Indiana Michigan Power 10-Q 22 Apr 21 2020 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2021	Apr. 22, 2021
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2021
Document Transition Report	false
Entity File Number	1-3525
Entity Registrant Name	AMERICAN ELECTRIC POWER CO INC.
Entity Incorporation, State or Country Code	NY
Entity Tax Identification Number	13-4922640
Entity Address, Address Line One	1 Riverside Plaza,
Entity Address, City or Town	Columbus,
Entity Address, State or Province	OH
Entity Address, Postal Zip Code	43215-2373
City Area Code	(614)
Local Phone Number	716-1000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		499,750,400
Entity Central Index Key	0000004904
Amendment Flag	false
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--12-31
AEP Texas Inc. [Member]
Entity Information [Line Items]
Entity File Number	333-221643
Entity Registrant Name	AEP TEXAS INC.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	51-0007707
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding		100
Entity Central Index Key	0001721781
AEP Transmission Co [Member]
Entity Information [Line Items]
Entity File Number	333-217143
Entity Registrant Name	AEP TRANSMISSION COMPANY, LLC
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	46-1125168
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Central Index Key	0001702494
Appalachian Power Co [Member]
Entity Information [Line Items]
Entity File Number	1-3457
Entity Registrant Name	APPALACHIAN POWER COMPANY
Entity Incorporation, State or Country Code	VA
Entity Tax Identification Number	54-0124790
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding		13,499,500
Entity Central Index Key	0000006879
Indiana Michigan Power Co [Member]
Entity Information [Line Items]
Entity File Number	1-3570
Entity Registrant Name	INDIANA MICHIGAN POWER COMPANY
Entity Incorporation, State or Country Code	IN
Entity Tax Identification Number	35-0410455
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding		1,400,000
Entity Central Index Key	0000050172
Ohio Power Co [Member]
Entity Information [Line Items]
Entity File Number	1-6543
Entity Registrant Name	OHIO POWER COMPANY
Entity Incorporation, State or Country Code	OH
Entity Tax Identification Number	31-4271000
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding		27,952,473
Entity Central Index Key	0000073986
Public Service Co Of Oklahoma [Member]
Entity Information [Line Items]
Entity File Number	0-343
Entity Registrant Name	PUBLIC SERVICE COMPANY OF OKLAHOMA
Entity Incorporation, State or Country Code	OK
Entity Tax Identification Number	73-0410895
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding		9,013,000
Entity Central Index Key	0000081027
Southwestern Electric Power Co [Member]
Entity Information [Line Items]
Entity File Number	1-3146
Entity Registrant Name	SOUTHWESTERN ELECTRIC POWER COMPANY
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	72-0323455
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding		3,680
Entity Central Index Key	0000092487
The NASDAQ Stock Market LLC | Common Stock [Member]
Entity Information [Line Items]
Title of 12(b) Security	Common Stock, $6.50 par value
Trading Symbol	AEP
Security Exchange Name	NASDAQ
The NASDAQ Stock Market LLC | Preferred Stock [Member]
Entity Information [Line Items]
Title of 12(b) Security	6.125% Corporate Units
Trading Symbol	AEPPL
Security Exchange Name	NASDAQ
The NASDAQ Stock Market LLC | Preferred Stock 2
Entity Information [Line Items]
Title of 12(b) Security	6.125% Corporate Units
Trading Symbol	AEPPZ
Security Exchange Name	NASDAQ

Consolidated Statements of Inco

Consolidated Statements of Income - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021		Mar. 31, 2020
Revenues
Revenue from Contracts with Customers	$ 4,281.1		$ 3,747.5
Sales to AEP Affiliates	0		0
TOTAL REVENUES	4,281.1		3,747.5
Expenses
Other Operation	592.4		602.1
Maintenance	274.9		249.5
Depreciation and Amortization	696.3		672.2
Taxes Other Than Income Taxes	346.5		321.1
TOTAL EXPENSES	3,470.8		2,995.9
OPERATING INCOME (LOSS)	810.3		751.6
Other Income (Expense):
Other Income	21.7		(4.4)
Allowance for Equity Funds Used During Construction	33.4		31.4
Non-Service Cost Components of Net Periodic Benefit Cost	29.6		29.7
Interest Expense	(290.2)		(292.1)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS	604.8		516.2
Income Tax Expense (Benefit)	54.5		46.5
Equity Earnings (Loss) of Unconsolidated Subsidiaries	28.5		29.6
Net Income (Loss)	578.8		499.3
Net Income (Loss) Attributable to Noncontrolling Interests	3.8		4.1
Earnings Attributable to Common Shareholders	$ 575		$ 495.2
Earnings Per Share
Weighted Average Number of Basic AEP Common Shares Outstanding	497,058,635		494,596,869
Total Basic Earnings Per Share Attributable to AEP Common Shareholders	$ 1.16		$ 1
Weighted Average Number of Diluted AEP Common Shares Outstanding	498,164,219		496,608,918
Total Diluted Earnings Per Share Attributable to AEP Common Shareholders	$ 1.15		$ 1
Common Stock, Dividends Per Share, Declared	$ 0.74		$ 0.70
Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers	$ 2,504.5		$ 2,193
Transmission and Distribution Utilities [Member]
Revenues
Revenue from Contracts with Customers	1,082.3		1,075.2
Generation and Marketing [Member]
Revenues
Revenue from Contracts with Customers	601.7		408.4
Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	92.6		70.9
TOTAL REVENUES	4.8	[1]	19.9	[2]
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold	1,560.7		1,151
AEP Texas Inc. [Member]
Revenues
Sales to AEP Affiliates	1		31.1
TOTAL REVENUES	364.2		423.6
Expenses
Other Operation	122.2		117.5
Maintenance	19.1		20.6
Depreciation and Amortization	97.5		162.5
Taxes Other Than Income Taxes	36.3		34
TOTAL EXPENSES	275.1		334.6
OPERATING INCOME (LOSS)	89.1		89
Other Income (Expense):
Interest Income	0.2		0.6
Allowance for Equity Funds Used During Construction	4.1		5.1
Non-Service Cost Components of Net Periodic Benefit Cost	2.8		2.8
Interest Expense	(43)		(42.5)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS	53.2		55
Income Tax Expense (Benefit)	7.1		7.4
Net Income (Loss)	46.1		47.6
AEP Texas Inc. [Member] | Transmission and Distribution Utilities [Member]
Revenues
Revenue from Contracts with Customers	361.7		391.6
AEP Texas Inc. [Member] | Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	1.5		0.9
TOTAL REVENUES	0	[3]	30.2	[4]
AEP Transmission Co [Member]
Revenues
Sales to AEP Affiliates	285.6		233.7
TOTAL REVENUES	361.7		295.6
Expenses
Other Operation	21.1		23.8
Maintenance	3.6		3.2
Depreciation and Amortization	70.6		56
Taxes Other Than Income Taxes	57.8		50.4
TOTAL EXPENSES	153.1		133.4
OPERATING INCOME (LOSS)	208.6		162.2
Other Income (Expense):
Interest Income	0.1		0.8
Allowance for Equity Funds Used During Construction	16.7		16.2
Interest Expense	(34.1)		(29.6)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS	191.3		149.6
Income Tax Expense (Benefit)	39.6		31.8
Net Income (Loss)	151.7		117.8
AEP Transmission Co [Member] | Transmission [Member]
Revenues
Revenue from Contracts with Customers	76		61.3
AEP Transmission Co [Member] | Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	0.1		0.6
TOTAL REVENUES	0	[3]	0	[4]
Appalachian Power Co [Member]
Revenues
Sales to AEP Affiliates	50.1		49.7
TOTAL REVENUES	817		749.4
Expenses
Other Operation	150.4		134
Maintenance	65.2		50.3
Depreciation and Amortization	135.8		122.2
Taxes Other Than Income Taxes	37.7		37.9
TOTAL EXPENSES	643.1		578
OPERATING INCOME (LOSS)	173.9		171.4
Other Income (Expense):
Interest Income	0.3		0.3
Allowance for Equity Funds Used During Construction	3.5		2.4
Non-Service Cost Components of Net Periodic Benefit Cost	4.7		4.7
Interest Expense	(54.9)		(53.1)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS	127.5		125.7
Income Tax Expense (Benefit)	5		10.4
Net Income (Loss)	122.5		115.3
Appalachian Power Co [Member] | Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers	764.2		697
Appalachian Power Co [Member] | Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	2.7		2.7
TOTAL REVENUES	0.2	[3]	0	[4]
Appalachian Power Co [Member] | Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold	163.9		111
Appalachian Power Co [Member] | Purchased Electricity for Resale [Member]
Expenses
Cost of Goods and Services Sold	90.1		122.6
Indiana Michigan Power Co [Member]
Revenues
Sales to AEP Affiliates	0.8		2.9
Other Revenues - Affiliated	14.3		12.5
TOTAL REVENUES	564.5		570.3
Expenses
Purchased Electricity from AEP Affiliates	51.6		36.2
Other Operation	154.6		144.7
Maintenance	49		49.1
Depreciation and Amortization	109.2		93.9
Taxes Other Than Income Taxes	26.2		26.4
TOTAL EXPENSES	474.2		453.6
OPERATING INCOME (LOSS)	90.3		116.7
Other Income (Expense):
Other Income	3		2.5
Allowance for Equity Funds Used During Construction	3.5		2
Non-Service Cost Components of Net Periodic Benefit Cost	4.1		4.2
Interest Expense	(27.3)		(30.7)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS	70.1		92.7
Income Tax Expense (Benefit)	(0.7)		0.4
Net Income (Loss)	70.8		92.3
Indiana Michigan Power Co [Member] | Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers	547.7		553.4
Indiana Michigan Power Co [Member] | Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	1.7		1.5
Sales to AEP Affiliates	16		16
TOTAL REVENUES	0	[3]	0	[4]
Indiana Michigan Power Co [Member] | Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold	36.3		53.2
Indiana Michigan Power Co [Member] | Purchased Electricity for Resale [Member]
Expenses
Cost of Goods and Services Sold	47.3		50.1
Ohio Power Co [Member]
Revenues
Sales to AEP Affiliates	4.8		8.4
TOTAL REVENUES	723.9		690.3
Expenses
Purchased Electricity from AEP Affiliates	30.1		42.4
Other Operation	184.6		177.3
Maintenance	38.7		31.6
Depreciation and Amortization	75.1		70.5
Taxes Other Than Income Taxes	121.3		112
TOTAL EXPENSES	625.1		582.9
OPERATING INCOME (LOSS)	98.8		107.4
Other Income (Expense):
Interest Income	0.2		0.2
Carrying Costs Income	0.5		0.4
Allowance for Equity Funds Used During Construction	2.7		1.9
Non-Service Cost Components of Net Periodic Benefit Cost	3.7		3.8
Interest Expense	(31.6)		(28.9)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS	74.3		84.8
Income Tax Expense (Benefit)	6.1		9.7
Net Income (Loss)	68.2		75.1
Ohio Power Co [Member] | Transmission and Distribution Utilities [Member]
Revenues
Revenue from Contracts with Customers	716.7		679.2
Ohio Power Co [Member] | Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	2.4		2.7
TOTAL REVENUES	5.3	[3]	6.1	[4]
Ohio Power Co [Member] | Purchased Electricity for Resale [Member]
Expenses
Cost of Goods and Services Sold	175.3		149.1
Public Service Co Of Oklahoma [Member]
Revenues
Sales to AEP Affiliates	1		1.1
TOTAL REVENUES	296.1		297.3
Expenses
Other Operation	79.1		87.2
Maintenance	24.4		24.4
Depreciation and Amortization	49.9		44.7
Taxes Other Than Income Taxes	12.5		11.3
TOTAL EXPENSES	286.8		294.9
OPERATING INCOME (LOSS)	9.3		2.4
Other Income (Expense):
Interest Income	0.1		0.1
Allowance for Equity Funds Used During Construction	0.4		1
Non-Service Cost Components of Net Periodic Benefit Cost	2.1		2.1
Interest Expense	(14.4)		(15.8)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS	(2.5)		(10.2)
Income Tax Expense (Benefit)	0.2		0.1
Net Income (Loss)	(2.7)		(10.3)
Public Service Co Of Oklahoma [Member] | Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers	293.6		295.4
Public Service Co Of Oklahoma [Member] | Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	1.5		0.8
TOTAL REVENUES	0	[3]	0	[4]
Public Service Co Of Oklahoma [Member] | Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold	120.9		127.3
Southwestern Electric Power Co [Member]
Revenues
Sales to AEP Affiliates	7.8		7.5
TOTAL REVENUES	616.1		385.9
Expenses
Other Operation	90.3		92.2
Maintenance	34		33.8
Depreciation and Amortization	69.6		67.3
Taxes Other Than Income Taxes	30		25.3
TOTAL EXPENSES	523.7		350.8
OPERATING INCOME (LOSS)	92.4		35.1
Other Income (Expense):
Interest Income	1		0.6
Allowance for Equity Funds Used During Construction	2.1		1.4
Non-Service Cost Components of Net Periodic Benefit Cost	2.1		2.1
Interest Expense	(29.3)		(30.1)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS	68.3		9.1
Income Tax Expense (Benefit)	5.6		(6.2)
Equity Earnings (Loss) of Unconsolidated Subsidiaries	0.7		0.8
Net Income (Loss)	63.4		16.1
Net Income (Loss) Attributable to Noncontrolling Interests	1		1
Earnings Attributable to Common Shareholders	62.4		15.1
Southwestern Electric Power Co [Member] | Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers	607.7		377.6
Southwestern Electric Power Co [Member] | Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	0.6		0.8
TOTAL REVENUES	0	[3]	0	[4]
Southwestern Electric Power Co [Member] | Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold	$ 299.8		$ 132.2
[1]	Amounts include affiliated and nonaffiliated revenues.
[2]	Amounts include affiliated and nonaffiliated revenues
[3]	Amounts include affiliated and nonaffiliated revenues.
[4]	Amounts include affiliated and nonaffiliated revenues.

