAN POWER COMPANY | Minimum
Debt Instrument [Line Items]
Interest Rate	3.25%	3.25%
Senior Unsecured Notes | INDIANA MICHIGAN POWER COMPANY | Maximum
Debt Instrument [Line Items]
Interest Rate	6.05%	6.05%
Senior Unsecured Notes | OHIO POWER COMPANY
Debt Instrument [Line Items]
Weighted Average Interest Rate	4.16%
Senior Unsecured Notes	$ 3,715.7	$ 3,366.8
Senior Unsecured Notes | OHIO POWER COMPANY | Minimum
Debt Instrument [Line Items]
Interest Rate	1.63%	1.63%
Senior Unsecured Notes | OHIO POWER COMPANY | Maximum
Debt Instrument [Line Items]
Interest Rate	6.60%	6.60%
Senior Unsecured Notes | PUBLIC SERVICE COMPANY OF OKLAHOMA
Debt Instrument [Line Items]
Weighted Average Interest Rate	4.29%
Senior Unsecured Notes	$ 2,854.2	$ 2,257.8
Senior Unsecured Notes | PUBLIC SERVICE COMPANY OF OKLAHOMA | Minimum
Debt Instrument [Line Items]
Interest Rate	2.20%	2.20%
Senior Unsecured Notes | PUBLIC SERVICE COMPANY OF OKLAHOMA | Maximum
Debt Instrument [Line Items]
Interest Rate	6.63%	6.63%
Senior Unsecured Notes | SOUTHWESTERN ELECTRIC POWER COMPANY
Debt Instrument [Line Items]
Weighted Average Interest Rate	3.73%
Senior Unsecured Notes	$ 3,649.4	$ 3,646.9
Senior Unsecured Notes | SOUTHWESTERN ELECTRIC POWER COMPANY | Minimum
Debt Instrument [Line Items]
Interest Rate	1.65%	1.65%
Senior Unsecured Notes | SOUTHWESTERN ELECTRIC POWER COMPANY | Maximum
Debt Instrument [Line Items]
Interest Rate	6.20%	6.20%
Pollution Control Bonds
Debt Instrument [Line Items]
Weighted Average Interest Rate	3.26%
Pollution Control Bonds	$ 1,771.3	$ 1,771.6
Pollution Control Bonds | Minimum
Debt Instrument [Line Items]
Interest Rate	0.63%	0.63%
Pollution Control Bonds | Maximum
Debt Instrument [Line Items]
Interest Rate	4.70%	4.90%
Pollution Control Bonds | AEP TEXAS INC.
Debt Instrument [Line Items]
Weighted Average Interest Rate	3.88%
Pollution Control Bonds	$ 440.3	$ 440.3
Pollution Control Bonds | AEP TEXAS INC. | Minimum
Debt Instrument [Line Items]
Interest Rate	2.60%	2.60%
Pollution Control Bonds | AEP TEXAS INC. | Maximum
Debt Instrument [Line Items]
Interest Rate	4.55%	4.55%
Pollution Control Bonds | APPALACHIAN POWER COMPANY
Debt Instrument [Line Items]
Weighted Average Interest Rate	2.95%
Pollution Control Bonds	$ 429.9	$ 430
Pollution Control Bonds | APPALACHIAN POWER COMPANY | Minimum
Debt Instrument [Line Items]
Interest Rate	0.63%	0.63%
Pollution Control Bonds | APPALACHIAN POWER COMPANY | Maximum
Debt Instrument [Line Items]
Interest Rate	4.22%	4.90%
Pollution Control Bonds | INDIANA MICHIGAN POWER COMPANY
Debt Instrument [Line Items]
Weighted Average Interest Rate	2.49%
Pollution Control Bonds	$ 189.9	$ 189.4
Pollution Control Bonds | INDIANA MICHIGAN POWER COMPANY | Minimum
Debt Instrument [Line Items]
Interest Rate	0.75%	0.75%
Pollution Control Bonds | INDIANA MICHIGAN POWER COMPANY | Maximum
Debt Instrument [Line Items]
Interest Rate	3.05%	3.05%
Notes Payable - Nonaffiliated
Debt Instrument [Line Items]
Weighted Average Interest Rate	6.49%
Notes Payable - Nonaffiliated	$ 609.9	$ 193.3
Notes Payable - Nonaffiliated | Minimum
Debt Instrument [Line Items]
Interest Rate	0.93%	0.93%
Notes Payable - Nonaffiliated | Maximum
Debt Instrument [Line Items]
Interest Rate	6.89%	6.59%
Notes Payable - Nonaffiliated | INDIANA MICHIGAN POWER COMPANY
Debt Instrument [Line Items]
Weighted Average Interest Rate	5.78%
Notes Payable - Nonaffiliated	$ 142.7	$ 163.3
Notes Payable - Nonaffiliated | INDIANA MICHIGAN POWER COMPANY | Minimum
Debt Instrument [Line Items]
Interest Rate	0.93%	0.93%
Notes Payable - Nonaffiliated | INDIANA MICHIGAN POWER COMPANY | Maximum
Debt Instrument [Line Items]
Interest Rate	6.41%	6.59%
Securitization Bonds
Debt Instrument [Line Items]
Weighted Average Interest Rate	4.08%
Securitization Bonds	$ 578	$ 368.9
Securitization Bonds | Minimum
Debt Instrument [Line Items]
Interest Rate	2.06%	2.06%
Securitization Bonds | Maximum
Debt Instrument [Line Items]
Interest Rate	4.88%	3.77%
Securitization Bonds | AEP TEXAS INC.
Debt Instrument [Line Items]
Weighted Average Interest Rate	2.27%
Securitization Bonds	$ 126.8	$ 221.8
Securitization Bonds | AEP TEXAS INC. | Minimum
Debt Instrument [Line Items]
Interest Rate	2.06%	2.06%
Securitization Bonds | AEP TEXAS INC. | Maximum
Debt Instrument [Line Items]
Interest Rate	2.29%	2.84%
Securitization Bonds | APPALACHIAN POWER COMPANY
Debt Instrument [Line Items]
Weighted Average Interest Rate	3.77%
Interest Rate	3.77%	3.77%
Securitization Bonds	$ 119.8	$ 147
Securitization Bonds | SOUTHWESTERN ELECTRIC POWER COMPANY
Debt Instrument [Line Items]
Weighted Average Interest Rate	4.88%
Interest Rate	4.88%	0%
Securitization Bonds	$ 331.4	$ 0
Junior Subordinated Notes
Debt Instrument [Line Items]
Weighted Average Interest Rate	5.67%
Junior Subordinated Notes	$ 2,579.1	$ 2,388.1
Junior Subordinated Notes | Minimum
Debt Instrument [Line Items]
Interest Rate	3.88%	2.03%
Junior Subordinated Notes | Maximum
Debt Instrument [Line Items]
Interest Rate	7.05%	5.70%
Spent Nuclear Fuel Obligation
Debt Instrument [Line Items]
Spent Nuclear Fuel Obligation	$ 316.3	$ 300.4
Spent Nuclear Fuel Obligation | INDIANA MICHIGAN POWER COMPANY
Debt Instrument [Line Items]
Spent Nuclear Fuel Obligation	$ 316.3	300.4
Other Long-term Debt
Debt Instrument [Line Items]
Weighted Average Interest Rate	5.60%
Other Long-term Debt	$ 377.3	$ 1,341.5
Other Long-term Debt | Minimum
Debt Instrument [Line Items]
Interest Rate	3%	3%
Other Long-term Debt | Maximum
Debt Instrument [Line Items]
Interest Rate	13.72%	13.72%
Other Long-term Debt | AEP TEXAS INC.
Debt Instrument [Line Items]
Weighted Average Interest Rate	4.50%
Interest Rate	4.50%
Other Long-term Debt	$ 0.7	$ 200.5
Other Long-term Debt | AEP TEXAS INC. | Minimum
Debt Instrument [Line Items]
Interest Rate		4.50%
Other Long-term Debt | AEP TEXAS INC. | Maximum
Debt Instrument [Line Items]
Interest Rate		6.71%
Other Long-term Debt | APPALACHIAN POWER COMPANY
Debt Instrument [Line Items]
Weighted Average Interest Rate	5.84%
Other Long-term Debt	$ 126.5	$ 426.4
Other Long-term Debt | APPALACHIAN POWER COMPANY | Minimum
Debt Instrument [Line Items]
Interest Rate	5.75%	6.46%
Other Long-term Debt | APPALACHIAN POWER COMPANY | Maximum
Debt Instrument [Line Items]
Interest Rate	13.72%	13.72%
Other Long-term Debt | INDIANA MICHIGAN POWER COMPANY
Debt Instrument [Line Items]
Weighted Average Interest Rate	6%
Interest Rate	6%	6%
Other Long-term Debt	$ 0.2	$ 2.7
Other Long-term Debt | PUBLIC SERVICE COMPANY OF OKLAHOMA
Debt Instrument [Line Items]
Weighted Average Interest Rate	3%
Interest Rate	3%
Other Long-term Debt	$ 1.4	$ 126.8
Other Long-term Debt | PUBLIC SERVICE COMPANY OF OKLAHOMA | Minimum
Debt Instrument [Line Items]
Interest Rate		3%
Other Long-term Debt | PUBLIC SERVICE COMPANY OF OKLAHOMA | Maximum
Debt Instrument [Line Items]
Interest Rate		6.71%

FINANCING ACTIVITIES - Schedu_2

FINANCING ACTIVITIES - Schedule of Long-Term Debt Maturities (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Debt Instrument [Line Items]
2025	$ 3,335
2026	1,864.4
2027	2,283.6
2028	2,592
2029	2,694
2029	30,212.8
Principal Amount	42,981.8
Unamortized Discount, Net and Debt Issuance Costs	(339)
Total Long-term Debt Outstanding	42,642.8	$ 40,143.2
AEP TEXAS INC.
Debt Instrument [Line Items]
2025	324.5
2026	75
2027	25.6
2028	526.2
2029	627.4
2029	4,912.8
Principal Amount	6,491.5
Unamortized Discount, Net and Debt Issuance Costs	(49.9)
Total Long-term Debt Outstanding	6,441.6	5,889.8
AEP TRANSMISSION COMPANY, LLC
Debt Instrument [Line Items]
2025	90
2026	425
2027	0
2028	60
2029	55
2029	5,201
Principal Amount	5,831
Unamortized Discount, Net and Debt Issuance Costs	(62.9)
Total Long-term Debt Outstanding	5,768.1	5,414.4
APPALACHIAN POWER COMPANY
Debt Instrument [Line Items]
2025	798.6
2026	30.9
2027	355.6
2028	117.8
2029	0
2029	4,400
Principal Amount	5,702.9
Unamortized Discount, Net and Debt Issuance Costs	(42.6)
Total Long-term Debt Outstanding	5,660.3	5,588.3
INDIANA MICHIGAN POWER COMPANY
Debt Instrument [Line Items]
2025	269.2
2026	43.6
2027	13.7
2028	356.5
2029	0
2029	2,841.3
Principal Amount	3,524.3
Unamortized Discount, Net and Debt Issuance Costs	(30)
Total Long-term Debt Outstanding	3,494.3	3,499.4
OHIO POWER COMPANY
Debt Instrument [Line Items]
2025	0
2026	0
2027	0
2028	0
2029	0
2029	3,750
Principal Amount	3,750
Unamortized Discount, Net and Debt Issuance Costs	(34.3)
Total Long-term Debt Outstanding	3,715.7	3,366.8
PUBLIC SERVICE COMPANY OF OKLAHOMA
Debt Instrument [Line Items]
2025	125.6
2026	50.6
2027	0.3
2028	0
2029	100
2029	2,600
Principal Amount	2,876.5
Unamortized Discount, Net and Debt Issuance Costs	(20.9)
Total Long-term Debt Outstanding	2,855.6	2,384.6
SOUTHWESTERN ELECTRIC POWER COMPANY
Debt Instrument [Line Items]
2025	22.7
2026	916.6
2027	17.4
2028	593.3
2029	19.2
2029	2,442.4
Principal Amount	4,011.6
Unamortized Discount, Net and Debt Issuance Costs	(30.8)
Total Long-term Debt Outstanding	$ 3,980.8	$ 3,646.9

FINANCING ACTIVITIES - Long-ter

FINANCING ACTIVITIES - Long-term Debt Subsequent Events Narrative (Details) - Subsequent Event - USD ($) $ in Millions	1 Months Ended
	Feb. 13, 2025	Jan. 31, 2025
INDIANA MICHIGAN POWER COMPANY
Debt Instrument [Line Items]
Debt retired	$ 4	$ 9
Transource Energy | Other Long-term Debt
Debt Instrument [Line Items]
Debt issued		2
KPCo | Term loan
Debt Instrument [Line Items]
Debt issued		$ 150
APPALACHIAN POWER COMPANY | Securitization Bonds
Debt Instrument [Line Items]
Debt retired	14
AEP TEXAS INC. | Securitization Bonds
Debt Instrument [Line Items]
Debt retired	$ 12

FINANCING ACTIVITIES - Debt Cov

FINANCING ACTIVITIES - Debt Covenants Narrative (Details) - AEP TRANSMISSION COMPANY, LLC $ in Millions	Dec. 31, 2024 USD ($)
Debt Instrument [Line Items]
Sub-limit of secured debt	$ 50
Maximum percentage of consolidated tangible net assets	10%
Tangible capital to tangible assets	0.006

FINANCING ACTIVITIES - Schedu_3

FINANCING ACTIVITIES - Schedule of Dividend Restrictions (Details) $ in Millions	Dec. 31, 2024 USD ($)
Dividends Payable [Line Items]
Restricted Retained Earnings	$ 3,247.9
AEP TEXAS INC.
Dividends Payable [Line Items]
Restricted Retained Earnings	1,109.2
AEP TRANSMISSION COMPANY, LLC
Dividends Payable [Line Items]
Restricted Retained Earnings	0
APPALACHIAN POWER COMPANY
Dividends Payable [Line Items]
Restricted Retained Earnings	539.2
INDIANA MICHIGAN POWER COMPANY
Dividends Payable [Line Items]
Restricted Retained Earnings	707
OHIO POWER COMPANY
Dividends Payable [Line Items]
Restricted Retained Earnings	0
PUBLIC SERVICE COMPANY OF OKLAHOMA
Dividends Payable [Line Items]
Restricted Retained Earnings	267.7
SOUTHWESTERN ELECTRIC POWER COMPANY
Dividends Payable [Line Items]
Restricted Retained Earnings	$ 366.5

FINANCING ACTIVITIES - Dividend

FINANCING ACTIVITIES - Dividend Restrictions Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Dividends Payable [Line Items]
Maximum percentage debt to capitalization	67.50%
Restricted net assets	$ 17,400
Retained earnings available to pay dividends	8,600
Dividends paid on common stock	1,903.9	$ 1,760.4	$ 1,645.2
Retained Earnings
Dividends Payable [Line Items]
Dividends paid on common stock	$ 1,900	1,800	1,600
INDIANA MICHIGAN POWER COMPANY
Dividends Payable [Line Items]
Maximum percentage debt to capitalization	67.50%
Dividends paid on common stock	$ 150	212.5	110
AEP TEXAS INC.
Dividends Payable [Line Items]
Maximum percentage debt to capitalization	67.50%
Dividends paid on common stock	$ 350	0	0
APPALACHIAN POWER COMPANY
Dividends Payable [Line Items]
Maximum percentage debt to capitalization	67.50%
Dividends paid on common stock	$ 75	0	37.5
SOUTHWESTERN ELECTRIC POWER COMPANY
Dividends Payable [Line Items]
Maximum percentage debt to capitalization	67.50%
Dividends paid on common stock	$ 250	175	105
PUBLIC SERVICE COMPANY OF OKLAHOMA
Dividends Payable [Line Items]
Maximum percentage debt to capitalization	67.50%
Dividends paid on common stock	$ 140	$ 52.5	$ 45
AEP TRANSMISSION COMPANY, LLC
Dividends Payable [Line Items]
Maximum percentage debt to capitalization	67.50%

FINANCING ACTIVITIES - Line of

FINANCING ACTIVITIES - Line of Credit and Short-Term Debt Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Line of Credit Facility [Line Items]
Credit facilities, total	$ 6,000
Short-term – Securitized Debt of Receivables	$ 900	$ 888
Securitized Debt
Line of Credit Facility [Line Items]
Weighted average interest rate of commercial paper outstanding during year	5.39%
Short-term – Securitized Debt of Receivables	$ 900
Commercial Paper
Line of Credit Facility [Line Items]
Weighted average interest rate of commercial paper outstanding during year	5.39%
Short-term debt, maximum amount outstanding during period	$ 2,900

FINANCING ACTIVITIES - Schedu_4

FINANCING ACTIVITIES - Schedule of Short-term Debt (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Short-Term Debt [Line Items]
Short-term – Securitized Debt of Receivables	$ 900	$ 888
Interest Rate	4.73%	5.65%
Commercial Paper	$ 1,618.3	$ 1,937.9
Total Short-term Debt	2,523.8	2,830.2
SOUTHWESTERN ELECTRIC POWER COMPANY
Short-Term Debt [Line Items]
Notes Payable	5.5	4.3
Total Short-term Debt	$ 5.5	$ 4.3
Commercial Paper
Short-Term Debt [Line Items]
Weighted-Average Interest Rate	4.70%	5.69%
Notes Payable | SOUTHWESTERN ELECTRIC POWER COMPANY
Short-Term Debt [Line Items]
Weighted-Average Interest Rate	6.69%	7.71%

FINANCING ACTIVITIES - Schedu_5

FINANCING ACTIVITIES - Schedule of Utility Money Pool Participants' Money Pool Activity and Authorized Borrowing Limits (Details) - Utility - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
AEP TEXAS INC.
Short-Term Debt [Line Items]
Maximum Borrowings	$ 374.6	$ 477.5
Maximum Loans	274.3	42
Average Borrowings	233.8	216.8
Average Loans	165.1	12.9
Authorized Short-term Borrowing Limit	600	600
AEP TEXAS INC. | Related Party
Short-Term Debt [Line Items]
Net Loans to (Borrowings from)	(284.9)	(103.7)
AEP TRANSMISSION COMPANY, LLC
Short-Term Debt [Line Items]
Maximum Borrowings	313.3	471.3
Maximum Loans	332	309.4
Average Borrowings	71.8	135.6
Average Loans	138.4	70.5
Authorized Short-term Borrowing Limit	820	820
AEP TRANSMISSION COMPANY, LLC | Related Party
Short-Term Debt [Line Items]
Net Loans to (Borrowings from)	(72.9)	(62.8)
APPALACHIAN POWER COMPANY
Short-Term Debt [Line Items]
Maximum Borrowings	399.5	388.6
Maximum Loans	132.3	19.8
Average Borrowings	102.6	283.5
Average Loans	29.7	19
Authorized Short-term Borrowing Limit	750	750
APPALACHIAN POWER COMPANY | Related Party
Short-Term Debt [Line Items]
Net Loans to (Borrowings from)	(77.3)	(320.7)
INDIANA MICHIGAN POWER COMPANY
Short-Term Debt [Line Items]
Maximum Borrowings	135.8	475.3
Maximum Loans	8.4	112.2
Average Borrowings	58.8	84
Average Loans	3.9	44.2
Authorized Short-term Borrowing Limit	500	500
INDIANA MICHIGAN POWER COMPANY | Related Party
Short-Term Debt [Line Items]
Net Loans to (Borrowings from)	(126.8)	(63.3)
OHIO POWER COMPANY
Short-Term Debt [Line Items]
Maximum Borrowings	310	485.7
Maximum Loans	183.4	64.7
Average Borrowings	180.5	183
Average Loans	94.2	40.2
Authorized Short-term Borrowing Limit	600	500
OHIO POWER COMPANY | Related Party
Short-Term Debt [Line Items]
Net Loans to (Borrowings from)	114.9	(110.5)
PUBLIC SERVICE COMPANY OF OKLAHOMA
Short-Term Debt [Line Items]
Maximum Borrowings	308.9	375
Maximum Loans	314.5	121.5
Average Borrowings	171.4	92.5
Average Loans	287.7	49.6
Authorized Short-term Borrowing Limit	750	750
PUBLIC SERVICE COMPANY OF OKLAHOMA | Related Party
Short-Term Debt [Line Items]
Net Loans to (Borrowings from)	232	(54.4)
SOUTHWESTERN ELECTRIC POWER COMPANY
Short-Term Debt [Line Items]
Maximum Borrowings	362.2	401.6
Maximum Loans	59.3	25.8
Average Borrowings	249.5	150.7
Average Loans	57.3	16.5
Authorized Short-term Borrowing Limit	750	750
SOUTHWESTERN ELECTRIC POWER COMPANY | Related Party
Short-Term Debt [Line Items]
Net Loans to (Borrowings from)	$ (275)	$ (88.7)