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income (Loss) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Net Income (Loss)	$ 578.8	$ 499.3
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	56.3	(67)
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(2)	(1.8)
Other Comprehensive Income (Loss), Net of Tax, Total	54.3	(68.8)
TOTAL COMPREHENSIVE INCOME (LOSS)	633.1	430.5
Total Comprehensive Income (Loss) Attributable to Noncontrolling Interest	3.8	4.1
TOTAL COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	629.3	426.4
Cash Flow Hedges, Tax	15	(17.8)
Amortization of Pension and OPEB Deferred Costs, Tax	$ (0.5)	$ (0.5)
Common Stock, Dividends Per Share, Declared	$ 0.74	$ 0.70
Appalachian Power Co [Member]
Net Income (Loss)	$ 122.5	$ 115.3
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	9	(4.2)
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(1.1)	(0.9)
Other Comprehensive Income (Loss), Net of Tax, Total	7.9	(5.1)
TOTAL COMPREHENSIVE INCOME (LOSS)	130.4	110.2
Cash Flow Hedges, Tax	2.4	(1.1)
Amortization of Pension and OPEB Deferred Costs, Tax	(0.3)	(0.3)
AEP Texas Inc. [Member]
Net Income (Loss)	46.1	47.6
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	0.3	0.3
Other Comprehensive Income (Loss), Net of Tax, Total	0.3	0.3
TOTAL COMPREHENSIVE INCOME (LOSS)	46.4	47.9
Cash Flow Hedges, Tax	0.1	0.1
Indiana Michigan Power Co [Member]
Net Income (Loss)	70.8	92.3
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	0.5	0.4
Other Comprehensive Income (Loss), Net of Tax, Total	0.5	0.4
TOTAL COMPREHENSIVE INCOME (LOSS)	71.3	92.7
Cash Flow Hedges, Tax	0.1	0.1
Ohio Power Co [Member]
Net Income (Loss)	68.2	75.1
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	0	0
TOTAL COMPREHENSIVE INCOME (LOSS)	68.2	75.1
Cash Flow Hedges, Tax	0	0
Public Service Co Of Oklahoma [Member]
Net Income (Loss)	(2.7)	(10.3)
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	(0.1)	(0.2)
Other Comprehensive Income (Loss), Net of Tax, Total	(0.1)	(0.2)
TOTAL COMPREHENSIVE INCOME (LOSS)	(2.8)	(10.5)
Cash Flow Hedges, Tax	0	(0.1)
Southwestern Electric Power Co [Member]
Net Income (Loss)	63.4	16.1
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	0.4	0.4
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(0.4)	(0.4)
Other Comprehensive Income (Loss), Net of Tax, Total	0	0
TOTAL COMPREHENSIVE INCOME (LOSS)	63.4	16.1
Total Comprehensive Income (Loss) Attributable to Noncontrolling Interest	1	1
TOTAL COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	62.4	15.1
Cash Flow Hedges, Tax	0.1	0.1
Amortization of Pension and OPEB Deferred Costs, Tax	(0.1)	(0.1)
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
OTHER COMPREHENSIVE INCOME
Other Comprehensive Income (Loss), Net of Tax, Total	(2)	(1.8)
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | Appalachian Power Co [Member]
OTHER COMPREHENSIVE INCOME
Other Comprehensive Income (Loss), Net of Tax, Total	(1.1)	(0.9)
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | AEP Texas Inc. [Member]
OTHER COMPREHENSIVE INCOME
Other Comprehensive Income (Loss), Net of Tax, Total	0	0
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | Indiana Michigan Power Co [Member]
OTHER COMPREHENSIVE INCOME
Other Comprehensive Income (Loss), Net of Tax, Total	0	0
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | Southwestern Electric Power Co [Member]
OTHER COMPREHENSIVE INCOME
Other Comprehensive Income (Loss), Net of Tax, Total	$ (0.4)	$ (0.4)

Condensed Consolidated Statemen

Condensed Consolidated Statements of Changes in Equity - USD ($) $ in Millions	Total	Generation And Marketing [Member]	Appalachian Power Co [Member]	AEP Texas Inc. [Member]	AEP Transmission Co [Member]	Indiana Michigan Power Co [Member]	Ohio Power Co [Member]	Public Service Co Of Oklahoma [Member]	Southwestern Electric Power Co [Member]	Common Stock [Member]	Common Stock [Member]Appalachian Power Co [Member]	Common Stock [Member]Indiana Michigan Power Co [Member]	Common Stock [Member]Ohio Power Co [Member]	Common Stock [Member]Public Service Co Of Oklahoma [Member]	Common Stock [Member]Southwestern Electric Power Co [Member]	Additional Paid-in Capital [Member]	Additional Paid-in Capital [Member]Appalachian Power Co [Member]	Additional Paid-in Capital [Member]AEP Texas Inc. [Member]	Additional Paid-in Capital [Member]AEP Transmission Co [Member]	Additional Paid-in Capital [Member]Indiana Michigan Power Co [Member]	Additional Paid-in Capital [Member]Ohio Power Co [Member]	Additional Paid-in Capital [Member]Public Service Co Of Oklahoma [Member]	Additional Paid-in Capital [Member]Southwestern Electric Power Co [Member]	Retained Earnings [Member]		Retained Earnings [Member]Appalachian Power Co [Member]	Retained Earnings [Member]AEP Texas Inc. [Member]	Retained Earnings [Member]AEP Transmission Co [Member]	Retained Earnings [Member]Indiana Michigan Power Co [Member]	Retained Earnings [Member]Ohio Power Co [Member]	Retained Earnings [Member]Public Service Co Of Oklahoma [Member]	Retained Earnings [Member]Southwestern Electric Power Co [Member]	Accumulated Other Comprehensive Income [Member]	Accumulated Other Comprehensive Income [Member]Appalachian Power Co [Member]	Accumulated Other Comprehensive Income [Member]AEP Texas Inc. [Member]	Accumulated Other Comprehensive Income [Member]Indiana Michigan Power Co [Member]	Accumulated Other Comprehensive Income [Member]Ohio Power Co [Member]	Accumulated Other Comprehensive Income [Member]Public Service Co Of Oklahoma [Member]	Accumulated Other Comprehensive Income [Member]Southwestern Electric Power Co [Member]	Noncontrolling Interests [Member]	Noncontrolling Interests [Member]Southwestern Electric Power Co [Member]	Dry Lake Solar Project	Dry Lake Solar ProjectNoncontrolling Interests [Member]	Dry Lake Solar ProjectNoncontrolling Interests [Member]Generation And Marketing [Member]
Beginning Balance at Dec. 31, 2019					$ 4,009.5														$ 2,480.6									$ 1,528.9
Beginning Balance at Dec. 31, 2019	$ 19,913.2		$ 4,172.4	$ 2,961.1		$ 2,544.4	$ 2,508.5	$ 1,373.3	$ 2,441.1	$ 3,343.4	$ 260.4	$ 56.6	$ 321.2	$ 157.2	$ 135.7	$ 6,535.6	$ 1,828.7	$ 1,457.9		$ 980.9	$ 838.8	$ 364	$ 676.6	$ 9,900.9		$ 2,078.3	$ 1,516		$ 1,518.5	$ 1,348.5	$ 851	$ 1,629.5	$ (147.7)	$ 5	$ (12.8)	$ (11.6)	$ 0	$ 1.1	$ (1.3)	$ 281	$ 0.6
Beginning Balance, Shares at Dec. 31, 2019										514,400,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of Common Stock, Value	56.1									$ 6.8						49.3
Issuance of Common Stock, Shares										1,000,000
Common Stock Dividends	(363.7)																							(359.1)	[1]
Common Stock Dividends			(50)			(21.3)	(21.9)																			(50)			(21.3)	(21.9)
Common Stock Dividends									(0.7)																															(4.6)	(0.7)
Other Changes in Equity	(30.2)															(29)																								(1.2)
Stockholders Equity ASU 2016-13 Adoption	(1.8)					0.4	0.3	0.3																(1.8)					0.4	0.3	0.3
Capital Contribution from Member					185														185
Dividends Paid on Common Stock			(50)			(21.3)	(21.9)
Net Income (Loss)	495.2								15.1															495.2								15.1
Net Income (Loss) Attributable to Noncontrolling Interests	4.1								1																															4.1	1
Net Income (Loss)	499.3	$ 30.5	115.3	47.6	117.8	92.3	75.1	(10.3)	16.1																	115.3	47.6	117.8	92.3	75.1	(10.3)
Other Comprehensive Income (Loss)	(68.8)		(5.1)	0.3		0.4		(0.2)	0																								(68.8)	(5.1)	0.3	0.4		(0.2)
Ending Balance at Mar. 31, 2020					4,312.3														2,665.6									1,646.7
Ending Balance at Mar. 31, 2020	$ 20,007.7		4,232.6	3,009		2,616.2	2,562	1,363.1	2,458.1	$ 3,350.2	260.4	56.6	321.2	157.2	135.7	6,555.9	1,828.7	1,457.9		980.9	838.8	364	676.6	10,038.8		2,143.6	1,563.6		1,589.9	1,402	841	1,646.2	(216.5)	(0.1)	(12.5)	(11.2)	0	0.9	(1.3)	279.3	0.9
Ending Balance, Shares at Mar. 31, 2020										515,400,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Dividends Per Share, Declared	$ 0.70
Beginning Balance at Dec. 31, 2020					4,712.9														2,765.6									1,947.3
Beginning Balance at Dec. 31, 2020	$ 20,774.5		4,344.3	3,206		2,749.2	2,692.7	$ 1,545.6	2,627.7	$ 3,359.3	260.4	56.6	321.2	157.2	0.1	6,588.9	1,828.7	1,457.9		980.9	838.8	414	812.2	10,687.8		2,248	1,757		1,718.7	1,532.7	974.3	1,811.9	(85.1)	7.2	(8.9)	(7)	0	0.1	1.9	223.6	1.6
Beginning Balance, Shares at Dec. 31, 2020	516,808,354							10,482,000		516,800,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of Common Stock, Value	$ 184.6									$ 17.1						167.5
Issuance of Common Stock, Shares										2,700,000
Common Stock Dividends	(372)																							(369.5)	[1]
Common Stock Dividends			(12.5)			(25)	(21.9)																			(12.5)			(25)	(21.9)
Common Stock Dividends									(1)																															(2.5)	(1)
Other Changes in Equity	(19.1)															(21.9)								(0.6)																3.4
Stockholders Equity ASU 2016-13 Adoption									1.6																							1.6
Capital Contribution from Member					124			$ 425	100										124			425	100
Acquisition																																										$ 18.9	$ 18.9	$ 19
Dividends Paid on Common Stock			(12.5)			(25)	(21.9)
Net Income (Loss)	575								62.4															575								62.4
Net Income (Loss) Attributable to Noncontrolling Interests	3.8								1																															3.8	1
Net Income (Loss)	578.8	$ 38.2	122.5	46.1	151.7	70.8	68.2	(2.7)	63.4																	122.5	46.1	151.7	70.8	68.2	(2.7)
Other Comprehensive Income (Loss)	54.3		7.9	0.3		0.5		(0.1)	0																								54.3	7.9	0.3	0.5		(0.1)
Ending Balance at Mar. 31, 2021					$ 4,988.6														$ 2,889.6									$ 2,099
Ending Balance at Mar. 31, 2021	$ 21,220		$ 4,462.2	$ 3,252.4		$ 2,795.5	$ 2,739	$ 1,967.8	$ 2,790.1	$ 3,376.4	$ 260.4	$ 56.6	$ 321.2	$ 157.2	$ 0.1	$ 6,734.5	$ 1,828.7	$ 1,457.9		$ 980.9	$ 838.8	$ 839	$ 912.2	$ 10,892.7		$ 2,358	$ 1,803.1		$ 1,764.5	$ 1,579	$ 971.6	$ 1,874.3	$ (30.8)	$ 15.1	$ (8.6)	$ (6.5)	$ 0	$ 0	$ 1.9	$ 247.2	$ 1.6
Ending Balance, Shares at Mar. 31, 2021	519,450,026							10,482,000		519,500,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Dividends Per Share, Declared	$ 0.74
[1]	(a)    Cash dividends declared per AEP common share were $0.74 and $0.70 for the three months ended March 31, 2021 and 2020.

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Millions		Mar. 31, 2021	Dec. 31, 2020
Current Assets
Cash and Cash Equivalents		$ 273.2	$ 392.7
Restricted Cash		50.8	45.6
Other Temporary Investments		199.1	200.8
Accounts Receivable:
Customers		763	613.6
Accrued Unbilled Revenues		199.9	248.7
Pledged Accounts Receivable - AEP Credit		919	1,018.4
Miscellaneous		36.1	33.1
Allowance for Uncollectible Accounts		(59.6)	(71.1)
Total Accounts Receivable		1,858.4	1,842.7
Fuel		588.6	629.4
Materials and Supplies		683.3	680.6
Risk Management Assets		72.1	94.7
Accrued Tax Benefits		187.6	185.3
Regulatory Asset for Under-Recovered Fuel Costs		129.8	90.7
Margin Deposits		91	62
Prepayments and Other Current Assets		124.5	127
TOTAL CURRENT ASSETS		4,258.4	4,351.5
Property, Plant and Equipment
Generation		23,186.5	23,133.9
Transmission		28,359.9	27,886.7
Distribution		24,311.8	23,972.1
Other Property, Plant and Equipment		5,465.2	5,294.6
Construction Work in Progress		4,289.5	4,025.7
Total Property, Plant and Equipment		85,612.9	84,313
Accumulated Depreciation and Amortization		20,916.8	20,411.4
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		64,696.1	63,901.6
Other Noncurrent Assets
Regulatory Assets		4,885.6	3,527
Securitized Assets		632.5	657
Spent Nuclear Fuel and Decommissioning Trusts		3,414.3	3,306.7
Goodwill		52.5	52.5
Long-term Risk Management Assets		264.8	242.2
Operating Lease Assets		818.9	866.4
Deferred Charges and Other Noncurrent Assets		3,962	3,852.3
TOTAL OTHER NONCURRENT ASSETS		14,030.6	12,504.1
TOTAL ASSETS		82,985.1	80,757.2
Current Liabilities
Accounts Payable		1,703.9	1,709.7
Short-term Debt:
Securitized Debt for Receivables - AEP Credit	[1]	669	592
Other Short-term Debt		2,379.4	1,887.3
Total Short-term Debt		3,048.4	2,479.3
Long-term Debt Due Within One Year		2,130.2	2,086.1
Risk Management Liabilities		39.1	78.8
Customer Deposits		331	335.6
Accrued Taxes		1,397.9	1,476.4
Accrued Interest		324.2	267.6
Obligations Under Operating Leases		240.6	241.3
Regulatory Liability for Over-Recovered Fuel Costs		39.1	52.6
Other Current Liabilities		965.7	1,199.3
TOTAL CURRENT LIABILITIES		10,220.1	9,926.7
Noncurrent Liabilities
Long-term Debt		30,214.8	28,986.4
Affiliated Long Term Debt Noncurrent		0	0
Long-term Risk Management Liabilities		273	232.8
Deferred Income Taxes		8,349.9	8,240.9
Regulatory Liabilities and Deferred Investment Tax Credits		8,466.1	8,378.7
Asset Retirement Obligations		2,483.7	2,469.2
Employee Benefits and Pension Obligations		343.4	336.4
Obligations Under Operating Leases		625.1	638.4
Deferred Credits and Other Noncurrent Liabilities		733.7	728
TOTAL NONCURRENT LIABILITIES		51,489.7	50,010.8
TOTAL LIABILITIES		61,709.8	59,937.5
Rate Matters
Commitments and Contingencies
Contingently Reedemable Performance Share Awards		55.3	45.2
Total Mezzanine Equity		55.3	45.2
Equity
Common Stock		3,376.4	3,359.3
Paid-in Capital		6,734.5	6,588.9
Retained Earnings		10,892.7	10,687.8
Accumulated Other Comprehensive Income (Loss)		(30.8)	(85.1)
TOTAL COMMON SHAREHOLDER'S EQUITY		20,972.8	20,550.9
Noncontrolling Interests		247.2	223.6
TOTAL EQUITY		21,220	20,774.5
TOTAL LIABILITIES AND EQUITY		$ 82,985.1	$ 80,757.2
Common Stock, No Par Value		$ 6.50	$ 6.50
Common Stock, Shares Authorized		600,000,000	600,000,000
Treasury Stock, Shares		20,204,160	20,204,160
Common Stock, Shares, Issued		519,450,026	516,808,354
Commodity [Member]
Equity
Cross Default Provisions Maximum Third Party Obligation Amount		$ 50	$ 50
Subsidiaries [Member]
Current Assets
Restricted Cash		50.8	45.6
Other Temporary Investments		191.7	194.6
Short-term Debt:
Long-term Debt Due Within One Year		192.3	198.3
Noncurrent Liabilities
Long-term Debt		921.1	950.1
AEP Texas Inc. [Member]
Current Assets
Cash and Cash Equivalents		0.1	0.1
Restricted Cash		39.3	28.7
Advances to Affiliates		6.8	7.1
Accounts Receivable:
Customers		129.3	112.8
Affiliated Companies - Contracts with Customers		7.2	5.1
Accrued Unbilled Revenues		58.2	65.8
Allowance for Uncollectible Accounts		(4.3)	(0.1)
Total Accounts Receivable		190.4	183.6
Materials and Supplies		69.8	70
Accrued Tax Benefits		11.4	16.8
Prepayments and Other Current Assets		4.7	4.6
TOTAL CURRENT ASSETS		322.5	310.9
Property, Plant and Equipment
Transmission		5,434.7	5,279.6
Distribution		4,654.2	4,580.8
Other Property, Plant and Equipment		885	868.4
Construction Work in Progress		567.8	614.1
Total Property, Plant and Equipment		11,541.7	11,342.9
Accumulated Depreciation and Amortization		1,565.9	1,529.3
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		9,975.8	9,813.6
Other Noncurrent Assets
Regulatory Assets		274.5	266.8
Securitized Assets		428.6	446.8
Deferred Charges and Other Noncurrent Assets		261.6	192.1
TOTAL OTHER NONCURRENT ASSETS		964.7	905.7
TOTAL ASSETS		11,263	11,030.2
Current Liabilities
Advances from Affiliates		284	67.1
Accounts Payable		198.8	231.7
Affiliated Companies		24.4	44
Short-term Debt:
Long-term Debt Due Within One Year		88.9	88.7
Accrued Taxes		107.1	78.3
Accrued Interest		54.7	43.9
Obligations Under Operating Leases		14.5	14.5
Other Current Liabilities		83.4	108.6
TOTAL CURRENT LIABILITIES		855.8	676.8
Noncurrent Liabilities
Long-term Debt		4,721.3	4,731.7
Deferred Income Taxes		1,024.3	1,016.7
Regulatory Liabilities and Deferred Investment Tax Credits		1,272	1,270.8
Obligations Under Operating Leases		68.9	71
Deferred Credits and Other Noncurrent Liabilities		68.3	57.2
TOTAL NONCURRENT LIABILITIES		7,154.8	7,147.4
TOTAL LIABILITIES		8,010.6	7,824.2
Rate Matters
Commitments and Contingencies
Equity
Paid-in Capital		1,457.9	1,457.9
Retained Earnings		1,803.1	1,757
Accumulated Other Comprehensive Income (Loss)		(8.6)	(8.9)
TOTAL EQUITY		3,252.4	3,206
TOTAL LIABILITIES AND EQUITY		11,263	11,030.2
AEP Texas Inc. [Member] | AEP Texas Transition Funding and Restoration Funding [Member]
Current Assets
Restricted Cash		39.3	28.7
Other Noncurrent Assets
Securitized Assets		428.6	446.8
Short-term Debt:
Long-term Debt Due Within One Year		88.9	88.7
Accrued Interest		3.2	2.5
Noncurrent Liabilities
Long-term Debt		392.7	403.9
AEP Transmission Co [Member]
Current Assets
Cash and Cash Equivalents		0	0
Advances to Affiliates		106.1	109.1
Accounts Receivable:
Customers		25.6	22.9
Affiliated Companies - Contracts with Customers		95	81.2
Total Accounts Receivable		120.6	104.1
Materials and Supplies		8.8	8.5
Prepayments and Other Current Assets		3.4	14.1
TOTAL CURRENT ASSETS		238.9	235.8
Property, Plant and Equipment
Transmission		9,788.3	9,593.5
Other Property, Plant and Equipment		356.2	329.5
Construction Work in Progress		1,549.5	1,422.6
Total Property, Plant and Equipment		11,694	11,345.6
Accumulated Depreciation and Amortization		623.6	572.8
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		11,070.4	10,772.8
Other Noncurrent Assets
Regulatory Assets		14	15.1
Deferred Property Taxes		190.1	220.1
Deferred Charges and Other Noncurrent Assets		1.7	2.2
TOTAL OTHER NONCURRENT ASSETS		205.8	237.4
TOTAL ASSETS		11,515.1	11,246
Current Liabilities
Advances from Affiliates		229.3	156.7
Accounts Payable		325.3	380.4
Affiliated Companies		72.2	97.3
Short-term Debt:
Long-term Debt Due Within One Year		50	50
Accrued Taxes		373.2	418.1
Accrued Interest		48.2	23.9
Obligations Under Operating Leases		0.8	1.2
Other Current Liabilities		12.3	9.9
TOTAL CURRENT LIABILITIES		1,111.3	1,137.5
Noncurrent Liabilities
Long-term Debt		3,899	3,898.5
Deferred Income Taxes		917.2	906.9
Regulatory Liabilities and Deferred Investment Tax Credits		597.1	581.8
Obligations Under Operating Leases		0.4	0.4
Deferred Credits and Other Noncurrent Liabilities		1.5	8
TOTAL NONCURRENT LIABILITIES		5,415.2	5,395.6
TOTAL LIABILITIES		6,526.5	6,533.1
Rate Matters
Commitments and Contingencies
Equity
Paid-in Captial		2,889.6	2,765.6
Retained Earnings		2,099	1,947.3
TOTAL MEMBER'S EQUITY		4,988.6	4,712.9
TOTAL LIABILITIES AND EQUITY		11,515.1	11,246
Appalachian Power Co [Member]
Current Assets
Cash and Cash Equivalents		4.8	5.8
Restricted Cash		11.6	16.9
Advances to Affiliates		261.1	21.4
Accounts Receivable:
Customers		146.4	142.8
Affiliated Companies - Contracts with Customers		64.9	64.3
Accrued Unbilled Revenues		50.7	80.1
Miscellaneous		0.3	0.3
Allowance for Uncollectible Accounts		(2.1)	(3.1)
Total Accounts Receivable		260.2	284.4
Fuel		166.9	193.6
Materials and Supplies		101.2	99.6
Risk Management Assets		6.9	22.4
Regulatory Asset for Under-Recovered Fuel Costs		15.3	5.3
Prepayments and Other Current Assets		24.7	24.7
TOTAL CURRENT ASSETS		852.7	674.1
Property, Plant and Equipment
Generation		6,643.9	6,633.7
Transmission		3,931.7	3,900.5
Distribution		4,511.5	4,464.3
Other Property, Plant and Equipment		644.2	627.2
Construction Work in Progress		525.9	484.6
Total Property, Plant and Equipment		16,257.2	16,110.3
Accumulated Depreciation and Amortization		4,802	4,716.2
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		11,455.2	11,394.1
Other Noncurrent Assets
Regulatory Assets		727.1	686.3
Securitized Assets		203.9	210.1
Employee Benefits and Pension Assets		152.3	150.1
Operating Lease Assets		76.3	78.8
Deferred Charges and Other Noncurrent Assets		130.1	121.7
TOTAL OTHER NONCURRENT ASSETS		1,289.7	1,247
TOTAL ASSETS		13,597.6	13,315.2
Current Liabilities
Advances from Affiliates		0	18.6
Accounts Payable		247.1	212
Affiliated Companies		99.3	97.1
Short-term Debt:
Long-term Debt Due Within One Year		168.5	518.3
Customer Deposits		75	77.8
Accrued Taxes		114.4	109.9
Accrued Interest		73.8	49.9
Obligations Under Operating Leases		14.9	14.9
Other Current Liabilities		107.9	119.2
TOTAL CURRENT LIABILITIES		900.9	1,217.7
Noncurrent Liabilities
Long-term Debt		4,797.7	4,315.8
Deferred Income Taxes		1,763.1	1,749.9
Regulatory Liabilities and Deferred Investment Tax Credits		1,215.6	1,224.7
Asset Retirement Obligations		305.5	304.8
Employee Benefits and Pension Obligations		44	44
Obligations Under Operating Leases		61.9	64.4
Deferred Credits and Other Noncurrent Liabilities		46.7	49.6
TOTAL NONCURRENT LIABILITIES		8,234.5	7,753.2
TOTAL LIABILITIES		9,135.4	8,970.9
Rate Matters
Commitments and Contingencies
Equity
Common Stock		260.4	260.4
Paid-in Capital		1,828.7	1,828.7
Retained Earnings		2,358	2,248
Accumulated Other Comprehensive Income (Loss)		15.1	7.2
TOTAL EQUITY		4,462.2	4,344.3
TOTAL LIABILITIES AND EQUITY		$ 13,597.6	$ 13,315.2
Common Stock, No Par Value		$ 0	$ 0
Common Stock, Shares Authorized		30,000,000	30,000,000
Common Stock, Shares, Outstanding		13,499,500	13,499,500
Indiana Michigan Power Co [Member]
Current Assets
Cash and Cash Equivalents		$ 2.8	$ 3.3
Advances to Affiliates		13.3	13.3
Accounts Receivable:
Customers		32.7	44
Affiliated Companies - Contracts with Customers		48.8	51.3
Accrued Unbilled Revenues		0.4	0
Miscellaneous		1.6	2
Allowance for Uncollectible Accounts		(0.4)	(0.3)
Total Accounts Receivable		83.1	97
Fuel		80.2	86
Materials and Supplies		172.8	175.8
Risk Management Assets		0.9	3.6
Accrued Tax Benefits		1	10.3
Regulatory Asset for Under-Recovered Fuel Costs		3.2	5.4
Prepayments and Other Current Assets		17.9	24.1
TOTAL CURRENT ASSETS		375.2	418.8
Property, Plant and Equipment
Generation		5,302.4	5,264.7
Transmission		1,696.9	1,696.4
Distribution		2,634.3	2,594.6
Other Property, Plant and Equipment		707.4	686.7
Construction Work in Progress		369.5	362.4
Total Property, Plant and Equipment		10,710.5	10,604.8
Accumulated Depreciation and Amortization		3,647.3	3,552.5
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		7,063.2	7,052.3
Other Noncurrent Assets
Regulatory Assets		403.4	404.8
Spent Nuclear Fuel and Decommissioning Trusts		3,414.3	3,306.7
Operating Lease Assets		196.8	218.1
Deferred Charges and Other Noncurrent Assets		241.3	237.6
TOTAL OTHER NONCURRENT ASSETS		4,255.8	4,167.2
TOTAL ASSETS		11,694.2	11,638.3
Current Liabilities
Advances from Affiliates		124.6	103
Accounts Payable		113.7	153.2
Affiliated Companies		70.9	80.5
Short-term Debt:
Long-term Debt Due Within One Year		363.1	369.6
Customer Deposits		43.5	41.7
Accrued Taxes		114.8	102.5
Accrued Interest		19.7	35.6
Obligations Under Operating Leases		85.5	85.6
Regulatory Liability for Over-Recovered Fuel Costs		9.3	20.8
Other Current Liabilities		82.6	112
TOTAL CURRENT LIABILITIES		1,027.7	1,104.5
Noncurrent Liabilities
Long-term Debt		2,643.2	2,660.3
Deferred Income Taxes		1,064.9	1,064.4
Regulatory Liabilities and Deferred Investment Tax Credits		2,111.8	2,041.9
Asset Retirement Obligations		1,830.9	1,812.9
Obligations Under Operating Leases		131.3	135.9
Deferred Credits and Other Noncurrent Liabilities		88.9	69.2
TOTAL NONCURRENT LIABILITIES		7,871	7,784.6
TOTAL LIABILITIES		8,898.7	8,889.1
Rate Matters
Commitments and Contingencies
Equity
Common Stock		56.6	56.6
Paid-in Capital		980.9	980.9
Retained Earnings		1,764.5	1,718.7
Accumulated Other Comprehensive Income (Loss)		(6.5)	(7)
TOTAL EQUITY		2,795.5	2,749.2
TOTAL LIABILITIES AND EQUITY		$ 11,694.2	$ 11,638.3
Common Stock, No Par Value		$ 0	$ 0
Common Stock, Shares Authorized		2,500,000	2,500,000
Common Stock, Shares, Outstanding		1,400,000	1,400,000
Indiana Michigan Power Co [Member] | DCC Fuel [Member]
Short-term Debt:
Long-term Debt Due Within One Year		$ 69.2	$ 75.7
Ohio Power Co [Member]
Current Assets
Cash and Cash Equivalents		6.1	7.4
Advances to Affiliates		0.5	0
Accounts Receivable:
Customers		66.1	50
Affiliated Companies - Contracts with Customers		78.3	65.1
Accrued Unbilled Revenues		15.3	14.8
Miscellaneous		7.2	3.9
Allowance for Uncollectible Accounts		(0.7)	(0.6)
Total Accounts Receivable		166.2	133.2
Materials and Supplies		67.3	66.9
Renewable Energy Credits		32	29.5
Prepayments and Other Current Assets		22.4	19.3
TOTAL CURRENT ASSETS		294.5	256.3
Property, Plant and Equipment
Transmission		2,862.7	2,831.9
Distribution		5,806.3	5,708.3
Other Property, Plant and Equipment		938.3	899.6
Construction Work in Progress		343.8	362.3
Total Property, Plant and Equipment		9,951.1	9,802.1
Accumulated Depreciation and Amortization		2,385.4	2,350
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		7,565.7	7,452.1
Other Noncurrent Assets
Regulatory Assets		392.3	385.8
Deferred Charges and Other Noncurrent Assets		536.2	616.2
TOTAL OTHER NONCURRENT ASSETS		928.5	1,002
TOTAL ASSETS		8,788.7	8,710.4
Current Liabilities
Advances from Affiliates		0	259.2
Accounts Payable		174.5	181
Affiliated Companies		117.7	118.4
Short-term Debt:
Long-term Debt Due Within One Year		500.1	500.1
Risk Management Liabilities		8.1	8.7
Customer Deposits		54.3	55.1
Accrued Taxes		484.7	631
Obligations Under Operating Leases		13.1	13.1
Other Current Liabilities		132	139.6
TOTAL CURRENT LIABILITIES		1,484.5	1,906.2
Noncurrent Liabilities
Long-term Debt		2,376.2	1,930.1
Long-term Risk Management Liabilities		95.9	101.6
Deferred Income Taxes		968.8	955.1
Regulatory Liabilities and Deferred Investment Tax Credits		1,008.4	1,005.2
Obligations Under Operating Leases		77	79.5
Deferred Credits and Other Noncurrent Liabilities		38.9	40
TOTAL NONCURRENT LIABILITIES		4,565.2	4,111.5
TOTAL LIABILITIES		6,049.7	6,017.7
Rate Matters
Commitments and Contingencies
Equity
Common Stock		321.2	321.2
Paid-in Capital		838.8	838.8
Retained Earnings		1,579	1,532.7
TOTAL EQUITY		2,739	2,692.7
TOTAL LIABILITIES AND EQUITY		$ 8,788.7	$ 8,710.4
Common Stock, No Par Value		$ 0	$ 0
Common Stock, Shares Authorized		40,000,000	40,000,000
Common Stock, Shares, Outstanding		27,952,473	27,952,473
Public Service Co Of Oklahoma [Member]
Current Assets
Cash and Cash Equivalents		$ 2.4	$ 2.6
Accounts Receivable:
Customers		37.7	30.8
Affiliated Companies - Contracts with Customers		21.8	15.6
Miscellaneous		0.1	2
Total Accounts Receivable		59.6	48.4
Fuel		14.1	17.9
Materials and Supplies		53.3	54
Risk Management Assets		5.5	10.3
Accrued Tax Benefits		9.9	10.9
Regulatory Asset for Under-Recovered Fuel Costs		44.8	30.1
Prepayments and Other Current Assets		7.4	7.1
TOTAL CURRENT ASSETS		197	181.3
Property, Plant and Equipment
Generation		1,481.7	1,480.7
Transmission		1,082	1,069.9
Distribution		2,896.4	2,853
Other Property, Plant and Equipment		411	393.3
Construction Work in Progress		98.2	128.7
Total Property, Plant and Equipment		5,969.3	5,925.6
Accumulated Depreciation and Amortization		1,626	1,605.6
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		4,343.3	4,320
Other Noncurrent Assets
Regulatory Assets		1,067.6	375
Employee Benefits and Pension Assets		65.9	65.8
Operating Lease Assets		42.4	42.6
Deferred Charges and Other Noncurrent Assets		39.6	6
TOTAL OTHER NONCURRENT ASSETS		1,215.5	489.4
TOTAL ASSETS		5,755.8	4,990.7
Current Liabilities
Advances from Affiliates		245.7	155.4
Accounts Payable		107.4	107
Affiliated Companies		49.6	43.4
Short-term Debt:
Long-term Debt Due Within One Year		0.5	0.5
Customer Deposits		53.6	54.8
Accrued Taxes		48.2	26.8
Obligations Under Operating Leases		6.6	6.5
Other Current Liabilities		57.6	84.2
TOTAL CURRENT LIABILITIES		569.2	478.6
Noncurrent Liabilities
Long-term Debt		1,623.3	1,373.3
Deferred Income Taxes		693.7	688.5
Regulatory Liabilities and Deferred Investment Tax Credits		799.7	802.2
Asset Retirement Obligations		46	45.7
Obligations Under Operating Leases		35.8	36.2
Deferred Credits and Other Noncurrent Liabilities		20.3	20.6
TOTAL NONCURRENT LIABILITIES		3,218.8	2,966.5
TOTAL LIABILITIES		3,788	3,445.1
Rate Matters
Commitments and Contingencies
Equity
Common Stock		157.2	157.2
Paid-in Capital		839	414
Retained Earnings		971.6	974.3
Accumulated Other Comprehensive Income (Loss)		0	0.1
TOTAL EQUITY		1,967.8	1,545.6
TOTAL LIABILITIES AND EQUITY		$ 5,755.8	$ 4,990.7
Common Stock, Shares Authorized		11,000,000	11,000,000
Common Stock, Shares, Outstanding		9,013,000	9,013,000
Common Stock, Par or Stated Value Per Share		$ 15	$ 15
Common Stock, Shares, Issued		10,482,000	10,482,000
Southwestern Electric Power Co [Member]
Current Assets
Cash and Cash Equivalents		$ 18.2	$ 13.2
Advances to Affiliates		2.1	2.1
Accounts Receivable:
Customers		119.4	27.1
Affiliated Companies - Contracts with Customers		34.6	25.1
Miscellaneous		16.7	12.7
Total Accounts Receivable		170.7	64.9
Fuel		195.6	191.1
Materials and Supplies		93	95.8
Risk Management Assets		1.3	3.2
Accrued Tax Benefits		36.3	29.9
Regulatory Asset for Under-Recovered Fuel Costs		5.8	2.6
Prepayments and Other Current Assets		17.9	25.2
TOTAL CURRENT ASSETS		540.9	428
Property, Plant and Equipment
Generation		4,679.8	4,681.4
Transmission		2,203.3	2,165.7
Distribution		2,403.1	2,382.5
Other Property, Plant and Equipment		803.9	788.8
Construction Work in Progress		232.4	228.3
Total Property, Plant and Equipment		10,322.5	10,246.7
Accumulated Depreciation and Amortization		3,275.2	3,158.5
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		7,047.3	7,088.2
Other Noncurrent Assets
Regulatory Assets		988.2	403.1
Deferred Charges and Other Noncurrent Assets		291.3	234.8
TOTAL OTHER NONCURRENT ASSETS		1,279.5	637.9
TOTAL ASSETS		8,867.7	8,154.1
Current Liabilities
Advances from Affiliates		86.9	124.6
Accounts Payable		219.7	135.9
Affiliated Companies		51.2	43
Short-term Debt:
Other Short-term Debt		5	35
Long-term Debt Due Within One Year		381.2	106.2
Risk Management Liabilities		0	0.7
Customer Deposits		60.3	61.3
Accrued Taxes		121.3	41
Accrued Interest		22.3	34.6
Obligations Under Operating Leases		8	7.9
Other Current Liabilities		127.7	173.4
TOTAL CURRENT LIABILITIES		1,083.6	763.6
Noncurrent Liabilities
Long-term Debt		2,750.2	2,530.2
Long-term Risk Management Liabilities		0.9	1
Deferred Income Taxes		1,017.4	1,017.6
Regulatory Liabilities and Deferred Investment Tax Credits		878.5	863.4
Asset Retirement Obligations		191.9	193.7
Employee Benefits and Pension Obligations		21.6	18.6
Obligations Under Operating Leases		44.3	44.1
Deferred Credits and Other Noncurrent Liabilities		89.2	94.2
TOTAL NONCURRENT LIABILITIES		4,994	4,762.8
TOTAL LIABILITIES		6,077.6	5,526.4
Rate Matters
Commitments and Contingencies
Equity
Common Stock		0.1	0.1
Paid-in Capital		912.2	812.2
Retained Earnings		1,874.3	1,811.9
Accumulated Other Comprehensive Income (Loss)		1.9	1.9
TOTAL COMMON SHAREHOLDER'S EQUITY		2,788.5	2,626.1
Noncontrolling Interests		1.6	1.6
TOTAL EQUITY		2,790.1	2,627.7
TOTAL LIABILITIES AND EQUITY		$ 8,867.7	$ 8,154.1
Common Stock, No Par Value		$ 18	$ 18
Common Stock, Shares Authorized		3,680	3,680
Common Stock, Shares, Outstanding		3,680	3,680
Southwestern Electric Power Co [Member] | Sabine Mining Co [Member]
Current Assets
Cash and Cash Equivalents		$ 14.7	$ 10.1
Accounts Receivable:
Fuel		17.2	35.2
Materials and Supplies		21.8	23.3
Property, Plant and Equipment
Other Property, Plant and Equipment		223.8	223.7
Accumulated Depreciation and Amortization		$ 137.7	$ 126.5
[1]	Amount of securitized debt for receivables as accounted for under the “Transfers and Servicing” accounting guidance.