FINANCING ACTIVITIES - Schedu_6

FINANCING ACTIVITIES - Schedule of Nonutility Money Pool Activity (Details) - Nonutility - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
AEP TEXAS INC.
Short-Term Debt [Line Items]
Maximum Loans	$ 7.2	$ 7.1
Average Loans	7.1	6.9
AEP TEXAS INC. | Related Party
Short-Term Debt [Line Items]
Advances to Affiliates	7.2	7.1
SOUTHWESTERN ELECTRIC POWER COMPANY
Short-Term Debt [Line Items]
Maximum Loans	2.9	2.8
Average Loans	2.6	2.4
SOUTHWESTERN ELECTRIC POWER COMPANY | Related Party
Short-Term Debt [Line Items]
Advances to Affiliates	$ 2.3	$ 2.2

FINANCING ACTIVITIES - Schedu_7

FINANCING ACTIVITIES - Schedule of Direct Borrowing Activity (Details) - Direct Borrowing - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
AEP TRANSMISSION COMPANY, LLC
Short-Term Debt [Line Items]
Maximum Borrowings	$ 49.4	$ 42.7
Maximum Loans	148.5	158.1
Average Borrowings	14.9	18
Average Loans	57	64.2
Borrowings	0	42.7
Loans	20.4	0
Authorized Short-term Borrowing Limit	0	0
SWTCo
Short-Term Debt [Line Items]
Maximum Borrowings	1.9	1.6
Maximum Loans	0	0
Average Borrowings	1.8	1.6
Average Loans	0	0
Borrowings	1.8	1.7
Loans	0	0
Authorized Short-term Borrowing Limit	$ 50	$ 50

FINANCING ACTIVITIES - Schedu_8

FINANCING ACTIVITIES - Schedule of Maximum and Minimum Interest Rates for Funds Either Borrowed from or Loaned to Utility Money Pool (Details) - Utility	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
SOUTHWESTERN ELECTRIC POWER COMPANY
Short-Term Debt [Line Items]
Maximum Interest Rate	5.79%	5.81%	5.28%
Minimum Interest Rate	4.74%	4.66%	0.10%
OHIO POWER COMPANY
Short-Term Debt [Line Items]
Maximum Interest Rate	5.79%	5.81%	5.28%
Minimum Interest Rate	4.74%	4.66%	0.10%
INDIANA MICHIGAN POWER COMPANY
Short-Term Debt [Line Items]
Maximum Interest Rate	5.79%	5.81%	5.28%
Minimum Interest Rate	4.74%	4.66%	0.10%
AEP TEXAS INC.
Short-Term Debt [Line Items]
Maximum Interest Rate	5.79%	5.81%	5.28%
Minimum Interest Rate	4.74%	4.66%	0.10%
APPALACHIAN POWER COMPANY
Short-Term Debt [Line Items]
Maximum Interest Rate	5.79%	5.81%	5.28%
Minimum Interest Rate	4.74%	4.66%	0.10%
PUBLIC SERVICE COMPANY OF OKLAHOMA
Short-Term Debt [Line Items]
Maximum Interest Rate	5.79%	5.81%	5.28%
Minimum Interest Rate	4.74%	4.66%	0.10%
AEP TRANSMISSION COMPANY, LLC
Short-Term Debt [Line Items]
Maximum Interest Rate	5.79%	5.81%	5.28%
Minimum Interest Rate	4.74%	4.66%	0.10%

FINANCING ACTIVITIES - Schedu_9

FINANCING ACTIVITIES - Schedule of Average Interest Rates for Funds Borrowed from and Loaned to Utility Money Pool (Details) - Utility	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
AEP TEXAS INC.
Short-Term Debt [Line Items]
Average Interest Rate for Funds Borrowed	5.48%	5.46%	1.08%
Average Interest Rate for Funds Loaned	5.45%	5.71%	1.99%
AEP TRANSMISSION COMPANY, LLC
Short-Term Debt [Line Items]
Average Interest Rate for Funds Borrowed	5.51%	5.41%	1.81%
Average Interest Rate for Funds Loaned	5.50%	5.56%	2.47%
APPALACHIAN POWER COMPANY
Short-Term Debt [Line Items]
Average Interest Rate for Funds Borrowed	5.51%	5.54%	2.34%
Average Interest Rate for Funds Loaned	5.41%	5.54%	2.39%
INDIANA MICHIGAN POWER COMPANY
Short-Term Debt [Line Items]
Average Interest Rate for Funds Borrowed	5.40%	5.14%	2.57%
Average Interest Rate for Funds Loaned	5.44%	5.57%	2.20%
OHIO POWER COMPANY
Short-Term Debt [Line Items]
Average Interest Rate for Funds Borrowed	5.70%	5.43%	3.51%
Average Interest Rate for Funds Loaned	5.20%	5.60%	1.22%
PUBLIC SERVICE COMPANY OF OKLAHOMA
Short-Term Debt [Line Items]
Average Interest Rate for Funds Borrowed	5.50%	5.51%	2.65%
Average Interest Rate for Funds Loaned	4.79%	5.35%	0.75%
SOUTHWESTERN ELECTRIC POWER COMPANY
Short-Term Debt [Line Items]
Average Interest Rate for Funds Borrowed	5.41%	5.34%	2.80%
Average Interest Rate for Funds Loaned	4.78%	5.72%	0.55%

FINANCING ACTIVITIES - Sched_10

FINANCING ACTIVITIES - Schedule of Maximum, Minimum and Average Interest Rates for Funds Borrowed from and Loaned to the Nonutility Money Pool (Details) - Nonutility	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
AEP TEXAS INC.
Short-Term Debt [Line Items]
Maximum Interest Rate for Funds Loaned	5.79%	5.81%	5.28%
Minimum Interest Rate for Funds Loaned	4.74%	4.66%	0.46%
Average Interest Rate for Funds Loaned	5.46%	5.54%	2.23%
SOUTHWESTERN ELECTRIC POWER COMPANY
Short-Term Debt [Line Items]
Maximum Interest Rate for Funds Loaned	5.79%	5.81%	5.28%
Minimum Interest Rate for Funds Loaned	4.74%	4.66%	0.46%
Average Interest Rate for Funds Loaned	5.45%	5.56%	2.23%

FINANCING ACTIVITIES - Sched_11

FINANCING ACTIVITIES - Schedule of Maximum Minimum and Average Interest Rates for Funds Borrowed from and Loaned to AEP (Details) - Direct Borrowing - AEP TRANSMISSION COMPANY, LLC	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Short-Term Debt [Line Items]
Maximum Interest Rate for Funds Borrowed	5.79%	5.81%	5.28%
Minimum Interest Rate For Funds Borrowed	4.66%	4.53%	0.46%
Maximum Interest Rate for Funds Loaned	5.79%	5.81%	5.28%
Minimum Interest Rate for Funds Loaned	4.66%	4.53%	0.46%
Average Interest Rate for Funds Borrowed	5.53%	5.56%	2.08%
Average Interest Rate for Funds Loaned	5.56%	5.51%	2.07%

FINANCING ACTIVITIES - Sched_12

FINANCING ACTIVITIES - Schedule of Interest Expense Incurred For Funds Borrowed from Utility Money Pool (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Short-Term Debt [Line Items]
Interest Expense	$ 1,862.8	$ 1,806.9	$ 1,396.1
AEP TEXAS INC.
Short-Term Debt [Line Items]
Interest Expense	257.6	232.7	208.7
AEP TRANSMISSION COMPANY, LLC
Short-Term Debt [Line Items]
Interest Expense	214.2	194.5	162.7
APPALACHIAN POWER COMPANY
Short-Term Debt [Line Items]
Interest Expense	271.4	269.6	233.9
INDIANA MICHIGAN POWER COMPANY
Short-Term Debt [Line Items]
Interest Expense	133.5	136.7	125.2
OHIO POWER COMPANY
Short-Term Debt [Line Items]
Interest Expense	148	130.9	119.6
PUBLIC SERVICE COMPANY OF OKLAHOMA
Short-Term Debt [Line Items]
Interest Expense	95.3	103.6	83.8
SOUTHWESTERN ELECTRIC POWER COMPANY
Short-Term Debt [Line Items]
Interest Expense	105.5	147.2	137.4
Utility | Related Party | APPALACHIAN POWER COMPANY
Short-Term Debt [Line Items]
Interest Expense	6.1	16.8	5.6
Utility | Related Party | INDIANA MICHIGAN POWER COMPANY
Short-Term Debt [Line Items]
Interest Expense	4.3	3.2	2.9
Utility | Related Party | OHIO POWER COMPANY
Short-Term Debt [Line Items]
Interest Expense	3.7	9.7	2.3
Utility | Related Party | PUBLIC SERVICE COMPANY OF OKLAHOMA
Short-Term Debt [Line Items]
Interest Expense	8.9	2.3	5.5
Utility | Nonutility | Related Party | AEP TEXAS INC.
Short-Term Debt [Line Items]
Interest Expense	6.7	10.8	0.9
Utility | Nonutility | Related Party | SOUTHWESTERN ELECTRIC POWER COMPANY
Short-Term Debt [Line Items]
Interest Expense	13.6	7.9	4.9
Utility | Direct Borrowing | Related Party | AEP TRANSMISSION COMPANY, LLC
Short-Term Debt [Line Items]
Interest Expense	$ 4.3	$ 7.6	$ 3.5

FINANCING ACTIVITIES - Sched_13

FINANCING ACTIVITIES - Schedule of Interest Income Earned for Funds Loaned to Utility Money Pool (Details) - Utility - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
APPALACHIAN POWER COMPANY
Short-Term Debt [Line Items]
Interest Income Earned on Advances to the Money Pool	$ 1.6	$ 1.1	$ 2.8
INDIANA MICHIGAN POWER COMPANY
Short-Term Debt [Line Items]
Interest Income Earned on Advances to the Money Pool	0	2.4	0.5
OHIO POWER COMPANY
Short-Term Debt [Line Items]
Interest Income Earned on Advances to the Money Pool	3.2	0.1	0.4
PUBLIC SERVICE COMPANY OF OKLAHOMA
Short-Term Debt [Line Items]
Interest Income Earned on Advances to the Money Pool	1	1.5	0.3
Nonutility | AEP TEXAS INC.
Short-Term Debt [Line Items]
Interest Income Earned on Advances to the Money Pool	4.4	0.1	2.6
Nonutility | SOUTHWESTERN ELECTRIC POWER COMPANY
Short-Term Debt [Line Items]
Interest Income Earned on Advances to the Money Pool	0.2	0.2	0.2
Direct Borrowing | AEP TRANSMISSION COMPANY, LLC
Short-Term Debt [Line Items]
Interest Income Earned on Advances to the Money Pool	$ 10.5	$ 7	$ 1.6

FINANCING ACTIVITIES - Securiti

FINANCING ACTIVITIES - Securitized Accounts Receivables Narrative (Details) $ in Millions	Dec. 31, 2024 USD ($)
Debt Disclosure [Abstract]
Total commitment from bank conduits to finance receivables	$ 900

FINANCING ACTIVITIES - Sched_14

FINANCING ACTIVITIES - Schedule of Comparative Accounts Receivable Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Debt Disclosure [Abstract]
Effective Interest Rates on Securitization of Accounts Receivable	5.39%	5.33%	1.84%
Net Uncollectible Accounts Receivable Written Off	$ 29.4	$ 30.7	$ 29.5

FINANCING ACTIVITIES - Sched_15

FINANCING ACTIVITIES - Schedule of Customer Accounts Receivable Managed Portfolio (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Debt Disclosure [Abstract]
Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts	$ 1,117	$ 1,207.4
Short-term – Securitized Debt of Receivables	900	888
Delinquent Securitized Accounts Receivable	56.2	52.2
Bad Debt Reserves Related to Securitization	44.5	42
Unbilled Receivables Related to Securitization	$ 335.5	$ 409.8

FINANCING ACTIVITIES - Sched_16

FINANCING ACTIVITIES - Schedule of Accounts Receivable and Accrued Unbilled Revenues (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
APPALACHIAN POWER COMPANY
Short-Term Debt [Line Items]
Accounts receivable and accrued unbilled revenues	$ 192.7	$ 184.6
INDIANA MICHIGAN POWER COMPANY
Short-Term Debt [Line Items]
Accounts receivable and accrued unbilled revenues	160.5	156.4
OHIO POWER COMPANY
Short-Term Debt [Line Items]
Accounts receivable and accrued unbilled revenues	470.7	541.7
PUBLIC SERVICE COMPANY OF OKLAHOMA
Short-Term Debt [Line Items]
Accounts receivable and accrued unbilled revenues	111.4	134.6
SOUTHWESTERN ELECTRIC POWER COMPANY
Short-Term Debt [Line Items]
Accounts receivable and accrued unbilled revenues	$ 153.5	$ 168.3

FINANCING ACTIVITIES - Sched_17

FINANCING ACTIVITIES - Schedule of Fees Paid to AEP Credit for Customer Accounts Receivable Sold (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	$ 19,969.7	$ 19,454.8	$ 19,391.7
APPALACHIAN POWER COMPANY
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	4,038.8	3,740.6	3,520.7
INDIANA MICHIGAN POWER COMPANY
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	2,603.5	2,522.3	2,659.7
OHIO POWER COMPANY
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	3,780.9	3,802.8	3,672.1
PUBLIC SERVICE COMPANY OF OKLAHOMA
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1,849.5	1,976.6	1,875.7
SOUTHWESTERN ELECTRIC POWER COMPANY
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	2,043.3	2,192.1	2,283.2
Servicing Contracts | APPALACHIAN POWER COMPANY
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	15.5	16.9	9.4
Servicing Contracts | INDIANA MICHIGAN POWER COMPANY
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	15.4	16.3	9.7
Servicing Contracts | OHIO POWER COMPANY
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	29.7	29.5	29.8
Servicing Contracts | PUBLIC SERVICE COMPANY OF OKLAHOMA
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	14.2	15.3	7.4
Servicing Contracts | SOUTHWESTERN ELECTRIC POWER COMPANY
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	$ 17.6	$ 18.5	$ 9.4

FINANCING ACTIVITIES - Sched_18

FINANCING ACTIVITIES - Schedule of Proceeds on Sale of Receivables to AEP Credit (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
APPALACHIAN POWER COMPANY
Accounts, Notes, Loans and Financing Receivable [Line Items]
Proceeds from sale of receivables to AEP Credit	$ 1,953.7	$ 1,819.8	$ 1,552.9
INDIANA MICHIGAN POWER COMPANY
Accounts, Notes, Loans and Financing Receivable [Line Items]
Proceeds from sale of receivables to AEP Credit	2,105.3	2,054.8	2,045.6
OHIO POWER COMPANY
Accounts, Notes, Loans and Financing Receivable [Line Items]
Proceeds from sale of receivables to AEP Credit	3,197.8	3,339.3	3,101.3
PUBLIC SERVICE COMPANY OF OKLAHOMA
Accounts, Notes, Loans and Financing Receivable [Line Items]
Proceeds from sale of receivables to AEP Credit	1,781.3	1,944.5	1,809.5
SOUTHWESTERN ELECTRIC POWER COMPANY
Accounts, Notes, Loans and Financing Receivable [Line Items]
Proceeds from sale of receivables to AEP Credit	$ 1,838.1	$ 1,866.4	$ 1,858.4

STOCK-BASED COMPENSATION - Narr

STOCK-BASED COMPENSATION - Narrative (Details) $ in Millions	12 Months Ended
	Dec. 31, 2024 USD ($) day metric shares	Dec. 31, 2023	Dec. 31, 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Cost not yet recognized, amount | $	$ 59
Cost not yet recognized, period for recognition	1 year 6 months
Performance Shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award performance period	3 years
Award performance score, lower	0%
Award performance score, higher	200%
Vesting period	3 years	3 years	3 years
Number of performance metrics | metric	3
Performance metric, operating period term	3 years
Performance metric, operating period, weight	50%
Performance metric, relative total shareholder return, weight	40%
Performance metric, generation capacity additions, weight	10%
Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Service period	3 years
Aggregate intrinsic value of nonvested | $	$ 44
Weighted-average remaining contractual life	1 year 6 months
Restricted Stock Units | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Expiration period	40 months
Stock Unit Accumulation Plan | Non-Employee Directors
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of trading days | day	20
Stock Unit Accumulation Plan | Maximum | Non-Employee Directors
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award payment period	10 years
Stock Unit Accumulation Plan | Minimum | Non-Employee Directors
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Subsequent award period	5 years
2024 Long-Term Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares available for grant (in shares) | shares	10,000,000
Common stock, capital shares reserved for future issuance (in shares) | shares	9,806,016
Shares available for grant, reduction rate	1

STOCK-BASED COMPENSATION - Perf

STOCK-BASED COMPENSATION - Performance Shares and Reinvested Dividends (Details) - $ / shares	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Performance Shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awarded (in shares)	440,700	486,700	530,300
Weighted-Average Share Fair Value at Grant Date	$ 99.76	$ 98.63	$ 97.61
Vesting Period (in years)	3 years	3 years	3 years
Performance Shares and AEP Career Shares (Reinvested Dividends Portion)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awarded (in shares)	66,000	81,300	63,300
Weighted-Average Share Fair Value at Grant Date	$ 91.75	$ 82.02	$ 98.73

STOCK-BASED COMPENSATION - Pe_2

STOCK-BASED COMPENSATION - Performance Shares Earned (Details) - Performance Shares - shares	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance Score	109.80%	106.10%	131.10%
Performance Shares Earned (in shares)	477,487	540,863	512,660
Performance Shares Mandatorily Deferred as AEP Career Shares (in shares)	39,172	70,377	28,282
Performance Shares Voluntarily Deferred into the Incentive Compensation Deferral Program (in shares)	21,245	22,716	23,609
Performance Shares to be Settled (in shares)	417,070	447,770	460,769