Condensed Consolidated Statem_2

Condensed Consolidated Statements of Cash Flows - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Operating Activities
Net Income (Loss)	$ 578.8	$ 499.3
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	696.3	672.2
Rockport Plant, Unit 2 Operating Lease Amortization	32.8	34.1
Deferred Income Taxes	44.3	27.9
Allowance for Equity Funds Used During Construction	(33.4)	(31.4)
Mark-to-Market of Risk Management Contracts	21	57.4
Amortization of Nuclear Fuel	22.7	23.4
Property Taxes	(74.8)	(59.8)
Deferred Fuel Over/Under-Recovery, Net	(1,225.1)	63.1
Change in Other Noncurrent Assets	(168.9)	(84.9)
Change in Other Noncurrent Liabilities	83.5	(74.8)
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(12.9)	(32.6)
Fuel, Materials and Supplies	39.5	(35.8)
Accounts Payable	171.8	(111.1)
Accrued Taxes, Net	(80.8)	(93.9)
Other Current Assets	(26.3)	5.3
Other Current Liabilities	(185.7)	(242.7)
Net Cash Flows from (Used for) Operating Activities	(117.2)	615.7
Investing Activities
Construction Expenditures	(1,492.7)	(1,792.7)
Purchases of Investment Securities	(337.6)	(632.7)
Sales of Investment Securities	325.5	635.6
Acquisitions of Nuclear Fuel	(55.9)	(1.3)
Acquisitions of Assets	(102.9)	0
Other Investing Activities	29.4	25.1
Net Cash Flows from (Used for) Investing Activities	(1,634.2)	(1,766)
Financing Activities
Issuance of Common Stock	184.6	56.1
Issuance of Long-term Debt	1,951.5	1,418.9
Issuance of Short-term Debt with Original Maturities greater than 90 Days	644.2	1,297.5
Change in Short-term Debt with Original Maturities less than 90 Days, Net	16.9	328.3
Retirement of Long-term Debt	(650.7)	(300.5)
Redemption of Short-term Debt with Original Maturities Greater than 90 Days	(92)	0
Principal Payments for Finance Leases Obligations	(15)	(15.4)
Dividends Paid on Common Stock	(372)	(363.7)
Other Financing Activities	(30.4)	(32.7)
Net Cash Flows from (Used for) Financing Activities	1,637.1	2,388.5
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(114.3)	1,238.2
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	438.3	432.6
Cash and Cash Equivalents at Beginning of Period	392.7
Cash, Cash Equivalents and Restricted Cash at End of Period	324	1,670.8
Cash and Cash Equivalents at End of Period	273.2
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	220.5	212.6
Net Cash Paid (Received) for Income Taxes	(0.2)	(0.6)
Noncash Acquisitions Under Finance Leases	9	19.4
Construction Expenditures Included in Current Liabilities as of March 31,	762.7	874.1
Construction Expenditures Included in Noncurrent Liabilities as of March 31,	0	8.3
Acquisition of Nuclear Fuel Included in Current Liabilities as of March 31,	6.7	0
Expected Reimbursement for Spent Nuclear Fuel Dry Cask Storage	0.1	1.3
AEP Texas Inc. [Member]
Operating Activities
Net Income (Loss)	46.1	47.6
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	97.5	162.5
Deferred Income Taxes	1.7	(7.6)
Allowance for Equity Funds Used During Construction	(4.1)	(5.1)
Property Taxes	(71.1)	(69.3)
Change in Other Noncurrent Assets	(14.8)	(10.8)
Change in Other Noncurrent Liabilities	14.7	3.2
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(6.8)	(34.3)
Fuel, Materials and Supplies	0.3	(7.6)
Accounts Payable	1.4	2.4
Accrued Taxes, Net	34.1	38.9
Other Current Assets	0.3	(1.4)
Other Current Liabilities	(15.2)	(4.6)
Net Cash Flows from (Used for) Operating Activities	84.1	113.9
Investing Activities
Construction Expenditures	(295.1)	(327.5)
Change in Advances to Affiliates, Net	0.3	200.1
Other Investing Activities	17	7.4
Net Cash Flows from (Used for) Investing Activities	(277.8)	(120)
Financing Activities
Change in Advances from Affiliates, Net	216.9	63.9
Retirement of Long-term Debt	(11.2)	(114.3)
Principal Payments for Finance Leases Obligations	(1.7)	(1.5)
Other Financing Activities	0.3	0.4
Net Cash Flows from (Used for) Financing Activities	204.3	(51.5)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	10.6	(57.6)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	28.8	157.8
Cash and Cash Equivalents at Beginning of Period	0.1
Cash, Cash Equivalents and Restricted Cash at End of Period	39.4	100.2
Cash and Cash Equivalents at End of Period	0.1
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	30	21.1
Noncash Acquisitions Under Finance Leases	0.8	3.7
Construction Expenditures Included in Current Liabilities as of March 31,	120.5	175.1
AEP Transmission Co [Member]
Operating Activities
Net Income (Loss)	151.7	117.8
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	70.6	56
Deferred Income Taxes	8.3	13.7
Allowance for Equity Funds Used During Construction	(16.7)	(16.2)
Property Taxes	30	28.4
Change in Other Noncurrent Assets	1.4	2.4
Change in Other Noncurrent Liabilities	0.6	0.6
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(16.5)	(22)
Fuel, Materials and Supplies	(0.3)	0.4
Accounts Payable	(18.9)	22.7
Accrued Taxes, Net	(35.1)	(37.8)
Accrued Interest	24.3	19.4
Other Current Assets	0.9	0.4
Other Current Liabilities	1.4	1.2
Net Cash Flows from (Used for) Operating Activities	201.7	187
Investing Activities
Construction Expenditures	(400.5)	(491.5)
Change in Advances to Affiliates, Net	3	(43)
Other Investing Activities	(0.8)	2.1
Net Cash Flows from (Used for) Investing Activities	(398.3)	(532.4)
Financing Activities
Capital Contributions from Parent	124	185
Change in Advances from Affiliates, Net	72.6	160.4
Net Cash Flows from (Used for) Financing Activities	196.6	345.4
Net Increase (Decrease) in Cash and Cash Equivalents	0	0
Cash and Cash Equivalents at Beginning of Period	0	0
Cash and Cash Equivalents at End of Period	0	0
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	8.9	9.3
Net Cash Paid (Received) for Income Taxes	0	0.1
Construction Expenditures Included in Current Liabilities as of March 31,	244.5	290.6
Appalachian Power Co [Member]
Operating Activities
Net Income (Loss)	122.5	115.3
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	135.8	122.2
Deferred Income Taxes	(1.7)	(5.1)
Allowance for Equity Funds Used During Construction	(3.5)	(2.4)
Mark-to-Market of Risk Management Contracts	12.1	29.6
Deferred Fuel Over/Under-Recovery, Net	(6.4)	7.6
Change in Other Noncurrent Assets	(54.3)	(24.4)
Change in Other Noncurrent Liabilities	6.8	(16.1)
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	25.1	(2.6)
Fuel, Materials and Supplies	25.2	(5.5)
Accounts Payable	46	(86.6)
Accrued Taxes, Net	8.2	14.5
Other Current Assets	(3.6)	19.2
Other Current Liabilities	3.1	(11.1)
Net Cash Flows from (Used for) Operating Activities	315.3	154.6
Investing Activities
Construction Expenditures	(187.5)	(219.1)
Change in Advances to Affiliates, Net	(239.7)	0.3
Other Investing Activities	6.6	1.1
Net Cash Flows from (Used for) Investing Activities	(420.6)	(217.7)
Financing Activities
Issuance of Long-term Debt	494.3	0
Change in Advances from Affiliates, Net	(18.6)	118.6
Retirement of Long-term Debt	(362.5)	(12.2)
Principal Payments for Finance Leases Obligations	(1.9)	(1.8)
Dividends Paid on Common Stock	(12.5)	(50)
Other Financing Activities	0.2	0.2
Net Cash Flows from (Used for) Financing Activities	99	54.8
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(6.3)	(8.3)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	22.7	26.8
Cash and Cash Equivalents at Beginning of Period	5.8
Cash, Cash Equivalents and Restricted Cash at End of Period	16.4	18.5
Cash and Cash Equivalents at End of Period	4.8
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	28.9	31.9
Noncash Acquisitions Under Finance Leases	0.4	1.9
Construction Expenditures Included in Current Liabilities as of March 31,	96.1	103.7
Indiana Michigan Power Co [Member]
Operating Activities
Net Income (Loss)	70.8	92.3
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	109.2	93.9
Rockport Plant, Unit 2 Operating Lease Amortization	16.6	17.3
Deferred Income Taxes	(12.1)	(16.3)
Amortization (Deferral) of Incremental Nuclear Refueling Outage Expenses, Net	4.9	15.2
Allowance for Equity Funds Used During Construction	(3.5)	(2)
Mark-to-Market of Risk Management Contracts	2.7	4.4
Amortization of Nuclear Fuel	22.7	23.4
Deferred Fuel Over/Under-Recovery, Net	(9.3)	22.5
Change in Other Noncurrent Assets	2.6	(2.9)
Change in Other Noncurrent Liabilities	24.1	10
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	14.4	8.6
Fuel, Materials and Supplies	8.8	(16.2)
Accounts Payable	(14.8)	(21.6)
Accrued Taxes, Net	21.6	25
Other Current Assets	5.2	18.2
Other Current Liabilities	(45.8)	(62.7)
Net Cash Flows from (Used for) Operating Activities	218.1	209.1
Investing Activities
Construction Expenditures	(120.2)	(141.4)
Change in Advances to Affiliates, Net	0	(0.1)
Purchases of Investment Securities	(336.9)	(626)
Sales of Investment Securities	320	612.4
Acquisitions of Nuclear Fuel	(55.9)	(1.3)
Other Investing Activities	3.2	4.2
Net Cash Flows from (Used for) Investing Activities	(189.8)	(152.2)
Financing Activities
Change in Advances from Affiliates, Net	21.6	(10.7)
Retirement of Long-term Debt	(24.1)	(23.7)
Principal Payments for Finance Leases Obligations	(1.5)	(1.5)
Dividends Paid on Common Stock	(25)	(21.3)
Other Financing Activities	0.2	0.1
Net Cash Flows from (Used for) Financing Activities	(28.8)	(57.1)
Net Increase (Decrease) in Cash and Cash Equivalents	(0.5)	(0.2)
Cash and Cash Equivalents at Beginning of Period	3.3	2
Cash and Cash Equivalents at End of Period	2.8	1.8
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	42	44.3
Noncash Acquisitions Under Finance Leases	2.4	1.4
Construction Expenditures Included in Current Liabilities as of March 31,	50.5	67.8
Acquisition of Nuclear Fuel Included in Current Liabilities as of March 31,	6.7	0
Expected Reimbursement for Spent Nuclear Fuel Dry Cask Storage	0.1	1.3
Ohio Power Co [Member]
Operating Activities
Net Income (Loss)	68.2	75.1
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	75.1	70.5
Deferred Income Taxes	4.5	12.9
Carrying Costs Income	(0.5)	(0.4)
Allowance for Equity Funds Used During Construction	(2.7)	(1.9)
Mark-to-Market of Risk Management Contracts	(6.3)	17.3
Property Taxes	78.3	74.4
Change in Other Noncurrent Assets	(20.9)	(61.5)
Change in Other Noncurrent Liabilities	3.8	(36.4)
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(31.8)	(19.9)
Fuel, Materials and Supplies	(3.7)	(10.2)
Accounts Payable	(6.4)	35.5
Accrued Taxes, Net	(144.7)	(141.9)
Other Current Assets	(0.2)	(2)
Other Current Liabilities	(2)	(8.4)
Net Cash Flows from (Used for) Operating Activities	11.2	3.5
Investing Activities
Construction Expenditures	(178.2)	(232.8)
Change in Advances to Affiliates, Net	(0.5)	0
Other Investing Activities	2.6	5.9
Net Cash Flows from (Used for) Investing Activities	(176.1)	(226.9)
Financing Activities
Issuance of Long-term Debt	445.8	347.1
Change in Advances from Affiliates, Net	(259.2)	(101.6)
Principal Payments for Finance Leases Obligations	(1.2)	(1.2)
Dividends Paid on Common Stock	(21.9)	(21.9)
Other Financing Activities	0.1	0.4
Net Cash Flows from (Used for) Financing Activities	163.6	222.8
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(1.3)	(0.6)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	7.4	3.7
Cash and Cash Equivalents at Beginning of Period	7.4
Cash, Cash Equivalents and Restricted Cash at End of Period	6.1	3.1
Cash and Cash Equivalents at End of Period	6.1
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	15.8	16.7
Noncash Acquisitions Under Finance Leases	0.4	4.3
Construction Expenditures Included in Current Liabilities as of March 31,	72.4	72.9
Public Service Co Of Oklahoma [Member]
Operating Activities
Net Income (Loss)	(2.7)	(10.3)
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	49.9	44.7
Deferred Income Taxes	(0.8)	(5.3)
Allowance for Equity Funds Used During Construction	(0.4)	(1)
Mark-to-Market of Risk Management Contracts	4.8	9.5
Property Taxes	(32.8)	(29.8)
Deferred Fuel Over/Under-Recovery, Net	(703.5)	4.1
Change in Other Noncurrent Assets	(7.3)	(0.1)
Change in Other Noncurrent Liabilities	1.5	4.2
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(11.2)	0.9
Fuel, Materials and Supplies	4.5	(8.5)
Accounts Payable	15.2	(39.1)
Accrued Taxes, Net	22.4	25.1
Other Current Assets	(0.3)	(1.7)
Other Current Liabilities	(24.7)	(7.2)
Net Cash Flows from (Used for) Operating Activities	(685.4)	(14.5)
Investing Activities
Construction Expenditures	(79.9)	(96.5)
Change in Advances to Affiliates, Net	0	38.8
Other Investing Activities	0.5	1.6
Net Cash Flows from (Used for) Investing Activities	(79.4)	(56.1)
Financing Activities
Capital Contributions from Parent	425	0
Issuance of Long-term Debt	500	0
Change in Advances from Affiliates, Net	90.3	70.9
Retirement of Long-term Debt	(250.1)	(0.1)
Principal Payments for Finance Leases Obligations	(0.9)	(0.8)
Other Financing Activities	0.3	0.2
Net Cash Flows from (Used for) Financing Activities	764.6	70.2
Net Increase (Decrease) in Cash and Cash Equivalents	(0.2)	(0.4)
Cash and Cash Equivalents at Beginning of Period	2.6	1.5
Cash and Cash Equivalents at End of Period	2.4	1.1
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	16.9	16.7
Noncash Acquisitions Under Finance Leases	1	0.9
Construction Expenditures Included in Current Liabilities as of March 31,	22.2	30.8
Southwestern Electric Power Co [Member]
Operating Activities
Net Income (Loss)	63.4	16.1
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	69.6	67.3
Deferred Income Taxes	8.6	(9.2)
Allowance for Equity Funds Used During Construction	(2.1)	(1.4)
Mark-to-Market of Risk Management Contracts	1.1	3.9
Property Taxes	(61.6)	(49)
Deferred Fuel Over/Under-Recovery, Net	(461.1)	21
Change in Regulatory Assets	(89.1)	(15.1)
Change in Other Noncurrent Assets	6.1	11.1
Change in Other Noncurrent Liabilities	16.6	9.8
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(105.8)	11.3
Fuel, Materials and Supplies	0.4	(7.6)
Accounts Payable	95.1	(31.2)
Accrued Taxes, Net	73.9	51.2
Other Current Assets	8.2	(4)
Other Current Liabilities	(51)	(48.4)
Net Cash Flows from (Used for) Operating Activities	(427.7)	25.8
Investing Activities
Construction Expenditures	(91.4)	(122.4)
Other Investing Activities	0.1	0.8
Net Cash Flows from (Used for) Investing Activities	(91.3)	(121.6)
Financing Activities
Capital Contributions from Parent	100	0
Issuance of Long-term Debt	496.8	0
Change in Short-term Debt with Original Maturities less than 90 Days, Net	(30)	12.2
Change in Advances from Affiliates, Net	(37.7)	88.2
Retirement of Long-term Debt	(1.6)	(1.6)
Principal Payments for Finance Leases Obligations	(2.6)	(2.7)
Dividends Paid on Common Stock	(1)	(0.7)
Other Financing Activities	0.1	0.2
Net Cash Flows from (Used for) Financing Activities	524	95.6
Net Increase (Decrease) in Cash and Cash Equivalents	5	(0.2)
Cash and Cash Equivalents at Beginning of Period	13.2	1.6
Cash and Cash Equivalents at End of Period	18.2	1.4
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	39.7	40.7
Noncash Acquisitions Under Finance Leases	1.5	3
Construction Expenditures Included in Current Liabilities as of March 31,	40.2	45.2
Noncontrolling Interest [Member]
Supplementary Information
Noncontrolling Interest Assumed with Dry Lake Solar Project Acquisition	$ 18.9	$ 0