STOCK-BASED COMPENSATION - Pe_3

STOCK-BASED COMPENSATION - Performance Shares and AEP Career Shares (Details) - Performance Shares and AEP Career Shares (Reinvested Dividends Portion) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
AEP Common Stock Settlements for Performance Shares	$ 38.1	$ 41.8	$ 43.2
AEP Common Stock Settlements for Career Share Distributions	$ 8.4	$ 8.3	$ 5.1

STOCK-BASED COMPENSATION - Pe_4

STOCK-BASED COMPENSATION - Performance Shares Activity (Details) - Performance Shares - $ / shares	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Shares
Nonvested, beginning balance (in shares)	889,900
Awarded (in shares)	440,700	486,700	530,300
Dividends (in shares)	49,400
Vested (in shares)	(440,600)
Forfeited (in shares)	(161,800)
Nonvested, ending balance (in shares)	777,600	889,900
Weighted Average Grant Date Fair Value
Nonvested, beginning balance (in dollars per share)	$ 99.49
Awarded (in dollars per share)	99.76	$ 98.63	$ 97.61
Dividends (in dollars per share)	91.82
Vested (in dollars per share)	100.52
Forfeited (in dollars per share)	87.94
Nonvested, ending balance (in dollars per share)	$ 100.97	$ 99.49
Shares to be converted (in shares)	417,000

STOCK-BASED COMPENSATION - Mont

STOCK-BASED COMPENSATION - Monte Carlo Valuation (Details) - Performance Shares	12 Months Ended
	Dec. 31, 2024 Rate	Dec. 31, 2023 Rate	Dec. 31, 2022 Rate
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Valuation Period (in years)	2 years 10 months 6 days	2 years 10 months 13 days	2 years 10 months 9 days
Expected Volatility Minimum	18.79%	21.23%	25.92%
Expected Volatility Maximum	33.29%	39%	40.82%
Expected Volatility Average	22.34%	25.35%	31.09%
Dividend Rate	0%	0%	0%
Risk Free Rate	4.43%	4.32%	1.64%

STOCK-BASED COMPENSATION - Rest

STOCK-BASED COMPENSATION - Restricted Stock Units (Details) - Restricted Stock Units - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awarded (in shares)	417,000	268,400	290,400
Weighted-Average Share Fair Value at Grant Date	$ 87.85	$ 88.52	$ 90.48
Fair Value of Restricted Stock Units Vested	$ 25.9	$ 18.8	$ 17.8
Intrinsic Value of Restricted Stock Units Vested	$ 27.3	$ 19	$ 20.3

STOCK-BASED COMPENSATION - Re_2

STOCK-BASED COMPENSATION - Restricted Stock Units Activity (Details) - Restricted Stock Units - $ / shares	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Shares
Nonvested, beginning balance (in shares)	431,100
Awarded (in shares)	417,000	268,400	290,400
Vested (in shares)	(296,800)
Forfeited (in shares)	(74,000)
Nonvested, ending balance (in shares)	477,300	431,100
Weighted Average Grant Date Fair Value
Nonvested, beginning balance (in dollars per share)	$ 88.57
Awarded (in dollars per share)	87.85	$ 88.52	$ 90.48
Vested (in dollars per share)	87.26
Forfeited (in dollars per share)	89.97
Nonvested, ending balance (in dollars per share)	$ 88.37	$ 88.57

STOCK-BASED COMPENSATION - Stoc

STOCK-BASED COMPENSATION - Stock Unit Accumulation Plan for Non-Employee Directors (Details) - Stock Unit Accumulation Plan - Non-Employee Directors - $ / shares	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awarded (in shares)	18,900	19,800	14,500
Weighted-Average Share Fair Value at Grant Date	$ 91.42	$ 82.14	$ 95.16

STOCK-BASED COMPENSATION - Shar

STOCK-BASED COMPENSATION - Share-based Compensation Plans (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Share-Based Payment Arrangement, Noncash Expense [Abstract]
Compensation Cost for Share-based Payment Arrangements	$ 52.9	$ 50.9	$ 63.3
Actual Tax Benefit	7.4	6.4	8
Total Compensation Cost Capitalized	$ 13.9	$ 15.3	$ 16

RELATED PARTY TRANSACTIONS - Na

RELATED PARTY TRANSACTIONS - Narrative (Details)	5 Months Ended	12 Months Ended
	Dec. 31, 2024 USD ($) state company	Dec. 31, 2024 USD ($) state company	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)	Aug. 31, 2023
Related Party Transaction [Line Items]
Number of states within service area | state	11	11
G&M | Fowler Ridge 2
Related Party Transaction [Line Items]
Ownership percentage					50%
Related Party
Related Party Transaction [Line Items]
Purchases from related party		$ 100,000
Power Coordination Agreement
Related Party Transaction [Line Items]
Number of member companies allocated for power and natural gas risk management activities | company	4	4
Joint License Agreement | AEP TRANSMISSION COMPANY, LLC
Related Party Transaction [Line Items]
Related party transaction, agreement term		50 years
Related party transaction, agreement term with counterparty		5 years
Related party transaction, agreement, expiration, auto-renew period		1 year
Direct Purchases from AEGCo | INDIANA MICHIGAN POWER COMPANY
Related Party Transaction [Line Items]
Purchases from related party		$ 209,000,000	$ 181,000,000	$ 242,000,000
Ohio Auction SSO Load Delivery Purchases from Affiliates | OHIO POWER COMPANY
Related Party Transaction [Line Items]
Purchases from related party		98,000,000	87,000,000	10,000,000
Clean Affordable Reliable Coalition (CARE)
Related Party Transaction [Line Items]
Related party transaction, amount		$ 0	$ 100,000	$ 200,000
Vendor Purchases
Related Party Transaction [Line Items]
Related party transaction, amount	$ 44,000,000
Vendor Purchases | AEP TEXAS INC.
Related Party Transaction [Line Items]
Related party transaction, amount	25,000,000
Vendor Purchases | PUBLIC SERVICE COMPANY OF OKLAHOMA
Related Party Transaction [Line Items]
Related party transaction, amount	$ 13,000,000
Transmission Revenues | Related Party
Related Party Transaction [Line Items]
Costs allocation, average period		12 months

RELATED PARTY TRANSACTIONS - Co

RELATED PARTY TRANSACTIONS - Contributions (Details) - Charitable Contributions - USD ($)	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Related Party Transaction [Line Items]
Related party transaction, amount	$ 0	$ 0	$ 75,000,000
AEP TEXAS INC.
Related Party Transaction [Line Items]
Related party transaction, amount			9,900,000
AEP TRANSMISSION COMPANY, LLC
Related Party Transaction [Line Items]
Related party transaction, amount			11,100,000
APPALACHIAN POWER COMPANY
Related Party Transaction [Line Items]
Related party transaction, amount			12,500,000
INDIANA MICHIGAN POWER COMPANY
Related Party Transaction [Line Items]
Related party transaction, amount			11,000,000
OHIO POWER COMPANY
Related Party Transaction [Line Items]
Related party transaction, amount			8,100,000
PUBLIC SERVICE COMPANY OF OKLAHOMA
Related Party Transaction [Line Items]
Related party transaction, amount			5,800,000
SOUTHWESTERN ELECTRIC POWER COMPANY
Related Party Transaction [Line Items]
Related party transaction, amount			$ 8,800,000

RELATED PARTY TRANSACTIONS - _2

RELATED PARTY TRANSACTIONS - Costs Paid (Details) - Barging, Urea Transloading And Other Transportion Services - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
AEGCo
Related Party Transaction [Line Items]
Related party transaction, amount	$ 10	$ 9.3	$ 11.3
APPALACHIAN POWER COMPANY
Related Party Transaction [Line Items]
Related party transaction, amount	47	39.2	36.1
KPCo
Related Party Transaction [Line Items]
Related party transaction, amount	0	0	2
WPCo
Related Party Transaction [Line Items]
Related party transaction, amount	$ 7.5	$ 10.6	$ 4.7

RELATED PARTY TRANSACTIONS - Pu

RELATED PARTY TRANSACTIONS - Purchased Electricity (Details) - G&M - Power Purchased From Affiliates - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
INDIANA MICHIGAN POWER COMPANY
Related Party Transaction [Line Items]
Related party transaction, amount	$ 8	$ 11.8
OHIO POWER COMPANY
Related Party Transaction [Line Items]
Related party transaction, amount	16.1	23.6
SOUTHWESTERN ELECTRIC POWER COMPANY
Related Party Transaction [Line Items]
Related party transaction, amount	$ 0	$ 13.7

RELATED PARTY TRANSACTIONS - Tr

RELATED PARTY TRANSACTIONS - Transmission Service Charges (Details) - Net Transmission Services - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
AEP TEXAS INC.
Related Party Transaction [Line Items]
Related party transaction, amount	$ 30.6	$ 28.7	$ 28.5
APPALACHIAN POWER COMPANY
Related Party Transaction [Line Items]
Related party transaction, amount	380.7	365.1	345.1
INDIANA MICHIGAN POWER COMPANY
Related Party Transaction [Line Items]
Related party transaction, amount	252.7	226.2	220.8
OHIO POWER COMPANY
Related Party Transaction [Line Items]
Related party transaction, amount	696.1	665.3	608.2
PUBLIC SERVICE COMPANY OF OKLAHOMA
Related Party Transaction [Line Items]
Related party transaction, amount	127.1	100.1	110.8
SOUTHWESTERN ELECTRIC POWER COMPANY
Related Party Transaction [Line Items]
Related party transaction, amount	$ 64.5	$ 49.2	$ 62.1

RELATED PARTY TRANSACTIONS - Re

RELATED PARTY TRANSACTIONS - Revenues (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	$ 19,969.7	$ 19,454.8	$ 19,391.7
AEP TEXAS INC.
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	2,080.8	1,906.1	1,848
AEP TEXAS INC. | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	5.4	4.9	3.5
AEP TRANSMISSION COMPANY, LLC
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	1,950.5	1,720.6	1,651.7
AEP TRANSMISSION COMPANY, LLC | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	1,512.3	1,317.8	1,283.8
APPALACHIAN POWER COMPANY
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	4,038.8	3,740.6	3,520.7
APPALACHIAN POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	247.4	239.3	256.1
INDIANA MICHIGAN POWER COMPANY
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	2,603.5	2,522.3	2,659.7
INDIANA MICHIGAN POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	66.2	57.8	69.6
OHIO POWER COMPANY
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	3,780.9	3,802.8	3,672.1
OHIO POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	22.7	31.1	18.8
PUBLIC SERVICE COMPANY OF OKLAHOMA
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	1,849.5	1,976.6	1,875.7
PUBLIC SERVICE COMPANY OF OKLAHOMA | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	6.9	1.2	2.9
SOUTHWESTERN ELECTRIC POWER COMPANY
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	2,043.3	2,192.1	2,283.2
SOUTHWESTERN ELECTRIC POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	62.1	46.8	53.9
Direct Sales to East Affiliates | AEP TEXAS INC. | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	0	0	0
Direct Sales to East Affiliates | AEP TRANSMISSION COMPANY, LLC | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	0	0	0
Direct Sales to East Affiliates | APPALACHIAN POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	159	158.7	169.7
Direct Sales to East Affiliates | INDIANA MICHIGAN POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	0	0	0
Direct Sales to East Affiliates | OHIO POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	0	0	0
Direct Sales to East Affiliates | PUBLIC SERVICE COMPANY OF OKLAHOMA | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	0	0	0
Direct Sales to East Affiliates | SOUTHWESTERN ELECTRIC POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	0	0	0
Direct Sales to West Affiliates | AEP TEXAS INC. | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers			0
Direct Sales to West Affiliates | AEP TRANSMISSION COMPANY, LLC | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers			0
Direct Sales to West Affiliates | APPALACHIAN POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers			0
Direct Sales to West Affiliates | INDIANA MICHIGAN POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers			0
Direct Sales to West Affiliates | OHIO POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers			0
Direct Sales to West Affiliates | PUBLIC SERVICE COMPANY OF OKLAHOMA | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers			0
Direct Sales to West Affiliates | SOUTHWESTERN ELECTRIC POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers			1.3
Transmission Revenues | AEP TEXAS INC. | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	0	0	0
Transmission Revenues | AEP TRANSMISSION COMPANY, LLC | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	1,491.1	1,304	1,276.4
Transmission Revenues | APPALACHIAN POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	78.8	70.9	77.5
Transmission Revenues | INDIANA MICHIGAN POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	(8.8)	(11.1)	7.7
Transmission Revenues | OHIO POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	(6.9)	3.2	(3.6)
Transmission Revenues | PUBLIC SERVICE COMPANY OF OKLAHOMA | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	0.1	0	0
Transmission Revenues | SOUTHWESTERN ELECTRIC POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	60.6	45.3	51.5
Barging, Urea Transloading and Other Transportation Services Revenues Affiliated | AEP TEXAS INC. | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers		0	0
Barging, Urea Transloading and Other Transportation Services Revenues Affiliated | AEP TRANSMISSION COMPANY, LLC | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers		0	0
Barging, Urea Transloading and Other Transportation Services Revenues Affiliated | APPALACHIAN POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers		0	0
Barging, Urea Transloading and Other Transportation Services Revenues Affiliated | INDIANA MICHIGAN POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers		59	54.1
Barging, Urea Transloading and Other Transportation Services Revenues Affiliated | OHIO POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers		0	0
Barging, Urea Transloading and Other Transportation Services Revenues Affiliated | PUBLIC SERVICE COMPANY OF OKLAHOMA | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers		0	0
Barging, Urea Transloading and Other Transportation Services Revenues Affiliated | SOUTHWESTERN ELECTRIC POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers		0	0
Other Revenues | AEP TEXAS INC. | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	5.4	4.9	3.5
Other Revenues | AEP TRANSMISSION COMPANY, LLC | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	21.2	13.8	7.4
Other Revenues | APPALACHIAN POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	9.6	9.7	8.9
Other Revenues | INDIANA MICHIGAN POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	75	9.9	7.8
Other Revenues | OHIO POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	29.6	27.9	22.4
Other Revenues | PUBLIC SERVICE COMPANY OF OKLAHOMA | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	6.8	1.2	2.9
Other Revenues | SOUTHWESTERN ELECTRIC POWER COMPANY | Affiliated Entity
Related Party Transaction [Line Items]
Total Revenues from Contracts with Customers	$ 1.5	$ 1.5	$ 1.1

VARIABLE INTEREST ENTITIES AN_3

VARIABLE INTEREST ENTITIES AND EQUITY METHOD INVESTMENTS - Narrative (Details) $ in Millions	12 Months Ended
	Dec. 31, 2024 USD ($) line MW	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2025 GW
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Accounts Payable - Affiliated Companies for collected reclamation costs that have been billed to SWEPCo	$ 2,637.6	$ 2,032.5
Securitized Assets	554.3	336.3
Construction work in progress	6,346.9	5,508
Investments in Equity Method Investees	1,055.9	1,073.6	$ 1,276.7
Equity Earnings (Loss) of Unconsolidated Subsidiaries	$ 93.7	58.5	(109.4)
Berkshire Hathaway
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Ownership percentage	50%
AEPTHCo
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Ownership percentage	50%
ETT
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Investments in Equity Method Investees	$ 897	811
Equity Earnings (Loss) of Unconsolidated Subsidiaries	86	74	74
SOUTHWESTERN ELECTRIC POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Accounts Payable - Affiliated Companies for collected reclamation costs that have been billed to SWEPCo	265.5	198.9
Securitized Assets	331.4	0
Construction work in progress	627.3	555.8
Equity Earnings (Loss) of Unconsolidated Subsidiaries	1.4	1.4	1.4
SOUTHWESTERN ELECTRIC POWER COMPANY | Affiliated Entity
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Accounts Payable - Affiliated Companies for collected reclamation costs that have been billed to SWEPCo	57.1	45.9
INDIANA MICHIGAN POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Accounts Payable - Affiliated Companies for collected reclamation costs that have been billed to SWEPCo	202.2	225.8
Construction work in progress	334.9	301.7
INDIANA MICHIGAN POWER COMPANY | Billings from AEP Generating Company
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Billings from VIE	209	181	242
INDIANA MICHIGAN POWER COMPANY | Carrying Amount in AEP Generating Company's Accounts Payable
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
As Reported on the Balance Sheet	14	15
INDIANA MICHIGAN POWER COMPANY | Affiliated Entity
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Accounts Payable - Affiliated Companies for collected reclamation costs that have been billed to SWEPCo	98.5	107.3
AEP TEXAS INC.
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Accounts Payable - Affiliated Companies for collected reclamation costs that have been billed to SWEPCo	366.2	192.3
Securitized Assets	116.7	202.9
Construction work in progress	1,118	904.6
AEP TEXAS INC. | Affiliated Entity
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Accounts Payable - Affiliated Companies for collected reclamation costs that have been billed to SWEPCo	34.9	27.7
APPALACHIAN POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Accounts Payable - Affiliated Companies for collected reclamation costs that have been billed to SWEPCo	427.2	280.4
Securitized Assets	106.2	133.4
Construction work in progress	742.6	709.2
APPALACHIAN POWER COMPANY | Affiliated Entity
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Accounts Payable - Affiliated Companies for collected reclamation costs that have been billed to SWEPCo	$ 205.9	121.3
Transource Energy
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Equity and voting ownership percentage	86.50%
AEGCo | Rockport Generating Plant
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Percent of Ownership	50%
Cleco Power, LLC
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Percentage of VIE sales of lignite produced	50%
OHIO POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Accounts Payable - Affiliated Companies for collected reclamation costs that have been billed to SWEPCo	$ 343.6	320.7
Construction work in progress	691.1	654
Equity Earnings (Loss) of Unconsolidated Subsidiaries	(1.1)	0	0.6
OHIO POWER COMPANY | Affiliated Entity
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Accounts Payable - Affiliated Companies for collected reclamation costs that have been billed to SWEPCo	$ 204.9	154.2
Variable Interest Entity, Primary Beneficiary
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Minimum percentage of equity AEP provides	5%
Percentage of short term borrowing needs in excess of third party financings	35%
Number of lines of insurance for protected cells | line	7
Insurance premium expense to protected cell	$ 37	34	31
Debt-to-total capitalization maximum	67.50%
Variable Interest Entity, Primary Beneficiary | SOUTHWESTERN ELECTRIC POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Guarantees of mine reclamation amount	$ 155
Estimated final cost mine reclamation	100
Amount recorded in ARO for final mine closure and reclamation costs	96
Amount collected through rider for final Mine closure and reclamation costs	97
Amount recorded in other noncurrent assets for final mine closure and reclamation costs	76
Securitized Assets	331
Variable Interest Entity, Primary Beneficiary | SOUTHWESTERN ELECTRIC POWER COMPANY | Affiliated Entity
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Accounts Payable - Affiliated Companies for collected reclamation costs that have been billed to SWEPCo	77
Variable Interest Entity, Primary Beneficiary | INDIANA MICHIGAN POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Capital lease payments made	$ 111	97	84
Capital lease term	54 months
Variable Interest Entity, Primary Beneficiary | AEP TEXAS INC. | AEP Texas Restoration Funding
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Securitized Assets	$ 117	139
Variable Interest Entity, Primary Beneficiary | AEP TEXAS INC. | AEP Texas Transition Funding
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Securitized Assets		64
Variable Interest Entity, Primary Beneficiary | APPALACHIAN POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Securitized Assets	$ 106	133
Variable Interest Entity, Primary Beneficiary | Great Plains Energy Inc.
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Equity and voting ownership percentage	13.50%
Variable Interest Entity, Primary Beneficiary | Current Liabilities | SOUTHWESTERN ELECTRIC POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Securitization Bonds	$ 23
Variable Interest Entity, Primary Beneficiary | Current Liabilities | AEP TEXAS INC. | AEP Texas Restoration Funding
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Securitization Bonds	24	24
Variable Interest Entity, Primary Beneficiary | Current Liabilities | AEP TEXAS INC. | AEP Texas Transition Funding
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Securitization Bonds		72
Variable Interest Entity, Primary Beneficiary | Current Liabilities | APPALACHIAN POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Securitization Bonds	28	27
Variable Interest Entity, Primary Beneficiary | Noncurrent Liabilities | SOUTHWESTERN ELECTRIC POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Securitization Bonds	309
Variable Interest Entity, Primary Beneficiary | Noncurrent Liabilities | AEP TEXAS INC. | AEP Texas Restoration Funding
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Securitization Bonds	102	126
Variable Interest Entity, Primary Beneficiary | Noncurrent Liabilities | APPALACHIAN POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Securitization Bonds	$ 91	120
Variable Interest Entity, Not Primary Beneficiary
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
AEP's ownership In OVEC	43.47%
Approximate OVEC generating capacity (MWs) | MW	2,400
Outstanding Indebtedness	$ 997	1,100
Variable Interest Entity, Not Primary Beneficiary | Parent
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
AEP's ownership In OVEC	39.17%
Variable Interest Entity, Not Primary Beneficiary | SOUTHWESTERN ELECTRIC POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Billings from VIE	$ 194.4	185.1	192.5
Percentage of VIE sales of lignite produced	50%
Percentage of VIE debt guaranteed	50%
Percentage of VIE management fee received	100%
Dividends	$ 1	1	25
Variable Interest Entity, Not Primary Beneficiary | INDIANA MICHIGAN POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Billings from VIE	$ 187.6	178.4	192.4
Power participation ratio	7.85%
Outstanding Indebtedness	$ 78	84
Variable Interest Entity, Not Primary Beneficiary | AEP TEXAS INC.
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Billings from VIE	242.6	228.5	236.8
Variable Interest Entity, Not Primary Beneficiary | APPALACHIAN POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Billings from VIE	$ 335.3	324.9	347.5
Power participation ratio	15.69%
Outstanding Indebtedness	$ 156	168
Variable Interest Entity, Not Primary Beneficiary | OHIO POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Billings from VIE	$ 283.4	269.5	$ 272.5
Power acquired, solid oxide fuel cells | MW	100
Construction work in progress	$ 457
Borrowings	$ 456
AEP's ownership In OVEC	4.30%
Power participation ratio	19.93%
Outstanding Indebtedness	$ 199	$ 213
Variable Interest Entity, Not Primary Beneficiary | OHIO POWER COMPANY | Forecast [Member]
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Power acquired, option, solid oxide fuel cells | GW				1