Significant Accounting Matters

Significant Accounting Matters	3 Months Ended
	Mar. 31, 2021
Significant Accounting Matters	SIGNIFICANT ACCOUNTING MATTERS The disclosures in this note apply to all Registrants unless indicated otherwise. General The unaudited condensed financial statements and footnotes were prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X of the SEC. Accordingly, they do not include all of the information and footnotes required by GAAP for complete annual financial statements. In the opinion of management, the unaudited condensed interim financial statements reflect all normal and recurring accruals and adjustments necessary for a fair statement of the net income, financial position and cash flows for the interim periods for each Registrant. Net income for the three months ended March 31, 2021 is not necessarily indicative of results that may be expected for the year ending December 31, 2021. The condensed financial statements are unaudited and should be read in conjunction with the audited 2020 financial statements and notes thereto, which are included in the Registrants’ Annual Reports on Form 10-K as filed with the SEC on February 25, 2021. COVID-19 In 2020, COVID-19 was declared a pandemic by the World Health Organization and the Centers for Disease Control and Prevention. Its rapid spread around the world and throughout the United States prompted many countries, including the United States, to institute restrictions on travel, public gatherings and certain business operations. These restrictions significantly disrupted economic activity in AEP’s service territory and resulted in reduced demand for energy, particularly from commercial and industrial customers. The Registrants continue to take steps to mitigate the potential risks to customers, suppliers and employees posed by the spread of COVID-19. As of March 31, 2021 and through the date of this report, the Registrants assessed certain accounting matters that require consideration of forecasted financial information, including, but not limited to, the allowance for credit losses and the carrying value of long-lived assets. While there were not any impairments or significant increases in credit allowances resulting from these assessments for the three months ended March 31, 2021 and 2020, the ultimate impact of COVID-19 also depends on factors beyond management’s knowledge or control, including the duration and severity of this outbreak as well as third-party actions taken to contain its spread and mitigate its public health effects. Therefore, management cannot estimate the potential future impact to financial position, results of operations and cash flows, but the impacts could be material. Earnings Per Share (EPS) (Applies to AEP) Basic EPS is calculated by dividing net earnings available to common shareholders by the weighted-average number of common shares outstanding during the period. Diluted EPS is calculated by adjusting the weighted-average outstanding common shares, assuming conversion of all potentially dilutive stock awards. The following table presents AEP’s basic and diluted EPS calculations included on the statements of income: Three Months Ended March 31, 2021 2020 (in millions, except per share data) $/share $/share Earnings Attributable to AEP Common Shareholders $ 575.0 $ 495.2 Weighted-Average Number of Basic AEP Common Shares Outstanding 497.1 $ 1.16 494.6 $ 1.00 Weighted-Average Dilutive Effect of Stock-Based Awards 1.1 (0.01) 2.0 — Weighted-Average Number of Diluted AEP Common Shares Outstanding 498.2 $ 1.15 496.6 $ 1.00 Equity Units are potentially dilutive securities but were excluded from the calculation of diluted EPS for the three months ended March 31, 2021 and 2020, as the dilutive stock price thresholds were not met. See Note 12 - Financing Activities for more information related to Equity Units. There were 0 and 697 thousand antidilutive shares outstanding as of March 31, 2021 and 2020, respectively. The antidilutive shares were excluded from the calculation of diluted EPS. Restricted Cash (Applies to AEP, AEP Texas and APCo) Restricted Cash primarily includes funds held by trustees for the payment of securitization bonds. Reconciliation of Cash, Cash Equivalents and Restricted Cash The following tables provide a reconciliation of Cash, Cash Equivalents and Restricted Cash reported within the balance sheets that sum to the total of the same amounts shown on the statements of cash flows: March 31, 2021 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 273.2 $ 0.1 $ 4.8 Restricted Cash 50.8 39.3 11.6 Total Cash, Cash Equivalents and Restricted Cash $ 324.0 $ 39.4 $ 16.4 December 31, 2020 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 392.7 $ 0.1 $ 5.8 Restricted Cash 45.6 28.7 16.9 Total Cash, Cash Equivalents and Restricted Cash $ 438.3 $ 28.8 $ 22.7

New Accounting Standards

New Accounting Standards	3 Months Ended
	Mar. 31, 2021
New Accounting Standards	NEW ACCOUNTING STANDARDS The disclosures in this note apply to all Registrants unless indicated otherwise. During the FASB’s standard-setting process and upon issuance of final standards, management reviews the new accounting literature to determine its relevance, if any, to the Registrants’ business. There are no new standards expected to have a material impact on the Registrants’ financial statements.

Comprehensive Income

Comprehensive Income	3 Months Ended
	Mar. 31, 2021
Comprehensive Income	COMPREHENSIVE INCOME The disclosures in this note apply to all Registrants except AEPTCo unless indicated otherwise. Presentation of Comprehensive Income The following tables provide the components of changes in AOCI and details of reclassifications from AOCI. The amortization of pension and OPEB AOCI components are included in the computation of net periodic pension and OPEB costs. See Note 7 - Benefit Plans for additional information. AEP Cash Flow Hedges Pension Three Months Ended March 31, 2021 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2020 $ (60.6) $ (47.5) $ 23.0 $ (85.1) Change in Fair Value Recognized in AOCI 177.3 13.1 (a) — 190.4 Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (b) 0.8 — — 0.8 Purchased Electricity for Resale (b) (172.0) — — (172.0) Interest Expense (b) — 1.5 — 1.5 Amortization of Prior Service Cost (Credit) — — (4.8) (4.8) Amortization of Actuarial (Gains) Losses — — 2.3 2.3 Reclassifications from AOCI, before Income Tax (Expense) Benefit (171.2) 1.5 (2.5) (172.2) Income Tax (Expense) Benefit (36.0) 0.4 (0.5) (36.1) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (135.2) 1.1 (2.0) (136.1) Net Current Period Other Comprehensive Income (Loss) 42.1 14.2 (2.0) 54.3 Balance in AOCI as of March 31, 2021 $ (18.5) $ (33.3) $ 21.0 $ (30.8) Cash Flow Hedges Pension Three Months Ended March 31, 2020 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2019 $ (103.5) $ (11.5) $ (32.7) $ (147.7) Change in Fair Value Recognized in AOCI (65.3) (42.7) (a) — (108.0) Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (b) (0.1) — — (0.1) Purchased Electricity for Resale (b) 51.1 — — 51.1 Interest Expense (b) — 0.9 — 0.9 Amortization of Prior Service Cost (Credit) — — (4.9) (4.9) Amortization of Actuarial (Gains) Losses — — 2.6 2.6 Reclassifications from AOCI, before Income Tax (Expense) Benefit 51.0 0.9 (2.3) 49.6 Income Tax (Expense) Benefit 10.7 0.2 (0.5) 10.4 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 40.3 0.7 (1.8) 39.2 Net Current Period Other Comprehensive Income (Loss) (25.0) (42.0) (1.8) (68.8) Balance in AOCI as of March 31, 2020 $ (128.5) $ (53.5) $ (34.5) $ (216.5) AEP Texas Cash Flow Hedge – Pension Three Months Ended March 31, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2020 $ (2.3) $ (6.6) $ (8.9) Change in Fair Value Recognized in AOCI 0.1 — 0.1 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.3 — 0.3 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.3 — 0.3 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.2 — 0.2 Net Current Period Other Comprehensive Income (Loss) 0.3 — 0.3 Balance in AOCI as of March 31, 2021 $ (2.0) $ (6.6) $ (8.6) Cash Flow Hedge – Pension Three Months Ended March 31, 2020 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2019 $ (3.4) $ (9.4) $ (12.8) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.4 — 0.4 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.4 — 0.4 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.3 — 0.3 Net Current Period Other Comprehensive Income (Loss) 0.3 — 0.3 Balance in AOCI as of March 31, 2020 $ (3.1) $ (9.4) $ (12.5) APCo Cash Flow Hedge – Pension Three Months Ended March 31, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2020 $ (0.8) $ 8.0 $ 7.2 Change in Fair Value Recognized in AOCI 9.3 — 9.3 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (0.4) — (0.4) Amortization of Prior Service Cost (Credit) — (1.4) (1.4) Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.4) (1.4) (1.8) Income Tax (Expense) Benefit (0.1) (0.3) (0.4) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.3) (1.1) (1.4) Net Current Period Other Comprehensive Income (Loss) 9.0 (1.1) 7.9 Balance in AOCI as of March 31, 2021 $ 8.2 $ 6.9 $ 15.1 Cash Flow Hedge – Pension Three Months Ended March 31, 2020 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2019 $ 0.9 $ 4.1 $ 5.0 Change in Fair Value Recognized in AOCI (3.9) — (3.9) Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (0.4) — (0.4) Amortization of Prior Service Cost (Credit) — (1.3) (1.3) Amortization of Actuarial (Gains) Losses — 0.1 0.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.4) (1.2) (1.6) Income Tax (Expense) Benefit (0.1) (0.3) (0.4) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.3) (0.9) (1.2) Net Current Period Other Comprehensive Income (Loss) (4.2) (0.9) (5.1) Balance in AOCI as of March 31, 2020 $ (3.3) $ 3.2 $ (0.1) I&M Cash Flow Hedge – Pension Three Months Ended March 31, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2020 $ (8.3) $ 1.3 $ (7.0) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.6 — 0.6 Amortization of Prior Service Cost (Credit) — (0.2) (0.2) Amortization of Actuarial (Gains) Losses — 0.2 0.2 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.6 — 0.6 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.5 — 0.5 Net Current Period Other Comprehensive Income (Loss) 0.5 — 0.5 Balance in AOCI as of March 31, 2021 $ (7.8) $ 1.3 $ (6.5) Cash Flow Hedge – Pension Three Months Ended March 31, 2020 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2019 $ (9.9) $ (1.7) $ (11.6) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.5 — 0.5 Amortization of Prior Service Cost (Credit) — (0.2) (0.2) Amortization of Actuarial (Gains) Losses — 0.2 0.2 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.5 — 0.5 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.4 — 0.4 Net Current Period Other Comprehensive Income (Loss) 0.4 — 0.4 Balance in AOCI as of March 31, 2020 $ (9.5) $ (1.7) $ (11.2) OPCo Cash Flow Hedge – Three Months Ended March 31, 2021 Interest Rate (in millions) Balance in AOCI as of December 31, 2020 $ — Change in Fair Value Recognized in AOCI — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) — Reclassifications from AOCI, before Income Tax (Expense) Benefit — Income Tax (Expense) Benefit — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit — Net Current Period Other Comprehensive Income (Loss) — Balance in AOCI as of March 31, 2021 $ — Cash Flow Hedge – Three Months Ended March 31, 2020 Interest Rate (in millions) Balance in AOCI as of December 31, 2019 $ — Change in Fair Value Recognized in AOCI — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) — Reclassifications from AOCI, before Income Tax (Expense) Benefit — Income Tax (Expense) Benefit — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit — Net Current Period Other Comprehensive Income (Loss) — Balance in AOCI as of March 31, 2020 $ — PSO Cash Flow Hedge – Three Months Ended March 31, 2021 Interest Rate (in millions) Balance in AOCI as of December 31, 2020 $ 0.1 Change in Fair Value Recognized in AOCI — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (0.1) Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.1) Income Tax (Expense) Benefit — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.1) Net Current Period Other Comprehensive Income (Loss) (0.1) Balance in AOCI as of March 31, 2021 $ — Cash Flow Hedge – Three Months Ended March 31, 2020 Interest Rate (in millions) Balance in AOCI as of December 31, 2019 $ 1.1 Change in Fair Value Recognized in AOCI — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (0.3) Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.3) Income Tax (Expense) Benefit (0.1) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.2) Net Current Period Other Comprehensive Income (Loss) (0.2) Balance in AOCI as of March 31, 2020 $ 0.9 SWEPCo Cash Flow Hedge – Pension Three Months Ended March 31, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2020 $ (0.3) $ 2.2 $ 1.9 Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.5 — 0.5 Amortization of Prior Service Cost (Credit) — (0.5) (0.5) Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.5 (0.5) — Income Tax (Expense) Benefit 0.1 (0.1) — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.4 (0.4) — Net Current Period Other Comprehensive Income (Loss) 0.4 (0.4) — Balance in AOCI as of March 31, 2021 $ 0.1 $ 1.8 $ 1.9 Cash Flow Hedge – Pension Three Months Ended March 31, 2020 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2019 $ (1.8) $ 0.5 $ (1.3) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.5 — 0.5 Amortization of Prior Service Cost (Credit) — (0.5) (0.5) Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.5 (0.5) — Income Tax (Expense) Benefit 0.1 (0.1) — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.4 (0.4) — Net Current Period Other Comprehensive Income (Loss) 0.4 (0.4) — Balance in AOCI as of March 31, 2020 $ (1.4) $ 0.1 $ (1.3) (a) The change in fair value includes $4 million and $5 million related to AEP's investment in joint venture wind farms acquired as part of the purchase of Sempra Renewables LLC for the three months ended March 31, 2021 and 2020, respectively. (b) Amounts reclassified to the referenced line item on the statements of income.