VARIABLE INTEREST ENTITIES AN_4

VARIABLE INTEREST ENTITIES AND EQUITY METHOD INVESTMENTS - VIE Consolidation (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
ASSETS
Current Assets	$ 5,788.8	$ 6,082.1
Net Property, Plant and Equipment	82,415.6	76,693.4
Other Noncurrent Assets	14,873.6	13,908.5
TOTAL ASSETS	103,078	96,684
LIABILITIES AND EQUITY
Current Liabilities	13,009.3	11,583.6
Noncurrent Liabilities	63,044.8	59,772
Equity	26,986.1	25,285.9	$ 24,122.4	$ 22,680.2
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	103,078	96,684
SOUTHWESTERN ELECTRIC POWER COMPANY
ASSETS
Current Assets	438	541.3
Net Property, Plant and Equipment	9,446.1	8,558.4
Other Noncurrent Assets	1,610.9	1,457.9
TOTAL ASSETS	11,495	10,557.6
LIABILITIES AND EQUITY
Current Liabilities	1,031.6	686.9
Noncurrent Liabilities	6,558.4	6,100.3
Equity	3,905	3,770.4	$ 3,674.8	$ 3,149.8
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	11,495	10,557.6
INDIANA MICHIGAN POWER COMPANY
ASSETS
Current Assets	543.6	528
Net Property, Plant and Equipment	7,679.3	7,629
Other Noncurrent Assets	5,312.6	4,651
TOTAL ASSETS	13,535.5	12,808
LIABILITIES AND EQUITY
Current Liabilities	1,071.2	830.2
Noncurrent Liabilities	9,067.8	8,837.6
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	13,535.5	12,808
AEP TEXAS INC.
ASSETS
Current Assets	500.4	520.1
Net Property, Plant and Equipment	14,043.5	12,774
Other Noncurrent Assets	655.7	696.6
TOTAL ASSETS	15,199.6	13,990.7
LIABILITIES AND EQUITY
Current Liabilities	1,407.1	749.4
Noncurrent Liabilities	8,907.9	8,445.2
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	15,199.6	13,990.7
APPALACHIAN POWER COMPANY
ASSETS
Current Assets	1,094.9	1,059
Net Property, Plant and Equipment	13,612.5	12,931.5
Other Noncurrent Assets	1,958.5	1,721.4
TOTAL ASSETS	16,665.9	15,711.9
LIABILITIES AND EQUITY
Current Liabilities	2,025.5	1,685.9
Noncurrent Liabilities	8,892.4	8,749.3
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	16,665.9	15,711.9
Variable Interest Entity, Primary Beneficiary | AEP Credit
ASSETS
Current Assets	1,118.3	1,208.8
Net Property, Plant and Equipment	0	0
Other Noncurrent Assets	10.5	9.6
TOTAL ASSETS	1,128.8	1,218.4
LIABILITIES AND EQUITY
Current Liabilities	1,068.8	1,155
Noncurrent Liabilities	1	0.9
Equity	59	62.5
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	1,128.8	1,218.4
Variable Interest Entity, Primary Beneficiary | Protected Cell of EIS
ASSETS
Current Assets	218.5	205.3
Net Property, Plant and Equipment	0	0
Other Noncurrent Assets	0	0
TOTAL ASSETS	218.5	205.3
LIABILITIES AND EQUITY
Current Liabilities	54.7	49.2
Noncurrent Liabilities	96	91.7
Equity	67.8	64.4
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	218.5	205.3
Variable Interest Entity, Primary Beneficiary | Transource Energy
ASSETS
Current Assets	40.2	36.9
Net Property, Plant and Equipment	598.3	533.4
Other Noncurrent Assets	3.5	5.1
TOTAL ASSETS	642	575.4
LIABILITIES AND EQUITY
Current Liabilities	57.2	45.3
Noncurrent Liabilities	274.3	241.5
Equity	310.5	288.6
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	642	575.4
Variable Interest Entity, Primary Beneficiary | SOUTHWESTERN ELECTRIC POWER COMPANY | Sabine
ASSETS
Current Assets	6	4.2
Net Property, Plant and Equipment	0	0
Other Noncurrent Assets	110.8	150.7
TOTAL ASSETS	116.8	154.9
LIABILITIES AND EQUITY
Current Liabilities	20.1	19.9
Noncurrent Liabilities	96.3	134.8
Equity	0.4	0.2
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	116.8	154.9
Variable Interest Entity, Primary Beneficiary | SOUTHWESTERN ELECTRIC POWER COMPANY | SWEPCo Storm Recovery Funding
ASSETS
Current Assets	3.4
Net Property, Plant and Equipment	0
Other Noncurrent Assets	331.4
TOTAL ASSETS	334.8
LIABILITIES AND EQUITY
Current Liabilities	24.4
Noncurrent Liabilities	308.7
Equity	1.7
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	334.8
Variable Interest Entity, Primary Beneficiary | INDIANA MICHIGAN POWER COMPANY | DCC Fuel
ASSETS
Current Assets	79.3	81.9
Net Property, Plant and Equipment	132.3	153.8
Other Noncurrent Assets	63.6	81.7
TOTAL ASSETS	275.2	317.4
LIABILITIES AND EQUITY
Current Liabilities	79.2	81.7
Noncurrent Liabilities	196	235.7
Equity	0	0
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	275.2	317.4
Variable Interest Entity, Primary Beneficiary | AEP TEXAS INC. | AEP Texas Transition Funding
ASSETS
Current Assets		25.5
Net Property, Plant and Equipment		0
Other Noncurrent Assets		71.4
TOTAL ASSETS		96.9
LIABILITIES AND EQUITY
Current Liabilities		75.5
Noncurrent Liabilities		17
Equity		4.4
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY		96.9
Variable Interest Entity, Primary Beneficiary | AEP TEXAS INC. | AEP Texas Restoration Funding
ASSETS
Current Assets	21.3	27.5
Net Property, Plant and Equipment	0	0
Other Noncurrent Assets	121.9	145.6
TOTAL ASSETS	143.2	173.1
LIABILITIES AND EQUITY
Current Liabilities	30.7	36.8
Noncurrent Liabilities	111.2	135.1
Equity	1.3	1.2
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	143.2	173.1
Variable Interest Entity, Primary Beneficiary | AEP TEXAS INC. | Other Noncurrent Assets | AEP Texas Transition Funding
LIABILITIES AND EQUITY
Intercompany item eliminated in consolidation	5	8
Variable Interest Entity, Primary Beneficiary | AEP TEXAS INC. | Other Noncurrent Assets | AEP Texas Restoration Funding
LIABILITIES AND EQUITY
Intercompany item eliminated in consolidation	1	6
Variable Interest Entity, Primary Beneficiary | APPALACHIAN POWER COMPANY | APCo Appalachian Consumer Rate Relief Funding
ASSETS
Current Assets	14.2	13.3
Net Property, Plant and Equipment	0	0
Other Noncurrent Assets	109.6	138.2
TOTAL ASSETS	123.8	151.5
LIABILITIES AND EQUITY
Current Liabilities	30.5	29.9
Noncurrent Liabilities	91.4	119.7
Equity	1.9	1.9
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	$ 123.8	151.5
Variable Interest Entity, Primary Beneficiary | APPALACHIAN POWER COMPANY | Other Noncurrent Assets | APCo Appalachian Consumer Rate Relief Funding
LIABILITIES AND EQUITY
Intercompany item eliminated in consolidation		$ 2

VARIABLE INTEREST ENTITIES AN_5

VARIABLE INTEREST ENTITIES AND EQUITY METHOD INVESTMENTS - Billings (Details) - Variable Interest Entity, Not Primary Beneficiary - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
AEP TEXAS INC.
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Billings from VIE	$ 242.6	$ 228.5	$ 236.8
AEP TRANSMISSION COMPANY, LLC
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Billings from VIE	289.7	269.9	286.6
APPALACHIAN POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Billings from VIE	335.3	324.9	347.5
INDIANA MICHIGAN POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Billings from VIE	187.6	178.4	192.4
OHIO POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Billings from VIE	283.4	269.5	272.5
PUBLIC SERVICE COMPANY OF OKLAHOMA
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Billings from VIE	157.4	138.6	142.3
SOUTHWESTERN ELECTRIC POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Billings from VIE	$ 194.4	$ 185.1	$ 192.5

VARIABLE INTEREST ENTITIES AN_6

VARIABLE INTEREST ENTITIES AND EQUITY METHOD INVESTMENTS - Investments (Details) - Variable Interest Entity, Not Primary Beneficiary - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Outstanding Indebtedness	$ 997	$ 1,100
APPALACHIAN POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Outstanding Indebtedness	156	168
INDIANA MICHIGAN POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Outstanding Indebtedness	78	84
OHIO POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Outstanding Indebtedness	199	213
Billings from AEP Service Corporation | AEP TEXAS INC.
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
As Reported on the Balance Sheet	26.1	15.1
Maximum Exposure	26.1	15.1
Billings from AEP Service Corporation | AEP TRANSMISSION COMPANY, LLC
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
As Reported on the Balance Sheet	29.3	17.9
Maximum Exposure	29.3	17.9
Billings from AEP Service Corporation | APPALACHIAN POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
As Reported on the Balance Sheet	36.4	21.1
Maximum Exposure	36.4	21.1
Billings from AEP Service Corporation | INDIANA MICHIGAN POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
As Reported on the Balance Sheet	25.1	14.3
Maximum Exposure	25.1	14.3
Billings from AEP Service Corporation | OHIO POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
As Reported on the Balance Sheet	34.5	19
Maximum Exposure	34.5	19
Billings from AEP Service Corporation | PUBLIC SERVICE COMPANY OF OKLAHOMA
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
As Reported on the Balance Sheet	19.2	10.6
Maximum Exposure	19.2	10.6
Billings from AEP Service Corporation | SOUTHWESTERN ELECTRIC POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
As Reported on the Balance Sheet	22	12.7
Maximum Exposure	22	12.7
Capital Contribution From Parent
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
As Reported on the Balance Sheet	4.4	4.4
Maximum Exposure	4.4	4.4
Capital Contribution From Parent | SOUTHWESTERN ELECTRIC POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
As Reported on the Balance Sheet	7.6	7.6
Maximum Exposure	7.6	7.6
Retained Earnings | SOUTHWESTERN ELECTRIC POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
As Reported on the Balance Sheet	0.3	0.4
Maximum Exposure	0.3	0.4
SWEPCo's Share of Obligations | SOUTHWESTERN ELECTRIC POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
As Reported on the Balance Sheet	0	0
Maximum Exposure	15.6	19.2
Total Investment
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
As Reported on the Balance Sheet	4.4	4.4
Maximum Exposure	437.6	469.7
Total Investment | SOUTHWESTERN ELECTRIC POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
As Reported on the Balance Sheet	7.9	8
Maximum Exposure	23.5	27.2
AEP's Ratio of OVEC Debt
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
As Reported on the Balance Sheet	0	0
Maximum Exposure	$ 433.2	$ 465.3

VARIABLE INTEREST ENTITIES AN_7

VARIABLE INTEREST ENTITIES AND EQUITY METHOD INVESTMENTS - Power Purchased (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
APPALACHIAN POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Amount of power purchased from OVEC	$ 133.6	$ 121.8	$ 119.3
INDIANA MICHIGAN POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Amount of power purchased from OVEC	66.8	60.9	59.7
OHIO POWER COMPANY
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Amount of power purchased from OVEC	$ 169.7	$ 154.7	$ 151.8

PROPERTY, PLANT, AND EQUIPMEN_2

PROPERTY, PLANT, AND EQUIPMENT - Total Plant Balances (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Property, Plant and Equipment [Line Items]
Generation	$ 24,694.5	$ 23,862.7
Transmission	38,871.9	35,903.6
Distribution	31,061.9	28,989.9
Other	6,544.9	5,986.1
CWIP	6,321.5	5,480.6
Less: Accumulated Depreciation	25,794	24,093.8
Total Regulated Property, Plant and Equipment - Net	81,700.7	76,129.1
Nonregulated Property, Plant and Equipment - Net	714.9	564.3
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	82,415.6	76,693.4
AEP TEXAS INC.
Property, Plant and Equipment [Line Items]
Generation	0	0
Transmission	7,546.2	6,812.6
Distribution	6,250.5	5,798.8
Other	1,172.9	1,142.9
CWIP	1,118	904.6
Less: Accumulated Depreciation	2,045.7	1,886.7
Total Regulated Property, Plant and Equipment - Net	14,041.9	12,772.2
Nonregulated Property, Plant and Equipment - Net	1.6	1.8
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	14,043.5	12,774
AEP TRANSMISSION COMPANY, LLC
Property, Plant and Equipment [Line Items]
Generation	0	0
Transmission	14,913.4	13,723.9
Distribution	0	0
Other	515.9	501.2
CWIP	1,965.4	1,563.7
Less: Accumulated Depreciation	1,578.5	1,291.4
Total Regulated Property, Plant and Equipment - Net	15,816.2	14,497.4
Nonregulated Property, Plant and Equipment - Net	0.3	0.3
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	15,816.5	14,497.7
APPALACHIAN POWER COMPANY
Property, Plant and Equipment [Line Items]
Generation	7,272.6	7,041.3
Transmission	5,001.5	4,711.8
Distribution	5,568.5	5,176.6
Other	1,023.9	943.7
CWIP	742.6	709.2
Less: Accumulated Depreciation	6,030.9	5,684
Total Regulated Property, Plant and Equipment - Net	13,578.2	12,898.6
Nonregulated Property, Plant and Equipment - Net	34.3	32.9
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	13,612.5	12,931.5
INDIANA MICHIGAN POWER COMPANY
Property, Plant and Equipment [Line Items]
Generation	5,438.5	5,588.7
Transmission	1,957.8	1,906.4
Distribution	3,535	3,254
Other	948.3	856.8
CWIP	330.1	294.1
Less: Accumulated Depreciation	4,607	4,353.7
Total Regulated Property, Plant and Equipment - Net	7,602.7	7,546.3
Nonregulated Property, Plant and Equipment - Net	76.6	82.7
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	7,679.3	7,629
OHIO POWER COMPANY
Property, Plant and Equipment [Line Items]
Generation	0	0
Transmission	3,663.9	3,395.1
Distribution	7,244	6,839.4
Other	1,245.3	1,114.4
CWIP	691.1	654
Less: Accumulated Depreciation	2,883	2,712.7
Total Regulated Property, Plant and Equipment - Net	9,961.3	9,290.2
Nonregulated Property, Plant and Equipment - Net	9.8	9.7
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	9,971.1	9,299.9
PUBLIC SERVICE COMPANY OF OKLAHOMA
Property, Plant and Equipment [Line Items]
Generation	2,772.4	2,695.5
Transmission	1,345.3	1,228.3
Distribution	3,698.8	3,450.8
Other	546.8	502.7
CWIP	378.8	313.7
Less: Accumulated Depreciation	2,214.7	2,083.6
Total Regulated Property, Plant and Equipment - Net	6,527.4	6,107.4
Nonregulated Property, Plant and Equipment - Net	4.9	4.9
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	6,532.3	6,112.3
SOUTHWESTERN ELECTRIC POWER COMPANY
Property, Plant and Equipment [Line Items]
Generation	5,287.5	4,790.7
Transmission	2,863.8	2,660.6
Distribution	3,007.1	2,824.1
Other	682.7	544.1
CWIP	627.3	555.8
Less: Accumulated Depreciation	3,048.5	2,840.8
Total Regulated Property, Plant and Equipment - Net	9,419.9	8,534.5
Nonregulated Property, Plant and Equipment - Net	26.2	23.9
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	$ 9,446.1	$ 8,558.4