Rate Matters

Rate Matters	3 Months Ended
	Mar. 31, 2021
Rate Matters	RATE MATTERS The disclosures in this note apply to all Registrants unless indicated otherwise. As discussed in the 2020 Annual Report, the Registrants are involved in rate and regulatory proceedings at the FERC and their state commissions. The Rate Matters note within the 2020 Annual Report should be read in conjunction with this report to gain a complete understanding of material rate matters still pending that could impact net income, cash flows and possibly financial condition. The following discusses ratemaking developments in 2021 and updates the 2020 Annual Report. Coal-Fired Generation Plants (Applies to AEP, PSO and SWEPCo) Compliance with extensive environmental regulations requires significant capital investment in environmental monitoring, installation of pollution control equipment, emission fees, disposal costs and permits. Management continuously evaluates cost estimates of complying with these regulations which has resulted in, and in the future may result in, a decision to retire coal-fired generating facilities earlier than their currently estimated useful lives. Management is seeking or will seek regulatory recovery, as necessary, for any net book value remaining when the plants are retired. To the extent the net book value of these generation assets are not deemed recoverable, it could materially reduce future net income and cash flows and impact financial condition. Regulated Generating Units that have been Retired PSO In September 2020, the Oklaunion Power Station was retired. As of March 31, 2021, PSO has a regulatory asset for accelerated depreciation pending approval recorded on its balance sheet of $34 million. PSO will seek recovery of the Oklaunion Power Station in its next base rate case. In October 2020, the Oklaunion Power Station site was sold to a nonaffiliated third-party. SWEPCo In April 2016, Welsh Plant, Unit 2 was retired. As part of the 2016 Texas Base Rate Case, SWEPCo received approval from the PUCT to recover the Texas jurisdictional share of Welsh Plant, Unit 2. See “2016 Texas Base Rate Case” section of Note 4 for additional information. As part of the 2019 Arkansas Base Rate Case, SWEPCo received approval from the APSC to recover the Arkansas jurisdictional share of Welsh Plant, Unit 2. In December 2020, SWEPCo filed a request with the LPSC to recover the Louisiana jurisdictional share of Welsh Plant, Unit 2. As of March 31, 2021, SWEPCo has a regulatory asset for plant retirement costs pending approval recorded on its balance sheet of $35 million related to the Louisiana jurisdictional share of Welsh Plant, Unit 2. See “2020 Louisiana Base Rate Case” section below for additional information. Regulated Generating Units to be Retired PSO In 2014, PSO received final approval from the Federal EPA to close Northeastern Plant, Unit 3, in 2026. The plant was originally scheduled to close in 2040. As a result of the early retirement date, PSO revised the useful life of Northeastern Plant, Unit 3, to the projected retirement date of 2026 and the incremental depreciation is being deferred as a regulatory asset. In 2016, as part of the 2015 Oklahoma Base Rate Case, the OCC issued an order approving the continued depreciation of Northeastern Plant, Unit 3 through 2040. The order did not approve accelerating the recovery of the incremental depreciation based on the revised retirement date of 2026. SWEPCo In January 2020, as part of the 2019 Arkansas Base Rate Case, management announced that the Dolet Hills Power Station was probable of abandonment and was to be retired by December 2026. As a result of the announcement, SWEPCo began recording a regulatory asset for accelerated depreciation. In March 2020, management announced plans to retire the plant in 2021. In November 2020, management announced plans to retire Pirkey Power Plant in 2023 and that it will cease using coal at the Welsh Plant in 2028. As a result of the announcement, SWEPCo began recording a regulatory asset for accelerated depreciation. The table below summarizes the net book value including CWIP, before cost of removal and materials and supplies, as of March 31, 2021, of generating facilities planned for early retirement: Plant Net Accelerated Depreciation Regulatory Asset Cost of Removal Projected Current Authorized Annual (dollars in millions) Northeastern Plant, Unit 3 $ 190.5 $ 114.8 $ 19.8 (b) 2026 (c) $ 14.9 Dolet Hills Power Station 51.3 92.6 1.1 2021 (d) 7.7 Pirkey Power Plant 178.3 30.8 18.4 2023 (e) 13.7 Welsh Plant, Units 1 and 3 528.8 14.2 11.4 (f) 2028 (g) 33.3 (a) Represents the amount of annual depreciation that has been collected from customers over the prior 12-month period. (b) Includes Northeastern Plant, Unit 4, which was retired in 2016. Removal of Northeastern Plant, Unit 4, will be performed with Northeastern Plant, Unit 3, after retirement. (c) Northeastern Plant, Unit 3 is currently being recovered through 2040. (d) Dolet Hills Power Station is currently being recovered through 2026 in the Louisiana jurisdiction and through 2046 in the Arkansas and Texas jurisdictions. (e) Pirkey Power Plant is currently being recovered through 2025 in the Louisiana jurisdiction and through 2045 in the Arkansas and Texas jurisdictions. (f) Includes Welsh Plant, Unit 2, which was retired in 2016. Removal of Welsh Plant, Unit 2, will be performed with Welsh Plant, Units 1 and 3, after retirement. (g) 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) During the second quarter of 2019, the Dolet Hills Power Station initiated a seasonal operating schedule. In January 2020, in accordance with the terms of SWEPCo’s settlement of its base rate review filed with the APSC, management announced that SWEPCo will seek regulatory approval to retire the Dolet Hills Power Station by the end of 2026. DHLC provides 100% of the fuel supply to Dolet Hills Power Station. After careful consideration of current economic conditions, and particularly for the benefit of their customers, management of SWEPCo and CLECO determined DHLC would not proceed developing additional Oxbow Lignite Company (Oxbow) mining areas for future lignite extraction and ceased extraction of lignite at the mine in May 2020. Based on these actions, management revised the estimated useful life of DHLC’s and Oxbow’s assets to coincide with the date at which extraction was discontinued in the second quarter of 2020 and the date at which delivery of lignite is expected to cease in September 2021. Management also revised the useful life of the Dolet Hills Power Station to 2021 based on the remaining estimated fuel supply available for continued seasonal operation. In March 2020, primarily due to the revision in the useful life of DHLC, SWEPCo recorded a revision to increase estimated ARO liabilities by $21 million. In April 2020, SWEPCo and CLECO jointly filed a notification letter to the LPSC providing notice of the cessation of lignite mining. The Dolet Hills Power Station costs are recoverable by SWEPCo through base rates. SWEPCo’s share of the net investment in the Dolet Hills Power Station is $150 million, including CWIP and materials and supplies, before cost of removal. Fuel costs incurred by the Dolet Hills Power Station are recoverable by SWEPCo through active fuel clauses. Under the fuel agreements, SWEPCo’s fuel inventory and unbilled fuel costs from mining related activities were $126 million as of March 31, 2021. Also, as of March 31, 2021, SWEPCo had a net over-recovered fuel balance of $20 million, excluding impacts of the February 2021 severe winter weather event, which includes fuel consumed at the Dolet Hills Power Station. Additional operational and land-related costs are expected to be incurred by DHLC and Oxbow and billed to SWEPCo prior to the closure of the Dolet Hills Power Station and recovered through fuel clauses. In June 2020, SWEPCo filed a fuel reconciliation with the PUCT for its retail operations in Texas, including Dolet Hills, for the reconciliation period of March 1, 2017 to December 31, 2019. See “2020 Texas Fuel Reconciliation” section below for additional information. In October 2020, SWEPCo filed a request with the LPSC seeking approval to close the mines and to recover the Louisiana jurisdictional share of the additional fuel costs. In March 2021, the LPSC issued an order allowing SWEPCo to recover up to $20 million of fuel costs in 2021 and defer approximately $30 million of additional costs with a recovery period to be determined at a later date. In March 2021, the APSC approved fuel rates that provide recovery of the Arkansas share of the 2021 Dolet Hills Power Station fuel costs over five years through the existing fuel clause. If any of these costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. Pirkey Power Plant and Related Fuel Operations (Applies to AEP and SWEPCo) In November 2020, management announced plans to retire the Pirkey Power Plant in 2023. The Pirkey Power Plant costs are recoverable by SWEPCo through base rates. SWEPCo’s share of the net investment in the Pirkey Power Plant is $209 million, including CWIP, before cost of removal. Sabine is a mining operator providing mining services to the Pirkey Power Plant. Under the provisions of the mining agreement, SWEPCo is required to pay, as part of the cost of lignite delivered, an amount equal to mining costs plus a management fee. SWEPCo expects fuel deliveries, including billings of all fixed and operating costs, from Sabine to cease during the first quarter of 2023. Under the fuel agreements, SWEPCo’s fuel inventory and unbilled fuel costs from mining related activities were $163 million as of March 31, 2021. Also, as of March 31, 2021, SWEPCo had a net over-recovered fuel balance of $20 million, excluding impacts of the February 2021 severe winter weather event, which includes fuel consumed at the Pirkey Power Plant. Additional operational costs are expected to be incurred by Sabine and billed to SWEPCo, as well as land-related costs incurred by SWEPCo, prior to the closure of the Pirkey Power Plant and recovered through fuel clauses. If any of these costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. 2020 Texas Fuel Reconciliation (Applies to AEP and SWEPCo) In June 2020, SWEPCo filed a fuel reconciliation with the PUCT for its retail operations in Texas for the reconciliation period of March 1, 2017 to December 31, 2019. The fuel reconciliation included total fuel costs of $1.7 billion ($616 million of which is related to the Texas jurisdiction). In January 2021, various parties filed testimony recommending fuel cost disallowances totaling $125 million relating to the Texas jurisdiction. Also in January 2021, SWEPCo filed rebuttal testimony disputing the recommended disallowances. In February 2021, SWEPCo and various parties reached a settlement in principle which resulted in an immaterial impact to SWEPCo’s 2020 financial statements. If additional costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. Regulatory Assets Pending Final Regulatory Approval (Applies to all Registrants except AEPTCo) AEP March 31, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Unrecovered Winter Storm Fuel Costs (a) $ 1,185.0 $ — Dolet Hills Power Station Accelerated Depreciation 92.6 71.2 Kentucky Deferred Purchase Power Expenses 42.8 41.3 Plant Retirement Costs – Unrecovered Plant, Louisiana 35.2 35.2 Oklaunion Power Station Accelerated Depreciation 34.0 34.4 Pirkey Power Plant Accelerated Depreciation 30.8 12.2 Other Regulatory Assets Pending Final Regulatory Approval 37.5 26.4 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 285.0 134.2 Plant Retirement Costs – Asset Retirement Obligation Costs 25.9 25.9 COVID-19 19.5 24.9 Environmental Expense Deferral - Virginia 12.3 9.3 Other Regulatory Assets Pending Final Regulatory Approval 33.0 27.2 Total Regulatory Assets Pending Final Regulatory Approval $ 1,833.6 $ 442.2 (a) PSO and SWEPCo have active fuel clauses that allow for the recovery of prudently incurred fuel and purchased power expenses. However, the recovery of these costs from customers may be extended over longer than usual time periods to mitigate the impact on customer bills. See “Impacts of Severe Winter Weather” section below for additional information. AEP Texas March 31, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Advanced Metering System $ 16.4 $ 16.3 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 10.5 0.8 COVID-19 8.6 10.5 Texas Retail Electric Provider Bad Debt Expense 4.1 — Vegetation Management Program 3.8 3.8 Other Regulatory Assets Pending Final Regulatory Approval 2.6 1.5 Total Regulatory Assets Pending Final Regulatory Approval $ 46.0 $ 32.9 APCo March 31, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return COVID-19 – Virginia $ 4.0 $ 3.7 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 49.1 3.4 Plant Retirement Costs – Asset Retirement Obligation Costs 25.9 25.9 Environmental Expense Deferral - Virginia 12.3 9.3 COVID-19 – West Virginia 1.6 1.5 Total Regulatory Assets Pending Final Regulatory Approval $ 92.9 $ 43.8 I&M March 31, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Other Regulatory Assets Pending Final Regulatory Approval $ — $ 0.5 Regulatory Assets Currently Not Earning a Return COVID-19 2.8 3.8 Other Regulatory Assets Pending Final Regulatory Approval 0.6 — Total Regulatory Assets Pending Final Regulatory Approval $ 3.4 $ 4.3 OPCo March 31, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Not Earning a Return Storm-Related Costs $ 6.8 $ 4.0 COVID-19 1.5 4.4 Other Regulatory Assets Pending Final Regulatory Approval 0.1 — Total Regulatory Assets Pending Final Regulatory Approval $ 8.4 $ 8.4 PSO March 31, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Unrecovered Winter Storm Fuel Costs (a) $ 688.7 $ — Oklaunion Power Station Accelerated Depreciation 34.0 34.4 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 24.8 15.8 Other Regulatory Assets Pending Final Regulatory Approval 0.8 0.3 Total Regulatory Assets Pending Final Regulatory Approval $ 748.3 $ 50.5 (a) PSO has an active fuel clause that allows for the recovery of prudently incurred fuel and purchased power expenses. However, the recovery of these costs from customers may be extended over longer than usual time periods to mitigate the impact on customer bills. See “Impacts of Severe Winter Weather” section below for additional information. SWEPCo March 31, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Unrecovered Winter Storm Fuel Costs (a) $ 496.3 $ — Dolet Hills Power Station Accelerated Depreciation 92.6 71.2 Plant Retirement Costs – Unrecovered Plant, Louisiana 35.2 35.2 Pirkey Power Plant Accelerated Depreciation 30.8 12.2 Welsh Plant, Units 1 and 3 Accelerated Depreciation 14.2 3.6 Other Regulatory Assets Pending Final Regulatory Approval 2.8 2.2 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 139.1 99.3 Asset Retirement Obligation - Louisiana 9.4 9.1 Other Regulatory Assets Pending Final Regulatory Approval 15.4 14.5 Total Regulatory Assets Pending Final Regulatory Approval $ 835.8 $ 247.3 (a) SWEPCo has an active fuel clause that allows for the recovery of prudently incurred fuel and purchased power expenses. However, the recovery of these costs from customers may be extended over longer than usual time periods to mitigate the impact on customer bills. See “Impacts of Severe Winter Weather” section below for additional information. If these costs are ultimately determined not to be recoverable, it could reduce future net income and cash flows and impact financial condition. Impacts of Severe Winter Weather Storm Restoration Costs (Applies to AEP, APCo and SWEPCo) In February 2021, severe winter weather impacted the service territories of APCo, KPCo and SWEPCo resulting in power outages and extensive damage to transmission and distribution