PROPERTY, PLANT, AND EQUIPMEN_3

PROPERTY, PLANT, AND EQUIPMENT - Depreciation Rates and Useful Lives (Details)	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Unregulated Operation | INDIANA MICHIGAN POWER COMPANY
Property, Plant and Equipment [Line Items]
Generation	39 years
Minimum | Regulated Operation
Property, Plant and Equipment [Line Items]
Generation	20 years	20 years	20 years
Transmission	15 years	15 years	24 years
Distribution	7 years	7 years	7 years
Other	5 years	5 years	5 years
Minimum | Regulated Operation | AEP TEXAS INC.
Property, Plant and Equipment [Line Items]
Transmission	50 years	50 years	50 years
Distribution	15 years	7 years	7 years
Other	5 years	5 years	5 years
Minimum | Regulated Operation | AEP TRANSMISSION COMPANY, LLC
Property, Plant and Equipment [Line Items]
Transmission	24 years	24 years	24 years
Other	5 years	5 years	5 years
Minimum | Regulated Operation | APPALACHIAN POWER COMPANY
Property, Plant and Equipment [Line Items]
Generation	35 years	35 years	35 years
Transmission	15 years	15 years	24 years
Distribution	12 years	12 years	12 years
Other	5 years	5 years	5 years
Minimum | Regulated Operation | INDIANA MICHIGAN POWER COMPANY
Property, Plant and Equipment [Line Items]
Generation	20 years	20 years	20 years
Transmission	44 years	44 years	44 years
Distribution	15 years	14 years	14 years
Other	5 years	5 years	5 years
Minimum | Regulated Operation | OHIO POWER COMPANY
Property, Plant and Equipment [Line Items]
Transmission	39 years	39 years	39 years
Distribution	11 years	11 years	11 years
Other	5 years	5 years	5 years
Minimum | Regulated Operation | PUBLIC SERVICE COMPANY OF OKLAHOMA
Property, Plant and Equipment [Line Items]
Generation	30 years	25 years	30 years
Transmission	41 years	41 years	42 years
Distribution	15 years	15 years	15 years
Other	5 years	5 years	5 years
Minimum | Regulated Operation | SOUTHWESTERN ELECTRIC POWER COMPANY
Property, Plant and Equipment [Line Items]
Generation	30 years	30 years	30 years
Transmission	46 years	46 years	44 years
Distribution	7 years	7 years	15 years
Other	5 years	5 years	5 years
Minimum | Unregulated Operation
Property, Plant and Equipment [Line Items]
Generation	39 years	10 years	3 years
Transmission		62 years	10 years
Other	5 years	5 years	5 years
Maximum | Regulated Operation
Property, Plant and Equipment [Line Items]
Generation	162 years	162 years	132 years
Transmission	79 years	78 years	75 years
Distribution	85 years	85 years	78 years
Other	75 years	75 years	75 years
Maximum | Regulated Operation | AEP TEXAS INC.
Property, Plant and Equipment [Line Items]
Transmission	79 years	75 years	75 years
Distribution	74 years	70 years	70 years
Other	54 years	50 years	50 years
Maximum | Regulated Operation | AEP TRANSMISSION COMPANY, LLC
Property, Plant and Equipment [Line Items]
Transmission	78 years	78 years	75 years
Other	58 years	58 years	56 years
Maximum | Regulated Operation | APPALACHIAN POWER COMPANY
Property, Plant and Equipment [Line Items]
Generation	162 years	162 years	118 years
Transmission	78 years	78 years	75 years
Distribution	60 years	60 years	57 years
Other	55 years	55 years	55 years
Maximum | Regulated Operation | INDIANA MICHIGAN POWER COMPANY
Property, Plant and Equipment [Line Items]
Generation	132 years	132 years	132 years
Transmission	67 years	67 years	67 years
Distribution	76 years	71 years	71 years
Other	45 years	45 years	45 years
Maximum | Regulated Operation | OHIO POWER COMPANY
Property, Plant and Equipment [Line Items]
Transmission	60 years	60 years	60 years
Distribution	70 years	70 years	70 years
Other	50 years	50 years	50 years
Maximum | Regulated Operation | PUBLIC SERVICE COMPANY OF OKLAHOMA
Property, Plant and Equipment [Line Items]
Generation	78 years	75 years	75 years
Transmission	75 years	75 years	75 years
Distribution	85 years	85 years	78 years
Other	58 years	58 years	56 years
Maximum | Regulated Operation | SOUTHWESTERN ELECTRIC POWER COMPANY
Property, Plant and Equipment [Line Items]
Generation	65 years	65 years	65 years
Transmission	70 years	70 years	70 years
Distribution	75 years	75 years	75 years
Other	58 years	58 years	57 years
Maximum | Unregulated Operation
Property, Plant and Equipment [Line Items]
Generation	61 years	61 years	61 years
Transmission			62 years
Other	35 years	35 years	35 years
Generation | Regulated Operation | APPALACHIAN POWER COMPANY
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	3.20%	3.30%	3.60%
Generation | Regulated Operation | INDIANA MICHIGAN POWER COMPANY
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	4.90%	4.70%	4.90%
Generation | Regulated Operation | PUBLIC SERVICE COMPANY OF OKLAHOMA
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	3.30%	3%	3.10%
Generation | Regulated Operation | SOUTHWESTERN ELECTRIC POWER COMPANY
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	3.70%	2.90%	2.70%
Generation | Unregulated Operation | INDIANA MICHIGAN POWER COMPANY
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	1.80%
Generation | Minimum | Regulated Operation
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	2.70%	2.70%	2.70%
Generation | Minimum | Unregulated Operation
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	1.80%	4.80%	3.80%
Generation | Maximum | Regulated Operation
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	4.90%	4.70%	7.60%
Generation | Maximum | Unregulated Operation
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	6%	6.70%	8.70%
Transmission | Regulated Operation | AEP TEXAS INC.
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	2.20%	2.20%	2.20%
Transmission | Regulated Operation | AEP TRANSMISSION COMPANY, LLC
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	2.70%	2.60%	2.60%
Transmission | Regulated Operation | APPALACHIAN POWER COMPANY
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	2.30%	2.30%	2.20%
Transmission | Regulated Operation | INDIANA MICHIGAN POWER COMPANY
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	2.60%	2.50%	2.50%
Transmission | Regulated Operation | OHIO POWER COMPANY
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	2.30%	2.30%	2.30%
Transmission | Regulated Operation | PUBLIC SERVICE COMPANY OF OKLAHOMA
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	2.60%	2.60%	2.50%
Transmission | Regulated Operation | SOUTHWESTERN ELECTRIC POWER COMPANY
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	2.20%	2.20%	2.30%
Transmission | Unregulated Operation
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges		2.50%	2.80%
Transmission | Minimum | Regulated Operation
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	2.10%	2%	2%
Transmission | Maximum | Regulated Operation
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	2.70%	2.70%	2.70%
Distribution | Regulated Operation | AEP TEXAS INC.
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	2.80%	2.90%	2.90%
Distribution | Regulated Operation | APPALACHIAN POWER COMPANY
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	3.50%	3.60%	3.60%
Distribution | Regulated Operation | INDIANA MICHIGAN POWER COMPANY
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	2.80%	2.90%	3.10%
Distribution | Regulated Operation | OHIO POWER COMPANY
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	3.10%	3.10%	2.70%
Distribution | Regulated Operation | PUBLIC SERVICE COMPANY OF OKLAHOMA
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	2.80%	2.90%	2.90%
Distribution | Regulated Operation | SOUTHWESTERN ELECTRIC POWER COMPANY
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	2.90%	2.90%	2.90%
Distribution | Minimum | Regulated Operation
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	2.80%	2.90%	2.70%
Distribution | Maximum | Regulated Operation
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	3.50%	3.60%	3.60%
Other | Regulated Operation | AEP TEXAS INC.
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	5.90%	6%	6.20%
Other | Regulated Operation | AEP TRANSMISSION COMPANY, LLC
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	7.10%	7%	6.60%
Other | Regulated Operation | APPALACHIAN POWER COMPANY
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	6.80%	7.40%	7.30%
Other | Regulated Operation | INDIANA MICHIGAN POWER COMPANY
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	8.90%	9.10%	10.10%
Other | Regulated Operation | OHIO POWER COMPANY
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	5.90%	6.40%	6.10%
Other | Regulated Operation | PUBLIC SERVICE COMPANY OF OKLAHOMA
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	6.60%	6.80%	6.80%
Other | Regulated Operation | SOUTHWESTERN ELECTRIC POWER COMPANY
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	6.70%	8.50%	9%
Other | Unregulated Operation
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	9.70%	10.60%	25.20%
Other | Minimum | Regulated Operation
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	3%	3.80%	3.10%
Other | Maximum | Regulated Operation
Property, Plant and Equipment [Line Items]
Annual Composite Depreciation Rate Ranges	8.90%	9.10%	14.40%

PROPERTY, PLANT, AND EQUIPMEN_4

PROPERTY, PLANT, AND EQUIPMENT - Narrative (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended	12 Months Ended
	Dec. 31, 2024	Jun. 30, 2024	Dec. 31, 2024	Dec. 31, 2023
Property, Plant and Equipment [Line Items]
ARO liabilities			$ 612.4	$ 38.9
Revision of estimate			(69.6)	63
INDIANA MICHIGAN POWER COMPANY
Property, Plant and Equipment [Line Items]
ARO liabilities			85.7	4.8
Revision of estimate			(175.9)	2
Settlement of decommissioning liabilities	$ 4,030		4,030	3,510
Cook Nuclear Plant | INDIANA MICHIGAN POWER COMPANY
Property, Plant and Equipment [Line Items]
Revision of reclamation costs	176
ARO decommissioning liability	$ 1,970		$ 1,970	$ 2,110
CCR Rule Revision
Property, Plant and Equipment [Line Items]
ARO liabilities		$ 602
Revision of estimate		$ 72

PROPERTY, PLANT, AND EQUIPMEN_5

PROPERTY, PLANT, AND EQUIPMENT - ARO Reconciliation (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	$ 3,031.2	$ 2,943.6
Accretion Expense	140.1	116.3
Liabilities Incurred	612.4	38.9
Liabilities Settled	(102.4)	(130.6)
Revisions in Cash Flow Estimates	(69.6)	63
Ending Balance	3,611.7	3,031.2
AEP TEXAS INC.
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	4.5	4.5
Accretion Expense	0.2	0.2
Liabilities Incurred	0	0
Liabilities Settled	(0.8)	(0.3)
Revisions in Cash Flow Estimates	0	0.1
Ending Balance	3.9	4.5
APPALACHIAN POWER COMPANY
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	464	427.7
Accretion Expense	27.7	16.8
Liabilities Incurred	247.1	16.1
Liabilities Settled	(18.1)	(23.1)
Revisions in Cash Flow Estimates	81	26.5
Ending Balance	801.7	464
INDIANA MICHIGAN POWER COMPANY
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	2,106	2,028.1
Accretion Expense	80.2	74.8
Liabilities Incurred	85.7	4.8
Liabilities Settled	(2.2)	(3.7)
Revisions in Cash Flow Estimates	(175.9)	2
Ending Balance	2,093.8	2,106
OHIO POWER COMPANY
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	2.1	5
Accretion Expense	1.4	0.2
Liabilities Incurred	52.9	0
Liabilities Settled	(0.1)	(3.1)
Revisions in Cash Flow Estimates	0	0
Ending Balance	56.3	2.1
PUBLIC SERVICE COMPANY OF OKLAHOMA
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	84.2	75.7
Accretion Expense	5.8	4.7
Liabilities Incurred	33.7	5.8
Liabilities Settled	(1.9)	(1.2)
Revisions in Cash Flow Estimates	0	(0.8)
Ending Balance	121.8	84.2
SOUTHWESTERN ELECTRIC POWER COMPANY
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	281.6	280.9
Accretion Expense	16.2	13.7
Liabilities Incurred	30.2	7.5
Liabilities Settled	(69.2)	(55)
Revisions in Cash Flow Estimates	19.9	34.5
Ending Balance	$ 278.7	$ 281.6

PROPERTY, PLANT, AND EQUIPMEN_6

PROPERTY, PLANT, AND EQUIPMENT - Allowance for Equity Funds and Borrowed Funds Used During Construction (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Property, Plant and Equipment [Line Items]
Allowance for equity funds used during construction	$ 211	$ 174.9	$ 133.7
Borrowed funds used during construction	129.8	117.3	63
AEP TEXAS INC.
Property, Plant and Equipment [Line Items]
Allowance for equity funds used during construction	45.9	28.4	19.7
Borrowed funds used during construction	30.7	23.4	11.5
AEP TRANSMISSION COMPANY, LLC
Property, Plant and Equipment [Line Items]
Allowance for equity funds used during construction	89.4	83.2	70.7
Borrowed funds used during construction	33.7	31.4	22.4
APPALACHIAN POWER COMPANY
Property, Plant and Equipment [Line Items]
Allowance for equity funds used during construction	16.1	11.9	11.7
Borrowed funds used during construction	10.5	14.1	6.5
INDIANA MICHIGAN POWER COMPANY
Property, Plant and Equipment [Line Items]
Allowance for equity funds used during construction	13.3	10.9	9.8
Borrowed funds used during construction	9.2	7.7	5.7
OHIO POWER COMPANY
Property, Plant and Equipment [Line Items]
Allowance for equity funds used during construction	23.4	17.1	13.9
Borrowed funds used during construction	12.8	14	6.7
PUBLIC SERVICE COMPANY OF OKLAHOMA
Property, Plant and Equipment [Line Items]
Allowance for equity funds used during construction	7.4	8.4	1.5
Borrowed funds used during construction	9.7	5.2	2.7
SOUTHWESTERN ELECTRIC POWER COMPANY
Property, Plant and Equipment [Line Items]
Allowance for equity funds used during construction	13.5	11.5	4.9
Borrowed funds used during construction	$ 15.1	$ 9.8	$ 4.3

PROPERTY, PLANT, AND EQUIPMEN_7

PROPERTY, PLANT, AND EQUIPMENT - Proportionate Share of Operating Costs (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Property, Plant and Equipment [Line Items]
Utility Plant in Service	$ 1,921.1	$ 1,906.8
Construction Work in Progress	4.6	11.7
Accumulated Depreciation	539	490.8
SOUTHWESTERN ELECTRIC POWER COMPANY
Property, Plant and Equipment [Line Items]
Utility Plant in Service	3,014.6	2,993.1
Construction Work in Progress	5.8	14.6
Accumulated Depreciation	$ 637.1	$ 558.7
Flint Creek Generating Station (Unit No. 1) | Coal
Property, Plant and Equipment [Line Items]
Percent of Ownership	50%	50%
Utility Plant in Service	$ 404.1	$ 402.8
Construction Work in Progress	3.4	1.6
Accumulated Depreciation	$ 188.8	$ 167.5
Flint Creek Generating Station (Unit No. 1) | Coal | SOUTHWESTERN ELECTRIC POWER COMPANY
Property, Plant and Equipment [Line Items]
Percent of Ownership	50%	50%
Utility Plant in Service	$ 404.1	$ 402.8
Construction Work in Progress	3.4	1.6
Accumulated Depreciation	$ 188.8	$ 167.5
Turk Generating Plant | Coal
Property, Plant and Equipment [Line Items]
Percent of Ownership	73.30%	73.30%
Utility Plant in Service	$ 1,517	$ 1,504
Construction Work in Progress	1.2	10.1
Accumulated Depreciation	$ 350.2	$ 323.3
Turk Generating Plant | Coal | SOUTHWESTERN ELECTRIC POWER COMPANY
Property, Plant and Equipment [Line Items]
Percent of Ownership	73.30%	73.30%
Utility Plant in Service	$ 1,517	$ 1,504
Construction Work in Progress	1.2	10.1
Accumulated Depreciation	$ 350.2	$ 323.3
Rockport Generating Plant | AEGCo
Property, Plant and Equipment [Line Items]
Percent of Ownership	50%
Rockport Generating Plant | Coal | INDIANA MICHIGAN POWER COMPANY
Property, Plant and Equipment [Line Items]
Percent of Ownership	50%	50%
Utility Plant in Service	$ 1,345	$ 1,341.4
Construction Work in Progress	10.9	7.9
Accumulated Depreciation	$ 1,181.8	$ 1,018.9
North Central Wind Energy Facilities | PUBLIC SERVICE COMPANY OF OKLAHOMA
Property, Plant and Equipment [Line Items]
Percent of Ownership	45.50%
North Central Wind Energy Facilities | SOUTHWESTERN ELECTRIC POWER COMPANY
Property, Plant and Equipment [Line Items]
Percent of Ownership	54.50%
North Central Wind Energy Facilities | Wind | PUBLIC SERVICE COMPANY OF OKLAHOMA
Property, Plant and Equipment [Line Items]
Percent of Ownership	45.50%	45.50%
Utility Plant in Service	$ 912.3	$ 906.3
Construction Work in Progress	1	2.4
Accumulated Depreciation	$ 77.6	$ 54.1
North Central Wind Energy Facilities | Wind | SOUTHWESTERN ELECTRIC POWER COMPANY
Property, Plant and Equipment [Line Items]
Percent of Ownership	54.50%	54.50%
Utility Plant in Service	$ 1,093.5	$ 1,086.3
Construction Work in Progress	1.2	2.9
Accumulated Depreciation	$ 98.1	$ 67.9

REVENUE FROM CONTRACTS WITH C_3

REVENUE FROM CONTRACTS WITH CUSTOMERS - Disaggregation of Revenue (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	$ 19,969.7	$ 19,454.8	$ 19,391.7
TOTAL REVENUES	19,721.3	18,982.3	19,639.5
Total Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	15,077.6	14,947.2	14,453.1
Residential Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	7,317.6	7,088.4	6,995.9
Commercial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	4,298.8	4,176	3,941.7
Industrial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	3,173.3	3,389.4	3,254.2
Other Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	287.9	293.4	261.3
Total Wholesale and Competitive Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	4,466.2	4,078.5	4,440.8
Generation Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	851	773.8	1,229.5
Transmission Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1,611	1,476.2	1,380.2
Renewable Generation Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	18.8	73.9	121.1
Retail, Trading and Marketing Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1,985.4	1,754.6	1,710
Other Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	425.9	429.1	497.8
TOTAL REVENUES	483	458.1	408.2
Total Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	(248.4)	(472.5)	247.8
Alternative Revenue Programs
Disaggregation of Revenue [Line Items]
Total Other Revenues	(79.1)	(117.1)	(112.5)
Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	(169.3)	(355.4)	360.3
AEP TEXAS INC.
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	2,080.8	1,906.1	1,848
TOTAL REVENUES	2,079.9	1,901.9	1,846.8
AEP TEXAS INC. | Total Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1,371.8	1,251.2	1,259.6
AEP TEXAS INC. | Residential Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	724.8	655.5	667.2
AEP TEXAS INC. | Commercial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	466.6	415.2	417.5
AEP TEXAS INC. | Industrial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	141.5	145	139.6
AEP TEXAS INC. | Other Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	38.9	35.5	35.3
AEP TEXAS INC. | Total Wholesale and Competitive Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	673.2	619	563.8
AEP TEXAS INC. | Generation Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
AEP TEXAS INC. | Transmission Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	673.2	619	563.8
AEP TEXAS INC. | Other Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	35.8	35.9	24.6
TOTAL REVENUES	3.7	5	3.6
AEP TEXAS INC. | Total Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	(0.9)	(4.2)	(1.2)
AEP TEXAS INC. | Alternative Revenue Programs
Disaggregation of Revenue [Line Items]
Total Other Revenues	(0.9)	(4.2)	(1.2)
AEP TEXAS INC. | Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	0	0	0
AEP TRANSMISSION COMPANY, LLC
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1,950.5	1,720.6	1,651.7
TOTAL REVENUES	1,890.9	1,672	1,624.5
AEP TRANSMISSION COMPANY, LLC | Total Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
AEP TRANSMISSION COMPANY, LLC | Residential Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
AEP TRANSMISSION COMPANY, LLC | Commercial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
AEP TRANSMISSION COMPANY, LLC | Industrial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
AEP TRANSMISSION COMPANY, LLC | Other Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
AEP TRANSMISSION COMPANY, LLC | Total Wholesale and Competitive Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1,924.6	1,703.9	1,643.5
AEP TRANSMISSION COMPANY, LLC | Generation Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
AEP TRANSMISSION COMPANY, LLC | Transmission Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1,924.6	1,703.9	1,643.5
AEP TRANSMISSION COMPANY, LLC | Transmission Revenues | Related Party
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1,600	1,400	1,300
AEP TRANSMISSION COMPANY, LLC | Other Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	25.9	16.7	8.2
AEP TRANSMISSION COMPANY, LLC | Total Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	(59.6)	(48.6)	(27.2)
AEP TRANSMISSION COMPANY, LLC | Alternative Revenue Programs
Disaggregation of Revenue [Line Items]
Total Other Revenues	(59.6)	(48.6)	(27.2)
AEP TRANSMISSION COMPANY, LLC | Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	0	0	0
APPALACHIAN POWER COMPANY
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	4,038.8	3,740.6	3,520.7
TOTAL REVENUES	4,032.6	3,720.7	3,519.9
APPALACHIAN POWER COMPANY | Total Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	3,462.5	3,197.2	2,953.2
APPALACHIAN POWER COMPANY | Residential Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1,772	1,612.9	1,558.7
APPALACHIAN POWER COMPANY | Commercial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	764.4	699.6	643.4
APPALACHIAN POWER COMPANY | Industrial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	813.1	778.4	664
APPALACHIAN POWER COMPANY | Other Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	113	106.3	87.1
APPALACHIAN POWER COMPANY | Total Wholesale and Competitive Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	489.1	469.2	466.9
APPALACHIAN POWER COMPANY | Generation Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	304.5	288.2	299.9
APPALACHIAN POWER COMPANY | Generation Revenues | Related Party
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	159	159	170
APPALACHIAN POWER COMPANY | Transmission Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	184.6	181	167
APPALACHIAN POWER COMPANY | Transmission Revenues | Related Party
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	87	93	78
APPALACHIAN POWER COMPANY | Other Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	87.2	74.2	100.6
TOTAL REVENUES	15.9	17.3	18.3
APPALACHIAN POWER COMPANY | Total Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	(6.2)	(19.9)	(0.8)
APPALACHIAN POWER COMPANY | Alternative Revenue Programs
Disaggregation of Revenue [Line Items]
Total Other Revenues	(6.4)	(20.1)	(1.3)
APPALACHIAN POWER COMPANY | Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	0.2	0.2	0.5
INDIANA MICHIGAN POWER COMPANY
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	2,603.5	2,522.3	2,659.7
TOTAL REVENUES	2,572	2,535.9	2,669.6
INDIANA MICHIGAN POWER COMPANY | Total Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	2,053	2,036.3	2,010.5
INDIANA MICHIGAN POWER COMPANY | Residential Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	847.2	841.9	852.4
INDIANA MICHIGAN POWER COMPANY | Commercial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	605.1	575.2	550.2
INDIANA MICHIGAN POWER COMPANY | Industrial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	595.6	614.2	602.9
INDIANA MICHIGAN POWER COMPANY | Other Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	5.1	5	5
INDIANA MICHIGAN POWER COMPANY | Total Wholesale and Competitive Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	434.5	365.7	526.8
INDIANA MICHIGAN POWER COMPANY | Generation Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	393.9	327.1	490
INDIANA MICHIGAN POWER COMPANY | Transmission Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	40.6	38.6	36.8
INDIANA MICHIGAN POWER COMPANY | Other Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	116	120.3	122.4
INDIANA MICHIGAN POWER COMPANY | Other Revenues | Related Party
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	75	68	62
INDIANA MICHIGAN POWER COMPANY | Total Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	(31.5)	13.6	9.9
INDIANA MICHIGAN POWER COMPANY | Alternative Revenue Programs
Disaggregation of Revenue [Line Items]
Total Other Revenues	(7.6)	(10.9)	10
INDIANA MICHIGAN POWER COMPANY | Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	(23.9)	24.5	(0.1)
OHIO POWER COMPANY
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	3,780.9	3,802.8	3,672.1
TOTAL REVENUES	3,827.8	3,811.4	3,665.1
OHIO POWER COMPANY | Total Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	3,522.6	3,547.9	3,363.5
OHIO POWER COMPANY | Residential Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	2,030.8	1,953.7	1,830.2
OHIO POWER COMPANY | Commercial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1,100.7	1,082	947.7
OHIO POWER COMPANY | Industrial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	373.7	497.1	571.7
OHIO POWER COMPANY | Other Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	17.4	15.1	13.9
OHIO POWER COMPANY | Total Wholesale and Competitive Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	96.3	82.6	86.2
OHIO POWER COMPANY | Generation Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
OHIO POWER COMPANY | Transmission Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	96.3	82.6	86.2
OHIO POWER COMPANY | Other Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	162	172.3	222.4
TOTAL REVENUES	12.1	12.3	11
OHIO POWER COMPANY | Total Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	46.9	8.6	(7)
OHIO POWER COMPANY | Alternative Revenue Programs
Disaggregation of Revenue [Line Items]
Total Other Revenues	26.9	(15.3)	(25.6)
OHIO POWER COMPANY | Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	20	23.9	18.6
PUBLIC SERVICE COMPANY OF OKLAHOMA
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1,849.5	1,976.6	1,875.7
TOTAL REVENUES	1,846.4	1,977	1,874.7
PUBLIC SERVICE COMPANY OF OKLAHOMA | Total Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1,758.7	1,905.9	1,780.9
PUBLIC SERVICE COMPANY OF OKLAHOMA | Residential Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	799.6	831.2	816.3
PUBLIC SERVICE COMPANY OF OKLAHOMA | Commercial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	509.5	538.8	489.2
PUBLIC SERVICE COMPANY OF OKLAHOMA | Industrial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	349.1	423.1	372.5
PUBLIC SERVICE COMPANY OF OKLAHOMA | Other Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	100.5	112.8	102.9
PUBLIC SERVICE COMPANY OF OKLAHOMA | Total Wholesale and Competitive Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	51.5	49.2	65.7
PUBLIC SERVICE COMPANY OF OKLAHOMA | Generation Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	9.4	11.7	26.5
PUBLIC SERVICE COMPANY OF OKLAHOMA | Transmission Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	42.1	37.5	39.2
PUBLIC SERVICE COMPANY OF OKLAHOMA | Other Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	39.3	21.5	29.1
TOTAL REVENUES	19.5	7.4	6.2
PUBLIC SERVICE COMPANY OF OKLAHOMA | Total Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	(3.1)	0.4	(1)
PUBLIC SERVICE COMPANY OF OKLAHOMA | Alternative Revenue Programs
Disaggregation of Revenue [Line Items]
Total Other Revenues	(3.1)	0.5	(1)
PUBLIC SERVICE COMPANY OF OKLAHOMA | Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	0	(0.1)	0
SOUTHWESTERN ELECTRIC POWER COMPANY
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	2,043.3	2,192.1	2,283.2
TOTAL REVENUES	2,036.3	2,182.8	2,284.4
SOUTHWESTERN ELECTRIC POWER COMPANY | Total Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1,661.6	1,834.9	1,836.6
SOUTHWESTERN ELECTRIC POWER COMPANY | Residential Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	726.4	799.5	820.7
SOUTHWESTERN ELECTRIC POWER COMPANY | Commercial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	558.1	609.4	612.3
SOUTHWESTERN ELECTRIC POWER COMPANY | Industrial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	367.9	415.9	393.5
SOUTHWESTERN ELECTRIC POWER COMPANY | Other Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	9.2	10.1	10.1
SOUTHWESTERN ELECTRIC POWER COMPANY | Total Wholesale and Competitive Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	349	327.7	421.9
SOUTHWESTERN ELECTRIC POWER COMPANY | Generation Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	176.9	176.9	273.2
SOUTHWESTERN ELECTRIC POWER COMPANY | Transmission Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	172.1	150.8	148.7
SOUTHWESTERN ELECTRIC POWER COMPANY | Transmission Revenues | Related Party
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	65	73	51
SOUTHWESTERN ELECTRIC POWER COMPANY | Other Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	32.7	29.5	24.7
TOTAL REVENUES	7.5	2.4	1.9
SOUTHWESTERN ELECTRIC POWER COMPANY | Total Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	(7)	(9.3)	1.2
SOUTHWESTERN ELECTRIC POWER COMPANY | Alternative Revenue Programs
Disaggregation of Revenue [Line Items]
Total Other Revenues	(7)	(9.4)	1.2
SOUTHWESTERN ELECTRIC POWER COMPANY | Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	0	0.1	0
Operating Segments
Disaggregation of Revenue [Line Items]
TOTAL REVENUES	21,500.5	20,523.5	21,133.4
Operating Segments | AEP TRANSMISSION COMPANY, LLC
Disaggregation of Revenue [Line Items]
TOTAL REVENUES	1,890.9	1,672	1,624.5
Corporate and Other
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	186	152.1	100.8
TOTAL REVENUES	183.1	168	109.9
Corporate and Other | Total Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
Corporate and Other | Residential Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
Corporate and Other | Commercial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
Corporate and Other | Industrial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
Corporate and Other | Other Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
Corporate and Other | Total Wholesale and Competitive Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1.3	0.6	6.9
Corporate and Other | Generation Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
Corporate and Other | Transmission Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
Corporate and Other | Renewable Generation Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
Corporate and Other | Retail, Trading and Marketing Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1.3	0.6	6.9
Corporate and Other | Other Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	184.7	151.5	93.9
Corporate and Other | Other Revenues | Related Party
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	137	100
Corporate and Other | Total Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	(2.9)	15.9	9.1
Corporate and Other | Alternative Revenue Programs
Disaggregation of Revenue [Line Items]
Total Other Revenues	0	0	0
Corporate and Other | Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	(2.9)	15.9	9.1
Corporate and Other | AEP TRANSMISSION COMPANY, LLC
Disaggregation of Revenue [Line Items]
TOTAL REVENUES	0	0	0
Reconciling Adjustments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	(1,935.3)	(1,668.4)	(1,537)
TOTAL REVENUES	(1,962.3)	(1,709.2)	(1,603.8)
Reconciling Adjustments | Total Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	(0.9)	(0.9)	(0.9)
Reconciling Adjustments | Residential Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
Reconciling Adjustments | Commercial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
Reconciling Adjustments | Industrial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	(0.9)	(0.9)	(0.9)
Reconciling Adjustments | Other Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
Reconciling Adjustments | Total Wholesale and Competitive Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	(1,720.9)	(1,507.2)	(1,431.3)
Reconciling Adjustments | Generation Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
Reconciling Adjustments | Transmission Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	(1,620.1)	(1,418.3)	(1,413.2)
Reconciling Adjustments | Renewable Generation Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	(4.4)	(6.7)	(8)
Reconciling Adjustments | Retail, Trading and Marketing Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	(96.4)	(82.2)	(10.1)
Reconciling Adjustments | Other Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	(213.5)	(160.3)	(104.8)
Reconciling Adjustments | Total Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	(27)	(40.8)	(66.8)
Reconciling Adjustments | Alternative Revenue Programs
Disaggregation of Revenue [Line Items]
Total Other Revenues	(29.8)	(25.5)	(57.7)
Reconciling Adjustments | Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	2.8	(15.3)	(9.1)
Reconciling Adjustments | AEP TRANSMISSION COMPANY, LLC
Disaggregation of Revenue [Line Items]
TOTAL REVENUES	0	0	0
VIU | Transmission Revenues | Related Party
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	177	205
VIU | Operating Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	11,642.2	11,459.9	11,473.3
TOTAL REVENUES	11,596.6	11,449.5	11,477.5
VIU | Operating Segments | Total Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	10,183.8	10,149	9,831.1
VIU | Operating Segments | Residential Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	4,561.9	4,479.3	4,498.6
VIU | Operating Segments | Commercial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	2,731.4	2,678.8	2,576.5
VIU | Operating Segments | Industrial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	2,659	2,748.2	2,543.8
VIU | Operating Segments | Other Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	231.5	242.7	212.2
VIU | Operating Segments | Total Wholesale and Competitive Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1,231.1	1,106.5	1,401.1
VIU | Operating Segments | Generation Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	747.8	662.5	958.3
VIU | Operating Segments | Transmission Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	483.3	444	442.8
VIU | Operating Segments | Renewable Generation Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
VIU | Operating Segments | Retail, Trading and Marketing Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
VIU | Operating Segments | Other Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	227.3	204.4	241.1
VIU | Operating Segments | Total Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	(45.6)	(10.4)	4.2
VIU | Operating Segments | Alternative Revenue Programs
Disaggregation of Revenue [Line Items]
Total Other Revenues	(22)	(35)	3.8
VIU | Operating Segments | Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	(23.6)	24.6	0.4
T&D | Operating Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	5,861.7	5,708.8	5,520.2
TOTAL REVENUES	5,907.7	5,713.3	5,512
T&D | Operating Segments | Total Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	4,894.7	4,799.1	4,622.9
T&D | Operating Segments | Residential Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	2,755.7	2,609.1	2,497.3
T&D | Operating Segments | Commercial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1,567.4	1,497.2	1,365.2
T&D | Operating Segments | Industrial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	515.2	642.1	711.3
T&D | Operating Segments | Other Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	56.4	50.7	49.1
T&D | Operating Segments | Total Wholesale and Competitive Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	769.5	701.6	650
T&D | Operating Segments | Generation Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
T&D | Operating Segments | Transmission Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	769.5	701.6	650
T&D | Operating Segments | Renewable Generation Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
T&D | Operating Segments | Retail, Trading and Marketing Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
T&D | Operating Segments | Other Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	197.5	208.1	247.3
T&D | Operating Segments | Total Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	46	4.5	(8.2)
T&D | Operating Segments | Alternative Revenue Programs
Disaggregation of Revenue [Line Items]
Total Other Revenues	26	(19.5)	(26.8)
T&D | Operating Segments | Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	20	24	18.6
AEPTHCo | Transmission Revenues | Related Party
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1,600	1,500	1,300
AEPTHCo | Operating Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	2,004.1	1,765.7	1,708.8
TOTAL REVENUES	1,950.8	1,728.5	1,677
AEPTHCo | Operating Segments | Total Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
AEPTHCo | Operating Segments | Residential Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
AEPTHCo | Operating Segments | Commercial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
AEPTHCo | Operating Segments | Industrial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
AEPTHCo | Operating Segments | Other Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
AEPTHCo | Operating Segments | Total Wholesale and Competitive Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1,978.3	1,748.9	1,700.6
AEPTHCo | Operating Segments | Generation Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
AEPTHCo | Operating Segments | Transmission Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	1,978.3	1,748.9	1,700.6
AEPTHCo | Operating Segments | Renewable Generation Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
AEPTHCo | Operating Segments | Retail, Trading and Marketing Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
AEPTHCo | Operating Segments | Other Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	25.8	16.8	8.2
AEPTHCo | Operating Segments | Total Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	(53.3)	(37.2)	(31.8)
AEPTHCo | Operating Segments | Alternative Revenue Programs
Disaggregation of Revenue [Line Items]
Total Other Revenues	(53.3)	(37.1)	(31.8)
AEPTHCo | Operating Segments | Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	0	(0.1)	0
G&M | Retail, Trading and Marketing Revenues | Related Party
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	96	82	59
G&M | Operating Segments
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	2,211	2,036.7	2,125.6
TOTAL REVENUES	2,045.4	1,632.2	2,466.9
G&M | Operating Segments | Total Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
G&M | Operating Segments | Residential Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
G&M | Operating Segments | Commercial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
G&M | Operating Segments | Industrial Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
G&M | Operating Segments | Other Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
G&M | Operating Segments | Total Wholesale and Competitive Retail Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	2,206.9	2,028.1	2,113.5
G&M | Operating Segments | Generation Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	103.2	111.3	271.2
G&M | Operating Segments | Transmission Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	0	0	0
G&M | Operating Segments | Renewable Generation Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	23.2	80.6	129.1
G&M | Operating Segments | Retail, Trading and Marketing Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	2,080.5	1,836.2	1,713.2
G&M | Operating Segments | Other Revenues
Disaggregation of Revenue [Line Items]
Total Revenues from Contracts with Customers	4.1	8.6	12.1
G&M | Operating Segments | Total Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	(165.6)	(404.5)	341.3
G&M | Operating Segments | Alternative Revenue Programs
Disaggregation of Revenue [Line Items]
Total Other Revenues	0	0	0
G&M | Operating Segments | Other Revenues
Disaggregation of Revenue [Line Items]
Total Other Revenues	$ (165.6)	$ (404.5)	$ 341.3

REVENUE FROM CONTRACTS WITH C_4

REVENUE FROM CONTRACTS WITH CUSTOMERS - Narrative (Details)	12 Months Ended
	Dec. 31, 2024 wk auction asset
Retail Revenues
Disaggregation of Revenue [Line Items]
Monthly billing, payment due term	35 days
Retail Revenues | Minimum
Disaggregation of Revenue [Line Items]
Monthly billing term	15 days
Retail Revenues | Maximum
Disaggregation of Revenue [Line Items]
Monthly billing term	20 days
Wholesale Revenues - Generation
Disaggregation of Revenue [Line Items]
Number of incremental auctions | auction	3
Incremental auction term	3 years
Monthly billing, number of weeks	1
Wholesale Revenues - Transmission
Disaggregation of Revenue [Line Items]
Monthly billing, number of weeks	1
Formula rate period	1 year
Costs allocation, average period	12 months
Costs allocation, number of transmission assets | asset	2
Wholesale Revenues - Transmission | Maximum
Disaggregation of Revenue [Line Items]
Performance obligation period	1 year
Marketing Arrangements
Disaggregation of Revenue [Line Items]
Monthly billing, payment due term	20 days
Competitive Retail And Offtake Arrangements For Renewable Assets Range | Minimum
Disaggregation of Revenue [Line Items]
Monthly billing, payment due term	15 days
Competitive Retail And Offtake Arrangements For Renewable Assets Range | Maximum
Disaggregation of Revenue [Line Items]
Monthly billing, payment due term	60 days

REVENUE FROM CONTRACTS WITH C_5

REVENUE FROM CONTRACTS WITH CUSTOMERS - Performance Obligation (Details) $ in Millions	Dec. 31, 2024 USD ($)
Disaggregation of Revenue [Line Items]
Fixed Performance Obligations	$ 301.6
APPALACHIAN POWER COMPANY
Disaggregation of Revenue [Line Items]
Fixed Performance Obligations	82.9
INDIANA MICHIGAN POWER COMPANY
Disaggregation of Revenue [Line Items]
Fixed Performance Obligations	22.4
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Disaggregation of Revenue [Line Items]
Fixed Performance Obligations	$ 93.7
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | APPALACHIAN POWER COMPANY
Disaggregation of Revenue [Line Items]
Fixed Performance Obligations	$ 16.1
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | INDIANA MICHIGAN POWER COMPANY
Disaggregation of Revenue [Line Items]
Fixed Performance Obligations	$ 4.4
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Disaggregation of Revenue [Line Items]
Fixed Performance Obligations	$ 143
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	2 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01 | APPALACHIAN POWER COMPANY
Disaggregation of Revenue [Line Items]
Fixed Performance Obligations	$ 32.1
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	2 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01 | INDIANA MICHIGAN POWER COMPANY
Disaggregation of Revenue [Line Items]
Fixed Performance Obligations	$ 8.8
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	2 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Disaggregation of Revenue [Line Items]
Fixed Performance Obligations	$ 48.8
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	2 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01 | APPALACHIAN POWER COMPANY
Disaggregation of Revenue [Line Items]
Fixed Performance Obligations	$ 23.1
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	2 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01 | INDIANA MICHIGAN POWER COMPANY
Disaggregation of Revenue [Line Items]
Fixed Performance Obligations	$ 6.8
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	2 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01
Disaggregation of Revenue [Line Items]
Fixed Performance Obligations	$ 16.1
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01 | APPALACHIAN POWER COMPANY
Disaggregation of Revenue [Line Items]
Fixed Performance Obligations	$ 11.6
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01 | INDIANA MICHIGAN POWER COMPANY
Disaggregation of Revenue [Line Items]
Fixed Performance Obligations	$ 2.4
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period