infrastructures. As a result, incremental restoration expenses have been deferred related to the severe winter weather. The current estimate of storm restoration costs are as follows: March 31, 2021 Company Jurisdiction Capital O&M Regulatory Asset Total (in millions) APCo Virginia $ 5.4 $ 2.2 $ 5.6 $ 13.2 APCo West Virginia 19.6 — 39.1 58.7 SWEPCo Louisiana 4.9 — 42.1 47.0 KPCo Kentucky 26.7 3.8 44.1 74.6 Total $ 56.6 $ 6.0 $ 130.9 $ 193.5 The amounts in the table above represent estimates as of March 31, 2021, and are subject to true-up as additional information becomes available. In March 2021, the LPSC approved the deferral of incremental other operation and maintenance storm restoration expenses related to the Louisiana jurisdiction for SWEPCo. Similarly, in April 2021, the KPSC approved deferral of KPCo’s incremental other operation and maintenance storm restoration expenses. APCo and KPCo intend to seek recovery of these incremental storm restoration costs in their next respective base rate cases while SWEPCo is expected to seek recovery in a separate filing. If any of the restoration costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. February 2021 Severe Winter Weather Impacts in SPP (Applies to AEP, PSO and SWEPCo) The February 2021 severe winter weather also had a significant impact in SPP resulting in the declaration of Energy Emergency Alert Levels 2 and 3 for the first time in SPP’s history. The winter storm increased the demand for natural gas and restricted the available natural gas supply resulting in significantly increased market prices for natural gas power plants to meet reliability needs for the SPP electric system. From February 9, 2021, to February 20, 2021, PSO’s and SWEPCo’s estimates of natural gas expenses and purchases of electricity to be recovered from customers are as follows: PSO SWEPCo Total (in millions) Retail Customers (a) $ 688.7 $ 496.3 $ 1,185.0 Wholesale Customers — 88.4 88.4 Total $ 688.7 $ 584.7 $ 1,273.4 (a) These costs were deferred as regulatory assets as of March 31, 2021. The amounts in the table above represent estimates as of March 31, 2021, and are subject to final settlement as additional information becomes available. Retail Customers PSO and SWEPCo have active fuel clauses that allow for the recovery of prudently incurred fuel and purchased power expenses. Given the significance of these costs, PSO and SWEPCo expect the costs to be subject to prudency reviews. Management believes these costs are probable of future recovery, but expects the recovery period to be extended to mitigate the impact on customer bills. In March 2021, the APSC issued an order authorizing recovery of the Arkansas jurisdictional share of the retail customer fuel costs over five years, with the appropriate carrying charge to be determined at a later date. Accordingly, in April 2021, SWEPCo began recovery of its Arkansas jurisdictional share of these fuel costs, which are subject to true-up by the APSC. Also in April 2021, SWEPCo filed testimony supporting a five-year recovery with a pretax rate of return of 6.05%. A hearing is expected in the third quarter of 2021. A separate proceeding will address the prudency of the fuel costs. Also in March 2021, the LPSC approved a special order granting a temporary modification to the FAC that allows SWEPCo to recover the Louisiana jurisdictional share of the retail fuel costs over a longer period. In April 2021, SWEPCo began recovery of its Louisiana jurisdictional share of these fuel costs based on a five year recovery period. SWEPCo will work with the LPSC to finalize the actual recovery period and determine the appropriate carrying charge in future proceedings. In April 2021, the OCC approved a waiver for PSO allowing the deferral of the extraordinary fuel and purchase of electricity costs, including carrying costs, over a longer time period than what the FAC traditionally allows. A time frame for recovery and the appropriate carrying charge will be decided at a later date. Also in April 2021, legislation was introduced in Oklahoma proposing to securitize the extraordinary fuel and purchase of electricity costs impacting the utilities within the state. Under the proposal, the State of Oklahoma would issue securitization bonds and provide the proceeds to utilities to recover their share of the costs. PSO will continue to evaluate and monitor the advancement of the proposed legislation. SWEPCo expects to make a filing with the PUCT in the second quarter of 2021 to seek a recovery mechanism and an appropriate carrying charge for the Texas jurisdictional share of the retail fuel costs. Wholesale Customers SWEPCo is also working with certain wholesale customers to establish payment terms for $88 million of accounts receivable resulting from the severe winter weather events. Management believes these receivables are probable of future collection. PSO and SWEPCo Cash Flow Implications PSO and SWEPCo evaluated financing alternatives to address the timing difference between the payment of the estimated natural gas expenses and purchases of electricity to suppliers and subsequent recovery from customers. In March 2021, PSO drew $100 million on its revolving credit facility and SWEPCo issued $500 million of Senior Unsecured Notes. In March 2021, Parent entered into a $500 million 364-day Term Loan and borrowed the full amount. The proceeds from this loan were used to help fund capital contributions to PSO and SWEPCo totaling $425 million and $100 million, respectively. In April 2021, PSO received an additional capital contribution from Parent of $125 million to further address these costs. Although the February 2021 severe winter weather did not materially impact AEP’s results of operations for the three months ended March 31, 2021, if either PSO or SWEPCo is unable to recover these fuel and purchased power costs, or obtain authorization of a reasonable carrying charge on these costs, it could reduce future net income and cash flows and impact financial condition. ERCOT (Applies to AEP and AEP Texas) In response to the extreme winter weather event, the Governor of Texas issued a Declaration of a State of Disaster for all counties in Texas. To assist with a return to normalcy, the PUCT issued an order that placed a temporary moratorium on customer disconnections due to non-payment for transmission and distribution utilities. This moratorium will be in effect until otherwise ordered by the PUCT. If related costs are not recoverable, it could reduce future net income and cash flows and impact financial condition. COVID-19 Pandemic During 2020, AEP’s electric operating companies informed both retail customers and state regulators that disconnections for non-payment were temporarily suspended. Shortly thereafter, AEP’s state regulators also imposed temporary moratoria on customary disconnection practices. As of March 31, 2021, AEP’s electric operating companies have resumed customary disconnection practices in all regulated jurisdictions with the exception of Arkansas and Virginia. In March 2021, the APSC issued an order allowing electric utilities in Arkansas to begin disconnections for non-payment beginning on May 3, 2021. AEP continues to work with regulators and stakeholders in Virginia and management currently anticipates resuming customary disconnection practices in the third quarter of 2021. Continuing adverse economic conditions may result in the inability of customers to pay for electric service, which could affect revenue recognition and the collectability of accounts receivable. If any costs related to COVID-19 are not recoverable, it could reduce future net income and cash flows and impact financial condition. AEP Texas Rate Matters (Applies to AEP and AEP Texas) AEP Texas Interim Transmission and Distribution Rates Through March 31, 2021, AEP Texas’ cumulative revenues from interim base rate increases that are subject to review is estimated to be $118 million. A base rate review could result in a refund to customers if AEP Texas incurs a disallowance of the transmission or distribution investment on which an interim increase was based. Management is unable to determine a range of potential losses, if any, that are reasonably possible of occurring. A revenue decrease, including a refund of interim transmission and distribution rates, could reduce future net income and cash flows and impact financial condition. AEP Texas is required to file for a comprehensive rate review no later than April 3, 2024. APCo and WPCo Rate Matters (Applies to AEP and APCo) 2017-2019 Virginia Triennial Review In November 2020, the Virginia SCC issued an order on APCo’s 2017-2019 Triennial Review filing concluding that APCo earned above its authorized ROE but within its ROE band for the 2017-2019 period, resulting in no refund to customers and no change to APCo base rates on a prospective basis. The Virginia SCC approved a prospective 9.2% ROE for APCo's 2020-2022 triennial review period with the continuation of a 140 basis point band (8.5% bottom, 9.2% midpoint, 9.9% top). In December 2020, an intervenor filed a petition at the Virginia SCC requesting reconsideration of: (a) the failure of the Virginia SCC to apply a threshold earnings test to the approved regulatory asset for APCo’s closed coal-fired generation assets, (b) the Virginia SCC’s use of a 2011 benchmark study to measure the replacement value of capacity for purposes of APCo’s 2017 – 2019 earnings test and (c) the reasonableness and prudency of APCo’s investments in AMI meters. In December 2020, APCo filed a petition at the Virginia SCC requesting reconsideration of: (a) certain issues related to APCo’s going-forward rates and (b) the Virginia SCC’s decision to deny APCo tariff changes that align rates with underlying costs. For APCo’s going-forward rates, APCo requested that the Virginia SCC clarify its final order and clarify whether APCo’s current rates will allow it to earn a fair return. If the Virginia SCC’s order did conclude on APCo’s ability to earn a fair return through existing base rates, APCo further requested that the Virginia SCC clarify whether it has the authority to also permit an increase in base rates. In March 2021, an intervenor filed its assignments of error with the Virginia Supreme Court related to the appeal of the November 2020 order in which it stated the Virginia SCC erred: (a) in determining that Virginia law did not apply to its determination to permit amortization for recovery of costs associated with retired coal-fired generation assets, (b) in establishing a new regulatory asset for a cost incurred outside of the triennial review period due to its failure to apply a threshold earnings test before approving deferred cost recovery and (c) in misapplying the requirement that APCo bear the burden of demonstrating that power purchases made by APCo from its affiliate, OVEC, were priced at the lower of OVEC’s cost or the market price for nonaffiliated power. In March 2021, APCo filed its assignments of error with the Virginia Supreme Court related to its appeal of the November 2020 order in which it stated the Virginia SCC erred: (a) in finding that costs associated with asset impairments related to early retirement determinations made by APCo for certain generation facilities should not be attributed to the test periods under review and deemed fully recovered in the period recorded, (b) in finding that it was permitted to evaluate the reasonableness of APCo’s decision to record, per books for financial reporting purposes, asset impairments related to early retirement determinations for certain generation facilities, (c) as a result of the errors described in (a) and (b), in denying APCo an increase in rates, (d) in failing to review and make any findings regarding whether APCo’s rates would allow it to earn a fair rate of return going forward, (e) in denying APCo an increase in base rates by failing to ensure that APCo has an opportunity to recover its costs and earn a fair rate of return, thereby resulting in a taking of private property for public use without just compensation and (f) in retroactively adjusting APCo’s depreciation expense for purposes of calculating APCo’s earnings for the 2017-2019 triennial period. In March 2021, the Virginia SCC issued an order confirming certain of its decisions from the November 2020 order and rejecting the various requests for reconsideration from APCo and an intervenor. In confirming its decision to reject an intervenor’s recommendation that APCo’s AMI costs incurred during the triennial period be disallowed, the Virginia SCC clarified that APCo established the need to replace its existing AMR meters, and that based on the uncertainty surrounding the continued manufacturing and support of AMR technology, APCo reasonably chose to replace them with AMI meters. In March 2021, APCo filed a notice of appeal of the reconsideration order with the Virginia Supreme Court. APCo expects to submit its brief before the Virginia Supreme Court in the second or third quarter of 2021. In April 2021, and in conjunction with APCo’s November 2020 and March 2021 appeals with the Virginia Supreme Court, APCo filed a petition for interim rates with the Virginia Supreme Court (subject to refund with interest and supported by a bond issuance) requesting a $40 million increase in annual APCo Virginia base rates. APCo submitted this filing based on Virginia law that allows the Virginia Supreme Court to authorize interim rates until the final disposition on APCo’s appeals. APCo also requested an expedited schedule from the Virginia Supreme Court on APCo’s appeals. APCo ultimately seeks an increase in base rates through its appeal to the Virginia Supreme Court. Among other issues, this appeal includes APCo’s request for proper treatment of the closed coal-fired plant assets in APCo’s 2017-2019 triennial period, reducing APCo’s earnings below the bottom of its authorized ROE band. If APCo’s appeals regarding treatment of the closed coal plants are granted by the Virginia Supreme Court, it could initially reduce future net income and impact financial condition. December 2020 Virginia Environmental Rate Adjustment Clause (E-RAC) Rider Filing In December 2020, APCo submitted an E-RAC filing with the Virginia SCC requesting the regulatory approvals necessary to implement CCR/ELG compliance plans at APCo’s Amos and Mountaineer plants. In this filing, APCo requested an initial E-RAC revenue requirement of $31 million to recover CCR/ELG construction costs and ongoing environmental operation and maintenance expenses. APCo’s current estimate of total company CCR/ELG costs for the Amos and Mountaineer plants, including AFUDC, is approximately $240 million. In April 2021, intervenors submitted testimony. Testimony included recommendations that APCo construct only the CCR-related investments at the Amos and Mountaineer plants and, as a consequence, APCo close the Amos and Mountaineer plants at the end of 2028. As of March 31, 2021, APCo’s total company combined CCR and ELG investment balances in CWIP for these plants were $8 million and $14 million, respectively. Virginia Staff will submit testimony in May 2021 with a hearing scheduled to occur in June 2021. If any APCo CCR/ELG costs are not approved for recovery, it would reduce future net income and cash flows and impact financial condition. ETT Rate Matters (Applies to AEP) ETT Interim Transmission Rates AEP has a 50% equity ownership interest in ETT. Predominantly all of ETT’s revenues are based on interim rate changes that can be filed twice annually and are subject to review and possible true-up in the next base rate proceeding. Through March 31, 2021, AEP’s share of ETT’s cumulative revenues that are subject to review is estimated to be $1.2 billion. A base rate review could produce a refund if ETT incurs a disallowance of the transmission investment on