REVENUE FROM CONTRACTS WITH C_6

REVENUE FROM CONTRACTS WITH CUSTOMERS - Affiliate Accounts Receivable (Details) - Related Party - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
AEP TEXAS INC.
Disaggregation of Revenue [Line Items]
Affiliated Companies	$ 0	$ 0
AEP TRANSMISSION COMPANY, LLC
Disaggregation of Revenue [Line Items]
Affiliated Companies	131.6	123.2
APPALACHIAN POWER COMPANY
Disaggregation of Revenue [Line Items]
Affiliated Companies	83.7	71.7
INDIANA MICHIGAN POWER COMPANY
Disaggregation of Revenue [Line Items]
Affiliated Companies	55	44
OHIO POWER COMPANY
Disaggregation of Revenue [Line Items]
Affiliated Companies	63.6	70.1
PUBLIC SERVICE COMPANY OF OKLAHOMA
Disaggregation of Revenue [Line Items]
Affiliated Companies	13	12.4
SOUTHWESTERN ELECTRIC POWER COMPANY
Disaggregation of Revenue [Line Items]
Affiliated Companies	$ 21.4	$ 27.4

SUBSEQUENT EVENTS (Details)

SUBSEQUENT EVENTS (Details) - Subsequent Event $ in Millions	1 Months Ended
	Jan. 31, 2025 USD ($)
Subsequent Event [Line Items]
Capital plan, amount	$ 54,000
OHTCo and IMTCo
Subsequent Event [Line Items]
Ownership percentage selling	19.90%
Proceeds from sale of noncontrolling interests	$ 2,820

SCHEDULE I - CONDENSED FINANC_5

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY - CONDENSED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
REVENUES
Total Revenues	$ 19,721.3	$ 18,982.3	$ 19,639.5
EXPENSES
Other Operation	3,127.6	2,810.5	2,878.1
Depreciation and Amortization	3,289.9	3,090.4	3,202.8
TOTAL EXPENSES	15,417.7	15,426.1	16,156.8
OPERATING INCOME	4,303.6	3,556.2	3,482.7
Other Income (Expense):
Interest Expense	(1,862.8)	(1,806.9)	(1,396.1)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	2,842.9	2,208.7	2,420.4
Income Tax Expense (Benefit)	(39.2)	54.6	5.4
Equity Earnings (Loss) of Unconsolidated Subsidiaries	93.7	58.5	(109.4)
Net Current Period Other Comprehensive Income (Loss)	52.4	(139.2)	(101.1)
TOTAL COMPREHENSIVE INCOME ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS	$ 3,019.5	$ 2,068.9	$ 2,206.1
WEIGHTED AVERAGE NUMBER OF BASIC AEP COMMON SHARES OUTSTANDING (in shares)	530,092,672	518,903,682	511,841,946
TOTAL BASIC EARNINGS PER SHARE ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS (in USD per share)	$ 5.60	$ 4.26	$ 4.51
WEIGHTED AVERAGE NUMBER OF DILUTED AEP COMMON SHARES OUTSTANDING (in shares)	531,337,703	520,206,258	513,484,609
TOTAL DILUTED EARNINGS PER SHARE ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS (in USD per share)	$ 5.58	$ 4.24	$ 4.49
Parent Company
REVENUES
Total Revenues	$ 5.5	$ 5.1	$ 5.1
EXPENSES
Other Operation	66	16.7	84.9
Loss on the Expected Sale of the Kentucky Operations	0	0	363.3
Depreciation and Amortization	0.6	0.5	0.4
Amortization of KPCo Basis Difference	(21.4)	(16.5)	0
TOTAL EXPENSES	45.2	0.7	448.6
OPERATING INCOME	(39.7)	4.4	(443.5)
Other Income (Expense):
Interest Income	107.9	181	80.3
Interest Expense	(531.8)	(526.3)	(275.5)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	(463.6)	(340.9)	(638.7)
Income Tax Expense (Benefit)	(150.5)	(80.8)	(136.3)
Equity Earnings (Loss) of Unconsolidated Subsidiaries	3,280.2	2,468.2	2,809.6
NET INCOME	2,967.1	2,208.1	2,307.2
Net Current Period Other Comprehensive Income (Loss)	52.4	(139.2)	(101.1)
TOTAL COMPREHENSIVE INCOME ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS	$ 3,019.5	$ 2,068.9	$ 2,206.1
WEIGHTED AVERAGE NUMBER OF BASIC AEP COMMON SHARES OUTSTANDING (in shares)	530,092,672	518,903,682	511,841,946
TOTAL BASIC EARNINGS PER SHARE ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS (in USD per share)	$ 5.60	$ 4.26	$ 4.51
WEIGHTED AVERAGE NUMBER OF DILUTED AEP COMMON SHARES OUTSTANDING (in shares)	531,337,703	520,206,258	513,484,609
TOTAL DILUTED EARNINGS PER SHARE ATTRIBUTABLE TO AEP COMMON SHAREHOLDERS (in USD per share)	$ 5.58	$ 4.24	$ 4.49

SCHEDULE I - CONDENSED FINANC_6

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY - CONDENSED BALANCE SHEETS (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
CURRENT ASSETS
Cash and Cash Equivalents	$ 202.9	$ 330.1
Other Temporary Investments	215.4	214.3
Accounts Receivable:
General	64.1	48.7
Total Accounts Receivable	2,631.9	2,447.4
Accrued Tax Benefits	38.2	156.2
Prepayments and Other Current Assets	285.9	274.2
TOTAL CURRENT ASSETS	5,788.8	6,082.1
PROPERTY, PLANT AND EQUIPMENT
Other Property, Plant and Equipment	7,491.6	6,484.9
Total Property, Plant and Equipment	108,602	101,246.4
Accumulated Depreciation and Amortization	26,186.4	24,553
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	82,415.6	76,693.4
OTHER NONCURRENT ASSETS
Deferred Charges and Other Noncurrent Assets	3,873.3	3,625.7
TOTAL OTHER NONCURRENT ASSETS	14,873.6	13,908.5
TOTAL ASSETS	103,078	96,684
Accounts Payable:
Accounts Payable	2,637.6	2,032.5
Short-term Debt	2,523.8	2,830.2
Long-term Debt Due Within One Year – Nonaffiliated	3,335	2,490.5
Other Current Liabilities	1,490.9	1,251.1
TOTAL CURRENT LIABILITIES	13,009.3	11,583.6
NONCURRENT LIABILITIES
Long-term Debt	39,307.8	37,652.7
Deferred Credits and Other Noncurrent Liabilities	800.6	545.8
TOTAL NONCURRENT LIABILITIES	63,044.8	59,772
TOTAL LIABILITIES	76,054.1	71,355.6
MEZZANINE EQUITY
Contingently Redeemable Performance Share Awards	37.8	42.5
COMMON SHAREHOLDER’S EQUITY
Common Stock	3,471.6	3,427.9
Paid-in Capital	9,606.1	9,073.9
Retained Earnings	13,869.2	12,800.4
Accumulated Other Comprehensive Income (Loss)	(3.1)	(55.5)
TOTAL COMMON SHAREHOLDER’S EQUITY	26,943.8	25,246.7
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	103,078	96,684
Parent Company
CURRENT ASSETS
Cash and Cash Equivalents	87.5	197.8
Other Temporary Investments	2.9	2.6
Advances to Affiliates	1,944.6	2,004.5
Accounts Receivable:
General	0	2.7
Total Accounts Receivable	32.5	50.4
Accrued Tax Benefits	93.7	77.7
Prepayments and Other Current Assets	11.6	11.6
TOTAL CURRENT ASSETS	2,172.8	2,344.6
PROPERTY, PLANT AND EQUIPMENT
Other Property, Plant and Equipment	3.2	3.1
Total Property, Plant and Equipment	3.2	3.1
Accumulated Depreciation and Amortization	1.7	1.4
TOTAL PROPERTY, PLANT AND EQUIPMENT – NET	1.5	1.7
OTHER NONCURRENT ASSETS
Investments in Unconsolidated Subsidiaries	35,306.2	33,598.6
Affiliated Notes Receivable	105	295
Deferred Charges and Other Noncurrent Assets	184.6	137
TOTAL OTHER NONCURRENT ASSETS	35,595.8	34,030.6
TOTAL ASSETS	37,770.1	36,376.9
CURRENT LIABILITIES
Advances from Affiliates	506.6	728.3
Accounts Payable:
Short-term Debt	1,618.3	1,937.9
Long-term Debt Due Within One Year – Nonaffiliated	1,281.5	1,104
Other Current Liabilities	202.4	137.7
TOTAL CURRENT LIABILITIES	3,615.7	3,931.3
NONCURRENT LIABILITIES
Long-term Debt	7,124.3	7,086.9
Deferred Credits and Other Noncurrent Liabilities	48.5	69.5
TOTAL NONCURRENT LIABILITIES	7,172.8	7,156.4
TOTAL LIABILITIES	10,788.5	11,087.7
MEZZANINE EQUITY
Contingently Redeemable Performance Share Awards	37.8	42.5
COMMON SHAREHOLDER’S EQUITY
Common Stock	3,471.6	3,427.9
Paid-in Capital	9,606.1	9,073.9
Retained Earnings	13,869.2	12,800.4
Accumulated Other Comprehensive Income (Loss)	(3.1)	(55.5)
TOTAL COMMON SHAREHOLDER’S EQUITY	26,943.8	25,246.7
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	37,770.1	36,376.9
Parent Company | Nonrelated Party
Accounts Payable:
Accounts Payable	4.7	11.1
Parent Company | Affiliated Entity
Accounts Receivable:
Affiliated Companies	32.5	47.7
Accounts Payable:
Accounts Payable	$ 2.2	$ 12.3

SCHEDULE I - CONDENSED FINANC_7

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY - CONDENSED BALANCE SHEETS ADDITIONAL INFORMATION (Details) - $ / shares	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Condensed Balance Sheet Statements, Captions [Line Items]
Common Stock – Par Value (in USD per share)	$ 6.50	$ 6.50
Common Stock – Shares Authorized (in shares)	600,000,000	600,000,000
Common Stock – Shares Issued (in shares)	534,094,530	527,369,157	525,099,321	524,416,175
Shares were Held in Treasury (in shares)	1,186,815	1,184,572	11,233,240	20,204,160
Parent Company
Condensed Balance Sheet Statements, Captions [Line Items]
Common Stock – Par Value (in USD per share)	$ 6.50	$ 6.50
Common Stock – Shares Authorized (in shares)	600,000,000	600,000,000
Common Stock – Shares Issued (in shares)	534,094,530	527,369,157
Shares were Held in Treasury (in shares)	1,186,815	1,184,572

SCHEDULE I - CONDENSED FINANC_8

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY - CONDENSED STATEMENTS OF CASH FLOWS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities:
Depreciation and Amortization	$ 3,289.9	$ 3,090.4	$ 3,202.8
Deferred Income Taxes	58.3	185.1	(137.2)
Loss on the Expected Sale of the Kentucky Operations	0	0	363.3
Change in Other Noncurrent Assets	(347.6)	(465.1)	(187.7)
Change in Other Noncurrent Liabilities	306.3	29	337.8
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(156)	236.5	(681.7)
Accounts Payable	85.1	(253.2)	489.2
Other Current Assets	(13.2)	(43.9)	109
Other Current Liabilities	182.6	(161.4)	54.3
Net Cash Flows from Operating Activities	6,804.3	5,012.2	5,288
INVESTING ACTIVITIES
Construction Expenditures	(7,630.7)	(7,378.3)	(6,671.7)
Other Investing Activities	141.9	122.1	50.3
Net Cash Flows Used for Investing Activities	(7,596.5)	(6,266.7)	(7,751.8)
FINANCING ACTIVITIES
Issuance of Common Stock, Net	552.1	999.6	826.5
Issuance of Long-term Debt	5,117	5,462.8	4,649.7
Issuance of Short-term Debt with Original Maturities greater than 90 Days	723.8	1,069.9	833.9
Change in Short-term Debt with Original Maturities less than 90 Day, Net	(159.1)	(1,223.1)	1,650.4
Retirement of Long-term Debt	(2,685)	(2,196.1)	(2,345.4)
Redemption of Short-term Debt with Original Maturities greater than 90 Days	(871.1)	(1,128.8)	(986.1)
Dividends Paid on Common Stock	(1,903.9)	(1,760.4)	(1,645.2)
Other Financing Activities	(49.8)	(78.6)	(105.4)
Net Cash Flows from Financing Activities	659.2	1,077	2,568.9
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(133)	(177.5)	105.1
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	379	556.5	451.4
Cash, Cash Equivalents and Restricted Cash at End of Period	246	379	556.5
Parent Company
OPERATING ACTIVITIES
Net Income	2,967.1	2,208.1	2,307.2
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities:
Depreciation and Amortization	0.6	0.5	0.4
Amortization of KPCo Basis Difference	(21.4)	(16.5)	0
Deferred Income Taxes	(53.3)	59.7	(63.3)
Loss on the Expected Sale of the Kentucky Operations	0	0	363.3
Equity Earnings of Unconsolidated Subsidiaries	(3,280.2)	(2,468.2)	(2,809.6)
Cash Dividends Received from Unconsolidated Subsidiaries	1,143.4	686.3	603.9
Change in Other Noncurrent Assets	4.9	(28.4)	(5)
Change in Other Noncurrent Liabilities	70.8	92.3	83.5
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	17.9	28.7	(61)
Accounts Payable	(16.5)	(15.9)	1.1
Other Current Assets	0	(3.6)	(6)
Other Current Liabilities	55.3	(14.5)	(76.6)
Net Cash Flows from Operating Activities	888.6	528.5	337.9
INVESTING ACTIVITIES
Construction Expenditures	(0.6)	(0.8)	(0.7)
Change in Advances to Affiliates, Net	59.9	2,007.6	(1,411.3)
Capital Contributions to Unconsolidated Subsidiaries	(399.9)	(789.9)	(568.3)
Return of Capital Contributions from Unconsolidated Subsidiaries	898.9	56.6	24.5
Issuance of Notes Receivable to Unconsolidated Subsidiaries	0	(210)	(20)
Repayment of Notes Receivable from Unconsolidated Subsidiaries	190	0	0
Other Investing Activities	0	0	(0.2)
Net Cash Flows Used for Investing Activities	748.3	1,063.5	(1,976)
FINANCING ACTIVITIES
Issuance of Common Stock, Net	552.1	999.6	826.5
Issuance of Long-term Debt	1,285.4	1,829.8	986.6
Issuance of Short-term Debt with Original Maturities greater than 90 Days	723.8	1,069.9	833.9
Change in Short-term Debt with Original Maturities less than 90 Day, Net	(172.3)	(1,365.4)	1,650.4
Retirement of Long-term Debt	(1,104)	(1,050)	(300)
Change in Advances from Affiliates, Net	(221.7)	(191.6)	336.9
Redemption of Short-term Debt with Original Maturities greater than 90 Days	(871.1)	(1,128.8)	(986.1)
Dividends Paid on Common Stock	(1,898.3)	(1,752.3)	(1,628.7)
Other Financing Activities	(41.1)	(59.6)	(74.5)
Net Cash Flows from Financing Activities	(1,747.2)	(1,648.4)	1,645
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(110.3)	(56.4)	6.9
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	197.8	254.2	247.3
Cash, Cash Equivalents and Restricted Cash at End of Period	$ 87.5	$ 197.8	$ 254.2

SCHEDULE I - CONDENSED FINANC_9

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY - FINANCING ACTIVITIES - SCHEDULE OF LONG-TERM DEBT (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Debt Instrument [Line Items]
Total Long-term Debt Outstanding	$ 42,642.8	$ 40,143.2
Long-term Debt Due Within One Year	3,335	2,490.5
Long-term Debt	39,307.8	37,652.7
Parent Company
Debt Instrument [Line Items]
Senior Unsecured Notes	5,290	5,265
Pollution Control Bonds	536.8	537.8
Junior Subordinated Notes	2,579	2,388.1
Total Long-term Debt Outstanding	8,405.8	8,190.9
Long-term Debt Due Within One Year	1,281.5	1,104
Long-term Debt	$ 7,124.3	7,086.9
Senior Unsecured Notes
Debt Instrument [Line Items]
Weighted Average Interest Rate	4.32%
Senior Unsecured Notes	$ 36,410.9	$ 33,779.4
Senior Unsecured Notes | Minimum
Debt Instrument [Line Items]
Interest Rate	1%	1%
Senior Unsecured Notes | Maximum
Debt Instrument [Line Items]
Interest Rate	8.13%	8.13%
Senior Unsecured Notes | Parent Company
Debt Instrument [Line Items]
Weighted Average Interest Rate	4.29%
Senior Unsecured Notes | Parent Company | Minimum
Debt Instrument [Line Items]
Interest Rate	1%	1%
Senior Unsecured Notes | Parent Company | Maximum
Debt Instrument [Line Items]
Interest Rate	5.95%	5.95%
Pollution Control Bonds
Debt Instrument [Line Items]
Weighted Average Interest Rate	3.26%
Pollution Control Bonds	$ 1,771.3	$ 1,771.6
Pollution Control Bonds | Minimum
Debt Instrument [Line Items]
Interest Rate	0.63%	0.63%
Pollution Control Bonds | Maximum
Debt Instrument [Line Items]
Interest Rate	4.70%	4.90%
Pollution Control Bonds | Parent Company
Debt Instrument [Line Items]
Weighted Average Interest Rate	3.12%
Pollution Control Bonds | Parent Company | Minimum
Debt Instrument [Line Items]
Interest Rate	2.40%	1.90%
Pollution Control Bonds | Parent Company | Maximum
Debt Instrument [Line Items]
Interest Rate	3.75%	2.60%
Junior Subordinated Notes
Debt Instrument [Line Items]
Weighted Average Interest Rate	5.67%
Junior Subordinated Notes	$ 2,579.1	$ 2,388.1
Junior Subordinated Notes | Minimum
Debt Instrument [Line Items]
Interest Rate	3.88%	2.03%
Junior Subordinated Notes | Maximum
Debt Instrument [Line Items]
Interest Rate	7.05%	5.70%
Junior Subordinated Notes | Parent Company
Debt Instrument [Line Items]
Weighted Average Interest Rate	5.67%
Junior Subordinated Notes | Parent Company | Minimum
Debt Instrument [Line Items]
Interest Rate	3.88%	2.03%
Junior Subordinated Notes | Parent Company | Maximum
Debt Instrument [Line Items]
Interest Rate	7.05%	5.70%

SCHEDULE I - CONDENSED FINAN_10

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY - FINANCING ACTIVITIES - SCHEDULE OF LONG-TERM DEBT OUTSTANDING (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Debt Instrument [Line Items]
2025	$ 3,335
2026	1,864.4
2027	2,283.6
2028	2,592
2029	2,694
2029	30,212.8
Principal Amount	42,981.8
Unamortized Discount, Net and Debt Issuance Costs	(339)
Total Long-term Debt Outstanding	42,642.8	$ 40,143.2
Parent Company
Debt Instrument [Line Items]
2025	1,281.5
2026	50
2027	1,758.3
2028	930.4
2029	1,694.5
2029	2,750
Principal Amount	8,464.7
Unamortized Discount, Net and Debt Issuance Costs	(58.9)
Total Long-term Debt Outstanding	$ 8,405.8	$ 8,190.9

SCHEDULE I - CONDENSED FINAN_11

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY - FINANCING ACTIVITIES - SCHEDULE OF SHORT-TERM DEBT (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Short-Term Debt [Line Items]
Commercial Paper	$ 1,618.3	$ 1,937.9
Total Short-term Debt	2,523.8	2,830.2
Parent Company
Short-Term Debt [Line Items]
Commercial Paper	1,618.3	1,937.9
Total Short-term Debt	$ 1,618.3	$ 1,937.9
Commercial Paper
Short-Term Debt [Line Items]
Weighted-Average Interest Rate	4.70%	5.69%
Commercial Paper | Parent Company
Short-Term Debt [Line Items]
Weighted-Average Interest Rate	4.70%	5.69%

SCHEDULE I - CONDENSED FINAN_12

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY - RELATED PARTY TRANSACTIONS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Subsidiaries | Affiliated Notes
Related Party Transaction [Line Items]
Interest income	$ 7	$ 6	$ 3
Parent Company
Related Party Transaction [Line Items]
Interest income	107.9	181	80.3
Parent Company | Subsidiaries
Related Party Transaction [Line Items]
Interest expense	28	33	30
Parent Company | Subsidiaries | Short-Term Lending
Related Party Transaction [Line Items]
Interest income	$ 84	$ 164	$ 71

SCHEDULE II _ VALUATION AND Q_2

SCHEDULE II – VALUATION AND QUALIFYING ACCOUNTS AND RESERVES (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at Beginning of Period	$ 60.1	$ 57.1	$ 55.4
Charged to Costs and Expenses	45.3	15	41.2
Charged to Other Accounts	2.9	0	0.8
Deductions	47.5	12	40.3
Balance at End of Period	$ 60.8	$ 60.1	$ 57.1

SCHEDULE I - CONDENSED FINAN_13

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY - AEPTCO PARENT - CONDENSED STATEMENTS OF INCOME (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
EXPENSES
Other Operation	$ 3,127,600	$ 2,810,500	$ 2,878,100
TOTAL EXPENSES	15,417,700	15,426,100	16,156,800
OPERATING INCOME	4,303,600	3,556,200	3,482,700
Other Income (Expense):
Interest Expense	(1,862,800)	(1,806,900)	(1,396,100)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	2,842,900	2,208,700	2,420,400
Income Tax Expense (Benefit)	(39,200)	54,600	5,400
Equity Earnings (Loss) of Unconsolidated Subsidiaries	93,700	58,500	(109,400)
Parent Company
EXPENSES
Other Operation	66,000	16,700	84,900
TOTAL EXPENSES	45,200	700	448,600
OPERATING INCOME	(39,700)	4,400	(443,500)
Other Income (Expense):
Interest Income	107,900	181,000	80,300
Interest Expense	(531,800)	(526,300)	(275,500)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	(463,600)	(340,900)	(638,700)
Income Tax Expense (Benefit)	(150,500)	(80,800)	(136,300)
Equity Earnings (Loss) of Unconsolidated Subsidiaries	3,280,200	2,468,200	2,809,600
NET INCOME	2,967,100	2,208,100	2,307,200
AEP TRANSMISSION COMPANY, LLC
EXPENSES
Other Operation	137,400	109,000	136,300
TOTAL EXPENSES	897,900	806,400	770,800
OPERATING INCOME	993,000	865,600	853,700
Other Income (Expense):
Interest Expense	(214,200)	(194,500)	(162,700)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	878,700	761,300	763,300
Income Tax Expense (Benefit)	190,300	147,100	169,100
NET INCOME	688,400	614,200	594,200
AEP TRANSMISSION COMPANY, LLC | Parent Company
EXPENSES
Other Operation	1,700	200	700
TOTAL EXPENSES	1,700	200	700
OPERATING INCOME	(1,700)	(200)	(700)
Other Income (Expense):
Interest Income	241,100	218,000	177,800
Interest Expense	(238,700)	(215,100)	(177,100)
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) AND EQUITY EARNINGS (LOSS)	700	2,700	0
Income Tax Expense (Benefit)	100	1,400	0
Equity Earnings (Loss) of Unconsolidated Subsidiaries	687,800	612,900	594,200
NET INCOME	688,400	614,200	594,200
AEP TRANSMISSION COMPANY, LLC | Parent Company | Short-Term Lending | Affiliated Entity
Other Income (Expense):
Interest Income	$ 3,000	$ 3,000	$ 915

SCHEDULE I - CONDENSED FINAN_14

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY - AEPTCO PARENT - CONDENSED BALANCE SHEETS (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Accounts Receivable:
General	$ 64.1	$ 48.7
Total Accounts Receivable	2,631.9	2,447.4
TOTAL CURRENT ASSETS	5,788.8	6,082.1
OTHER NONCURRENT ASSETS
Deferred Charges and Other Noncurrent Assets	3,873.3	3,625.7
TOTAL OTHER NONCURRENT ASSETS	14,873.6	13,908.5
TOTAL ASSETS	103,078	96,684
Accounts Payable:
Accounts Payable	2,637.6	2,032.5
Long-term Debt Due Within One Year – Nonaffiliated	3,335	2,490.5
Accrued Interest	453.3	410.2
Other Current Liabilities	1,490.9	1,251.1
TOTAL CURRENT LIABILITIES	13,009.3	11,583.6
NONCURRENT LIABILITIES
Long-term Debt – Nonaffiliated	39,307.8	37,652.7
TOTAL NONCURRENT LIABILITIES	63,044.8	59,772
TOTAL LIABILITIES	76,054.1	71,355.6
MEMBER’S EQUITY
Retained Earnings	13,869.2	12,800.4
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	103,078	96,684
AEP TRANSMISSION COMPANY, LLC
CURRENT ASSETS
Advances to Affiliates	30.4	67.1
Accounts Receivable:
General	1.3	0
Total Accounts Receivable	194.3	207.7
TOTAL CURRENT ASSETS	235.8	278.8
OTHER NONCURRENT ASSETS
Deferred Charges and Other Noncurrent Assets	8.7	6.5
TOTAL OTHER NONCURRENT ASSETS	318	296
TOTAL ASSETS	16,370.3	15,072.5
Accounts Payable:
Accounts Payable	360.5	274.7
Long-term Debt Due Within One Year – Nonaffiliated	90	95
Accrued Interest	44.9	39.6
Other Current Liabilities	44.5	24.7
TOTAL CURRENT LIABILITIES	1,408.8	1,286.1
NONCURRENT LIABILITIES
Long-term Debt – Nonaffiliated	5,678.1	5,319.4
TOTAL NONCURRENT LIABILITIES	8,010.6	7,453.1
TOTAL LIABILITIES	9,419.4	8,739.2
MEMBER’S EQUITY
Paid-in Capital	3,100.6	3,043.4
Retained Earnings	3,850.3	3,289.9
TOTAL MEMBER’S EQUITY	6,950.9	6,333.3	$ 5,873	$ 5,376.1
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	16,370.3	15,072.5
Affiliated Entity | AEP TRANSMISSION COMPANY, LLC
Accounts Receivable:
Affiliated Companies	134.1	125.5
CURRENT LIABILITIES
Advances from Affiliates	84.7	174.3
Accounts Payable:
Accounts Payable	117	107.9
Parent Company
CURRENT ASSETS
Advances to Affiliates	1,944.6	2,004.5
Accounts Receivable:
General	0	2.7
Total Accounts Receivable	32.5	50.4
TOTAL CURRENT ASSETS	2,172.8	2,344.6
OTHER NONCURRENT ASSETS
Notes Receivable - Affiliated	105	295
Investments in Unconsolidated Subsidiaries	35,306.2	33,598.6
Deferred Charges and Other Noncurrent Assets	184.6	137
TOTAL OTHER NONCURRENT ASSETS	35,595.8	34,030.6
TOTAL ASSETS	37,770.1	36,376.9
CURRENT LIABILITIES
Advances from Affiliates	506.6	728.3
Accounts Payable:
Long-term Debt Due Within One Year – Nonaffiliated	1,281.5	1,104
Other Current Liabilities	202.4	137.7
TOTAL CURRENT LIABILITIES	3,615.7	3,931.3
NONCURRENT LIABILITIES
Long-term Debt – Nonaffiliated	7,124.3	7,086.9
TOTAL NONCURRENT LIABILITIES	7,172.8	7,156.4
TOTAL LIABILITIES	10,788.5	11,087.7
MEMBER’S EQUITY
Retained Earnings	13,869.2	12,800.4
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	37,770.1	36,376.9
Parent Company | AEP TRANSMISSION COMPANY, LLC
CURRENT ASSETS
Advances to Affiliates	20.4	0
Accounts Receivable:
General	0	28.1
Affiliated Companies	61.7	44
Total Accounts Receivable	61.7	72.1
Notes Receivable - Affiliated	90	95
TOTAL CURRENT ASSETS	172.1	167.1
OTHER NONCURRENT ASSETS
Notes Receivable - Affiliated	8,498.1	5,319.4
Investments in Unconsolidated Subsidiaries	4,272.8	6,476.2
Deferred Charges and Other Noncurrent Assets	0.3	0
TOTAL OTHER NONCURRENT ASSETS	12,771.2	11,795.6
TOTAL ASSETS	12,943.3	11,962.7
CURRENT LIABILITIES
Advances from Affiliates	0	42.7
Accounts Payable:
Accounts Payable	69.4	35.4
Long-term Debt Due Within One Year – Nonaffiliated	90	95
Accrued Interest	45	39.6
Other Current Liabilities	14.8	15.8
TOTAL CURRENT LIABILITIES	314.3	310
NONCURRENT LIABILITIES
Long-term Debt – Nonaffiliated	5,678.1	5,319.4
TOTAL NONCURRENT LIABILITIES	5,678.1	5,319.4
TOTAL LIABILITIES	5,992.4	5,629.4
MEMBER’S EQUITY
Paid-in Capital	3,100.6	3,043.4
Retained Earnings	3,850.3	3,289.9
TOTAL MEMBER’S EQUITY	6,950.9	6,333.3
TOTAL LIABILITIES, MEZZANINE EQUITY AND EQUITY	12,943.3	11,962.7
Parent Company | Affiliated Entity
Accounts Receivable:
Affiliated Companies	32.5	47.7
Accounts Payable:
Accounts Payable	2.2	12.3
Parent Company | Affiliated Entity | AEP TRANSMISSION COMPANY, LLC
Accounts Payable:
Accounts Payable	$ 95.1	$ 81.5

SCHEDULE I - CONDENSED FINAN_15

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY - AEPTCO PARENT - CONDENSED STATEMENTS OF CASH FLOWS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities:
Change in Other Noncurrent Assets	$ (347.6)	$ (465.1)	$ (187.7)
Change in Other Noncurrent Liabilities	306.3	29	337.8
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(156)	236.5	(681.7)
Accounts Payable	85.1	(253.2)	489.2
Other Current Liabilities	182.6	(161.4)	54.3
Net Cash Flows from Operating Activities	6,804.3	5,012.2	5,288
INVESTING ACTIVITIES
Net Cash Flows Used for Investing Activities	(7,596.5)	(6,266.7)	(7,751.8)
FINANCING ACTIVITIES
Issuance of Long-term Debt	5,117	5,462.8	4,649.7
Retirement of Long-term Debt	(2,685)	(2,196.1)	(2,345.4)
Other Financing Activities	(49.8)	(78.6)	(105.4)
Net Cash Flows from Financing Activities	659.2	1,077	2,568.9
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(133)	(177.5)	105.1
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	379	556.5	451.4
Cash, Cash Equivalents and Restricted Cash at End of Period	246	379	556.5
AEP TRANSMISSION COMPANY, LLC
OPERATING ACTIVITIES
Net Income	688.4	614.2	594.2
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities:
Change in Other Noncurrent Assets	(0.6)	8.6	(7.4)
Change in Other Noncurrent Liabilities	(17)	134.2	68.7
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	13.4	(41.3)	(46.3)
Accounts Payable	9.5	22.8	18.5
Accrued Interest	5.3	10.8	0
Other Current Liabilities	13.3	(0.1)	3
Net Cash Flows from Operating Activities	1,237.8	1,137.6	995.3
INVESTING ACTIVITIES
Change in Advances to Affiliates, Net	36.7	(62.7)	22.8
Net Cash Flows Used for Investing Activities	(1,428.1)	(1,557.7)	(1,439.2)
FINANCING ACTIVITIES
Capital Contribution from Member	61.7	29.7	72.7
Return of Capital to Parent	(4.5)	(8.6)	0
Issuance of Long-term Debt	445.7	689	540.8
Retirement of Long-term Debt	(95)	(60)	(104)
Change in Advances from Affiliates, Net	(89.6)	(55)	104.4
Dividends Paid to Member	(128)	(175)	(170)
Net Cash Flows from Financing Activities	190.3	420.1	443.9
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	0	0	0
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	0	0	0
Cash, Cash Equivalents and Restricted Cash at End of Period	0	0	0
Parent Company
OPERATING ACTIVITIES
Net Income	2,967.1	2,208.1	2,307.2
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities:
Equity Earnings of Unconsolidated Subsidiaries	(3,280.2)	(2,468.2)	(2,809.6)
Change in Other Noncurrent Assets	4.9	(28.4)	(5)
Change in Other Noncurrent Liabilities	70.8	92.3	83.5
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	17.9	28.7	(61)
Accounts Payable	(16.5)	(15.9)	1.1
Other Current Liabilities	55.3	(14.5)	(76.6)
Net Cash Flows from Operating Activities	888.6	528.5	337.9
INVESTING ACTIVITIES
Change in Advances to Affiliates, Net	59.9	2,007.6	(1,411.3)
Repayment of Notes Receivable from Affiliated Companies	(190)	0	0
Issuance of Notes Receivable to Affiliated Companies	0	210	20
Net Cash Flows Used for Investing Activities	748.3	1,063.5	(1,976)
FINANCING ACTIVITIES
Issuance of Long-term Debt	1,285.4	1,829.8	986.6
Retirement of Long-term Debt	(1,104)	(1,050)	(300)
Change in Advances from Affiliates, Net	(221.7)	(191.6)	336.9
Other Financing Activities	(41.1)	(59.6)	(74.5)
Net Cash Flows from Financing Activities	(1,747.2)	(1,648.4)	1,645
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(110.3)	(56.4)	6.9
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	197.8	254.2	247.3
Cash, Cash Equivalents and Restricted Cash at End of Period	87.5	197.8	254.2
Parent Company | AEP TRANSMISSION COMPANY, LLC
OPERATING ACTIVITIES
Net Income	688.4	614.2	594.2
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities:
Equity Earnings of Unconsolidated Subsidiaries	(687.8)	(612.9)	(594.2)
Change in Other Noncurrent Assets	0	3.8	0
Change in Other Noncurrent Liabilities	4	11.5	9.1
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	10.4	(37.5)	(2.2)
Accounts Payable	12.9	36.6	(0.6)
Accrued Interest	5.4	10.8	0
Other Current Liabilities	34	(30.5)	(0.8)
Net Cash Flows from Operating Activities	67.3	(4)	5.5
INVESTING ACTIVITIES
Change in Advances to Affiliates, Net	(20.4)	0	12.7
Repayment of Notes Receivable from Affiliated Companies	95	60	104
Issuance of Notes Receivable to Affiliated Companies	450	700	550
Return of Capital Contributions from Unconsolidated Subsidiaries	132.8	183.7	130
Capital Contributions to Subsidiaries	(61.7)	(29.7)	(69.5)
Net Cash Flows Used for Investing Activities	(304.3)	(486)	(372.8)
FINANCING ACTIVITIES
Capital Contribution from Member	61.7	29.7	72.7
Return of Capital to Parent	(4.5)	(8.6)	0
Issuance of Long-term Debt	445.7	689	540.8
Retirement of Long-term Debt	(95)	(60)	(104)
Change in Advances from Affiliates, Net	(42.7)	14.9	27.8
Dividends Paid to Member	(128)	(175)	(170)
Other Financing Activities	(0.2)	0	0
Net Cash Flows from Financing Activities	237	490	367.3
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	0	0	0
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	0	0	0
Cash, Cash Equivalents and Restricted Cash at End of Period	$ 0	$ 0	$ 0

SCHEDULE I - CONDENSED FINAN_16

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY - AEPTCO PARENT - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) - OHTCo and IMTCo - USD ($)	1 Months Ended
	Jan. 31, 2025	Dec. 31, 2024
Subsequent Event
Related Party Transaction [Line Items]
Ownership percentage selling	19.90%
Proceeds from sale of noncontrolling interests	$ 2,820,000,000
Parent Company | Affiliated Entity | AEP TRANSMISSION COMPANY, LLC
Related Party Transaction [Line Items]
Notes receivable – affiliated		$ 2,820,000,000
Parent Company | Affiliated Entity | AEP TRANSMISSION COMPANY, LLC | Subsequent Event
Related Party Transaction [Line Items]
Ownership percentage selling	19.90%
Proceeds from sale of noncontrolling interests	$ 2,820,000,000

SCHEDULE I - CONDENSED FINAN_17

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY - AEPTCO PARENT - RELATED PARTY TRANSACTIONS (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Related Party Transaction [Line Items]
Long-term debt	$ 42,642,800	$ 40,143,200
Accrued interest	453,300	410,200
AEP TRANSMISSION COMPANY, LLC
Related Party Transaction [Line Items]
Long-term debt	5,768,100	5,414,400
Accrued interest	44,900	39,600
Affiliated Entity | AEP TRANSMISSION COMPANY, LLC
Related Party Transaction [Line Items]
Accounts receivable – affiliated companies	134,100	125,500
Parent Company
Related Party Transaction [Line Items]
Long-term debt	8,405,800	8,190,900
Interest income	107,900	181,000	$ 80,300
Parent Company | AEP TRANSMISSION COMPANY, LLC
Related Party Transaction [Line Items]
Accrued interest	45,000	39,600
Accounts receivable – affiliated companies	61,700	44,000
Interest income	241,100	218,000	177,800
Parent Company | Subsidiaries
Related Party Transaction [Line Items]
Interest expense	28,000	33,000	30,000
Parent Company | Subsidiaries | AEP TRANSMISSION COMPANY, LLC
Related Party Transaction [Line Items]
Long-term debt	5,800,000	5,400,000
Notes receivable – affiliated	8,600,000	5,400,000
Accrued interest	45,000	40,000
Accounts receivable – affiliated companies	62,000	44,000
Interest expense	238,000	215,000	177,000
Parent Company | Affiliated Entity
Related Party Transaction [Line Items]
Accounts receivable – affiliated companies	32,500	47,700
Parent Company | Long-Term Lending | Subsidiaries | AEP TRANSMISSION COMPANY, LLC
Related Party Transaction [Line Items]
Interest income	238,000	215,000	177,000
Parent Company | Short-Term Lending | Subsidiaries
Related Party Transaction [Line Items]
Interest income	84,000	164,000	71,000
Parent Company | Short-Term Lending | Affiliated Entity | AEP TRANSMISSION COMPANY, LLC
Related Party Transaction [Line Items]
Interest income	$ 3,000	$ 3,000	$ 915