Commitments, Guarantees and Con

Commitments, Guarantees and Contingencies	3 Months Ended
	Mar. 31, 2021
Commitments, Guarantees and Contingencies	COMMITMENTS, GUARANTEES AND CONTINGENCIES The disclosures in this note apply to all Registrants unless indicated otherwise. The Registrants are subject to certain claims and legal actions arising in the ordinary course of business. In addition, the Registrants’ business activities are subject to extensive governmental regulation related to public health and the environment. The ultimate outcome of such pending or potential litigation against the Registrants cannot be predicted. Management accrues contingent liabilities only when management concludes that it is both probable that a liability has been incurred at the date of the financial statements and the amount of loss can be reasonably estimated. When management determines that it is not probable, but rather reasonably possible that a liability has been incurred at the date of the financial statements, management discloses such contingencies and the possible loss or range of loss if such estimate can be made. Any estimated range is based on currently available information and involves elements of judgment and significant uncertainties. Any estimated range of possible loss may not represent the maximum possible loss exposure. Circumstances change over time and actual results may vary significantly from estimates. For current proceedings not specifically discussed below, management does not anticipate that the liabilities, if any, arising from such proceedings would have a material effect on the financial statements. The Commitments, Guarantees and Contingencies note within the 2020 Annual Report should be read in conjunction with this report. GUARANTEES Liabilities for guarantees are recorded in accordance with the accounting guidance for “Guarantees.” There is no collateral held in relation to any guarantees. In the event any guarantee is drawn, there is no recourse to third-parties unless specified below. Letters of Credit (Applies to AEP and AEP Texas) Standby letters of credit are entered into with third-parties. These letters of credit are issued in the ordinary course of business and cover items such as natural gas and electricity risk management contracts, construction contracts, insurance programs, security deposits and debt service reserves. AEP has $4 billion and $1 billion revolving credit facilities due in March 2026 and 2023, respectively, under which up to $1.2 billion may be issued as letters of credit on behalf of subsidiaries. As of March 31, 2021, 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 $425 million. The Registrants’ maximum future payments for letters of credit issued under the uncommitted facilities as of March 31, 2021 were as follows: Company Amount Maturity (in millions) AEP $ 183.2 April 2021 to March 2022 AEP Texas 2.2 July 2021 Guarantees of Equity Method Investees (Applies to AEP) In 2019, AEP acquired Sempra Renewables LLC. The transaction resulted in the acquisition of a 50% ownership interest in five non-consolidated joint ventures and the acquisition of two tax equity partnerships. Parent has issued guarantees over the performance of the joint ventures. If a joint venture were to default on payments or performance, Parent would be required to make payments on behalf of the joint venture. As of March 31, 2021, the maximum potential amount of future payments associated with these guarantees was $157 million, with the last guarantee expiring in December 2037. The non-contingent liability recorded associated with these guarantees was $30 million, with an additional $1 million expected credit loss liability for the contingent portion of the guarantees. Management considered historical losses, economic conditions and reasonable and supportable forecasts in the calculation of the expected credit loss. As the joint ventures generate cash flows through PPAs, the measurement of the contingent portion of the guarantee liability is based upon assessments of the credit quality and default probabilities of the respective PPA counterparties. Indemnifications and Other Guarantees Contracts The Registrants enter into certain types of contracts which require indemnifications. Typically these contracts include, but are not limited to, sale agreements, lease agreements, purchase agreements and financing agreements. Generally, these agreements may include, but are not limited to, indemnifications around certain tax, contractual and environmental matters. With respect to sale agreements, exposure generally does not exceed the sale price. As of March 31, 2021, there were no material liabilities recorded for any indemnifications. AEPSC conducts power purchase-and-sale activity on behalf of APCo, I&M, KPCo and WPCo, who are jointly and severally liable for activity conducted on their behalf. AEPSC also conducts power purchase-and-sale activity on behalf of PSO and SWEPCo, who are jointly and severally liable for activity conducted on their behalf. Master Lease Agreements (Applies to all Registrants except AEPTCo) The Registrants lease certain equipment under master lease agreements. Under the lease agreements, the lessor is guaranteed a residual value up to a stated percentage of the equipment cost at the end of the lease term. If the actual fair value of the leased equipment is below the guaranteed residual value at the end of the lease term, the Registrants are committed to pay the difference between the actual fair value and the residual value guarantee. Historically, at the end of the lease term the fair value has been in excess of the amount guaranteed. As of March 31, 2021, 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 $ 48.6 AEP Texas 11.3 APCo 6.3 I&M 4.2 OPCo 7.7 PSO 4.7 SWEPCo 5.4 Rockport Lease (Applies to AEP and I&M) AEGCo and I&M entered into a sale-and-leaseback transaction in 1989 with Wilmington Trust Company (Owner Trustee), an unrelated, unconsolidated trustee for Rockport Plant, Unit 2 (the Plant). The Owner Trustee was capitalized with equity from six owner participants with no relationship to AEP or any of its subsidiaries and debt from a syndicate of banks and securities in a private placement to certain institutional investors. The Owner Trustee owns the Plant and leases equal portions to AEGCo and I&M. The lease is accounted for as an operating lease. The lease term is for 33 years and at the end of the lease term, AEGCo and I&M have the option to renew the lease at a rate that approximates fair value. In November 2020, management announced that AEP will not renew the lease when it expires in 2022. AEP, AEGCo and I&M have no ownership interest in the Owner Trustee and do not guarantee its debt. The future minimum lease payments for this sale-and-leaseback transaction as of March 31, 2021 were as follows: Future Minimum Lease Payments AEP (a) I&M (in millions) 2021 $ 147.8 $ 73.9 2022 147.6 73.8 Total Future Minimum Lease Payments $ 295.4 $ 147.7 (a) AEP’s future minimum lease payments include equal shares from AEGCo and I&M. AEPRO Boat and Barge Leases (Applies to AEP) In 2015, AEP sold its commercial barge transportation subsidiary, AEPRO, to a nonaffiliated party. Certain boat and barge leases acquired by the nonaffiliated party are subject to an AEP guarantee in favor of the respective lessors, ensuring future payments under such leases with maturities up to 2027. As of March 31, 2021, the maximum potential amount of future payments required under the guaranteed leases was $47 million. Under the terms of certain of the arrangements, upon the lessors exercising their rights after an event of default by the nonaffiliated party, AEP is entitled to enter into new lease arrangements as a lessee that would have substantially the same terms as the existing leases. Alternatively, for the arrangements with one of the lessors, upon an event of default by the nonaffiliated party and the lessor exercising its rights, payment to the lessor would allow AEP to step into the lessor’s rights as well as obtaining title to the assets. Under either situation, AEP would have the ability to utilize the assets in the normal course of barging operations. AEP would also have the right to sell the acquired assets for which it obtained title. As of March 31, 2021, AEP’s boat and barge lease guarantee liability was $3 million, of which $1 million was recorded in Other Current Liabilities and $2 million was recorded in Deferred Credits and Other Noncurrent Liabilities on AEP’s balance sheets. In February 2020, the nonaffiliated party filed Chapter 11 bankruptcy. The party entered into a restructuring support agreement and has announced it expected to continue their operations as normal. In March 2020, the bankruptcy court approved the party’s recapitalization plan. In April 2020, the nonaffiliated party emerged from bankruptcy. Management has determined that it is reasonably possible that enforcement of AEP’s liability for future payments under these leases will be exercised within the next twelve months. In such an event, if AEP is unable to sell or incorporate any of the acquired assets into its fleet operations, it could reduce future net income and cash flows and impact financial condition. ENVIRONMENTAL CONTINGENCIES (Applies to all Registrants except AEPTCo) The Comprehensive Environmental Response Compensation and Liability Act (Superfund) and State Remediation By-products from the generation of electricity include materials such as ash, slag, sludge, low-level radioactive waste and SNF. Coal combustion by-products, which constitute the overwhelming percentage of these materials, are typically treated and deposited in captive disposal facilities or are beneficially utilized. In addition, the generation plants and transmission and distribution facilities have used asbestos, polychlorinated biphenyls and other hazardous and non-hazardous materials. The Registrants currently incur costs to dispose of these substances safely. For remediation processes not specifically discussed, management does not anticipate that the liabilities, if any, arising from such remediation processes would have a material effect on the financial statements. NUCLEAR CONTINGENCIES (Applies to AEP and I&M) I&M owns and operates the Cook Plant under licenses granted by the Nuclear Regulatory Commission. I&M has a significant future financial commitment to dispose of SNF and to safely decommission and decontaminate the plant. The licenses to operate the two nuclear units at the Cook Plant expire in 2034 and 2037. The operation of a nuclear facility also involves special risks, potential liabilities and specific regulatory and safety requirements. By agreement, I&M is partially liable, together with all other electric utility companies that own nuclear generation units, for a nuclear power plant incident at any nuclear plant in the U.S. Should a nuclear incident occur at any nuclear power plant in the U.S., the resultant liability could be substantial. OPERATIONAL CONTINGENCIES Rockport Plant Litigation (Applies to AEP and I&M) In 2013, the Wilmington Trust Company filed a complaint in the U.S. District Court for the Southern District of New York against AEGCo and I&M alleging that it would be unlawfully burdened by the terms of the modified NSR consent decree after the Rockport Plant, Unit 2 lease expiration in December 2022. The terms of the consent decree allow the installation of environmental emission control equipment, repowering, refueling or retirement of the unit. The plaintiffs seek a judgment declaring that the defendants breached the lease, must satisfy obligations related to installation of emission control equipment and indemnify the plaintiffs. The New York court granted a motion to transfer this case to the U.S. District Court for the Southern District of Ohio. AEGCo and I&M sought and were granted dismissal by the U.S. District Court for the Southern District of Ohio of certain of the plaintiffs’ claims, including claims for compensatory damages, breach of contract, breach of the implied covenant of good faith and fair dealing and indemnification of costs. Plaintiffs voluntarily dismissed the surviving claims that AEGCo and I&M failed to exercise prudent utility practices with prejudice, and the court issued a final judgment. The plaintiffs subsequently filed an appeal in the U.S. Court of Appeals for the Sixth Circuit. In 2017, the U.S. Court of Appeals for the Sixth Circuit issued an opinion and judgment affirming the district court’s dismissal of the owners’ breach of good faith and fair dealing claim as duplicative of the breach of contract claims, reversing the district court’s dismissal of the breach of contract claims and remanding the case for further proceedings. Thereafter, AEP filed a motion with the U.S. District Court for the Southern District of Ohio in the original NSR litigation, seeking to modify the consent decree. The district court granted the owners’ unopposed motion to stay the lease litigation to afford time for resolution of AEP’s motion to modify the consent decree. The consent decree was modified based on an agreement among the parties in July 2019. The district court’s stay of the lease litigation expired in August 2020. Upon expiration of the stay, plaintiffs filed a motion for partial summary judgment, arguing that the consent decree violates the facility lease and the participation agreement and requesting that the district court enter a judgment for the plaintiffs on their breach of contract claim. AEP’s memorandum in opposition to plaintiffs’ motion for partial summary judgment was filed in October 2020. At the parties’ request, the district court stayed the case until April 19, 2021 to provide the parties an opportunity to resolve the case. On April 20, 2021, I&M and AEGCo reached an agreement to acquire 100% of the interests in Rockport Plant, Unit 2 for $115.5 million from certain financial institutions that own the unit through trusts established by Wilmington Trust, the nonaffiliated owner trustee of the ownership interests in the unit, with closing to occur as of the end of the Rockport Plant, Unit 2 lease in December 2022. As a result, the parties have submitted a stipulation and order of dismissal requesting that the district court dismiss the case without prejudice to plaintiffs asserting their claims in a re-filed action or in a new action. The agreement is subject to customary closing conditions, including regulatory approvals, and as of the closing will result in a final settlement of, and release of claims in, the lease litigation. Management believes its financial statements appropriately reflect the expected resolution of the pending litigation. Claims Challenging Transition of American Electric Power System Retirement Plan to Cash Balance Formula The American Electric Power System Retirement Plan (the Plan) has received a letter written on behalf of four participants (the Claimants) making a claim for additional plan benefits and purporting to advance such claims on behalf of a class. When the Plan’s benefit formula was changed in the year 2000, AEP provided a special provision for employees hired before January 1, 2001, allowing them to continue benefit accruals under the then benefit formula for a full 10 years alongside of the new cash balance benefit formula then being implemented. Employees who were hired on or after January 1, 2001 accrued benefits only under the new cash balance benefit formula. The Claimants have asserted claims that: (a) the Plan violates the requirements under the Employee Retirement Income Security Act (ERISA) intended to preclude back-loading the accrual of benefits to the end of a participant’s career, (b) the Plan violates the age discrimination prohibitions of ERISA and the Age Discrimination in Employment Act and (c) the company failed to provide required notice regarding the changes to the Plan. AEP has responded to the Claimants providing a reasoned explanation for why each of their claims have been denied. The denial of those claims was appealed to the AEP System Retirement Plan Appeal Committee and the Committee upheld the denial of claims. Management will continue to defend against the claims. Management is unable to determine a range of potential losses that is reasonably possible of occurring. Litigation Related to Ohio House Bill 6 (HB 6) In August 2020, an AEP shareholder filed a putative class action lawsuit in the United States District Court for the Southern District of Ohio against AEP and certain of its officers for alleged violations of securities laws. The amended complaint alleges misrepresentations or omissions by AEP regarding: (a) its alleged participation in or connection to public corruption with respect to the passage of HB 6 and (b) its regulatory, legislative, political contribution, 501 (c)(4) organization contribution and lobbying activities in Ohio. The complaint seeks monetary damages, among other forms of relief. The company will continue to defend against the claims. Management is unable to determine a range of potential losses that is reasonably possible of occurring. In January 2021, an AEP shareholder filed a derivative action in the United States District Court for the Southern District of Ohio purporting to assert claims on behalf of AEP against certain AEP officers and directors. In February 2021, a second AEP shareholder filed a similar derivative action in the Court of Common Pleas of Franklin County, Ohio. In April 2021, a third AEP shareholder filed a similar derivative action in the U.S. District Court for the Southern District of Ohio. These derivative complaints allege the officers and directors made misrepresentations and omissions similar to those alleged in the putative securities class action lawsuit filed against AEP. The derivative complaints together assert claims for: (a) breach of fiduciary duty, (b) waste of corporate assets, (c) unjust enrichment, (d) breach of duty for insider trading and (e) contribution for violations of sections 10(b) and 21D of the Securities Exchange Act of 1934; and seek monetary damages and changes to AEP’s corporate governance and internal policies among other forms of relief. The company will continue to defend against the claims. Management is unable to determine a range of potential losses that is reasonably possible of occurring. On March 1, 2021, AEP received a litigation demand letter from counsel representing a purported AEP shareholder. The litigation demand letter is directed to the Board of Directors of AEP and contains factual allegations involving HB 6 that are generally consistent with those in the derivative litigation filed in state and federal court. The letter demands, among other things, that the AEP Board undertake an independent investigation into alleged legal violations by directors and officers, and that, following such investigation, the Company commence a civil action for breaches of fiduciary duty and related claims and take appropriate disciplinary action against those individuals who allegedly harmed the company. The AEP Board will act in response to the letter as appropriate. Management is unable to determine a range of potential losses that is reasonably possible of occurring.

Benefit Plans

Benefit Plans	3 Months Ended
	Mar. 31, 2021
Benefit Plans	BENEFIT PLANS The disclosures in this note apply to all Registrants except AEPTCo unless indicated otherwise. AEP sponsors a qualified pension plan and two unfunded nonqualified pension plans. Substantially all AEP employees are covered by the qualified plan or both the qualified and a nonqualified pension plan. AEP also sponsors OPEB plans to provide health and life insurance benefits for retired employees. Components of Net Periodic Benefit Cost The following tables provide the components of net periodic benefit cost (credit) by Registrant for the plans: AEP Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2021 2020 2021 2020 (in millions) Service Cost $ 32.3 $ 28.0 $ 2.4 $ 2.5 Interest Cost 34.3 42.0 7.6 9.9 Expected Return on Plan Assets (57.5) (66.2) (22.8) (23.9) Amortization of Prior Service Credit — — (17.7) (17.4) Amortization of Net Actuarial Loss 25.4 23.4 — 1.5 Net Periodic Benefit Cost (Credit) $ 34.5 $ 27.2 $ (30.5) $ (27.4) AEP Texas Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2021 2020 2021 2020 (in millions) Service Cost $ 3.0 $ 2.6 $ 0.2 $ 0.2 Interest Cost 2.8 3.5 0.6 0.8 Expected Return on Plan Assets (4.9) (5.7) (1.9) (2.0) Amortization of Prior Service Credit — — (1.5) (1.4) Amortization of Net Actuarial Loss 2.1 1.9 — 0.1 Net Periodic Benefit Cost (Credit) $ 3.0 $ 2.3 $ (2.6) $ (2.3) APCo Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2021 2020 2021 2020 (in millions) Service Cost $ 3.0 $ 2.6 $ 0.3 $ 0.3 Interest Cost 4.1 5.1 1.2 1.6 Expected Return on Plan Assets (7.3) (8.4) (3.4) (3.6) Amortization of Prior Service Credit — — (2.6) (2.5) Amortization of Net Actuarial Loss 3.0 2.8 — 0.2 Net Periodic Benefit Cost (Credit) $ 2.8 $ 2.1 $ (4.5) $ (4.0) I&M Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2021 2020 2021 2020 (in millions) Service Cost $ 4.4 $ 3.9 $ 0.3 $ 0.3 Interest Cost 4.0 4.9 0.9 1.2 Expected Return on Plan Assets (7.2) (8.3) (2.8) (2.9) Amortization of Prior Service Credit — — (2.4) (2.4) Amortization of Net Actuarial Loss 2.9 2.7 — 0.2 Net Periodic Benefit Cost (Credit) $ 4.1 $ 3.2 $ (4.0) $ (3.6) OPCo Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2021 2020 2021 2020 (in millions) Service Cost $ 2.9 $ 2.4 $ 0.2 $ 0.2 Interest Cost 3.1 3.9 0.8 1.0 Expected Return on Plan Assets (5.6) (6.6) (2.4) (2.6) Amortization of Prior Service Credit — — (1.8) (1.8) Amortization of Net Actuarial Loss 2.2 2.1 — 0.2 Net Periodic Benefit Cost (Credit) $ 2.6 $ 1.8 $ (3.2) $ (3.0) PSO Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2021 2020 2021 2020 (in millions) Service Cost $ 1.9 $ 1.8 $ 0.2 $ 0.2 Interest Cost 1.7 2.1 0.4 0.5 Expected Return on Plan Assets (3.1) (3.6) (1.3) (1.3) Amortization of Prior Service Credit — — (1.1) (1.1) Amortization of Net Actuarial Loss 1.3 1.2 — 0.1 Net Periodic Benefit Cost (Credit) $ 1.8 $ 1.5 $ (1.8) $ (1.6) SWEPCo Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2021 2020 2021 2020 (in millions) Service Cost $ 2.9 $ 2.5 $ 0.1 $ 0.2 Interest Cost 2.1 2.5 0.5 0.6 Expected Return on Plan Assets (3.4) (3.9) (1.5) (1.5) Amortization of Prior Service Credit — — (1.3) (1.3) Amortization of Net Actuarial Loss 1.5 1.4 — 0.1 Net Periodic Benefit Cost (Credit) $ 3.1 $ 2.5 $ (2.2) $ (1.9)

Business Segments

Business Segments	3 Months Ended
	Mar. 31, 2021
Business Segments	BUSINESS SEGMENTS The disclosures in this note apply to all Registrants unless indicated otherwise. AEP’s Reportable Segments AEP’s primary business is the generation, transmission and distribution of electricity. Within its Vertically Integrated Utilities segment, AEP centrally dispatches generation assets and manages its overall utility operations on an integrated basis because of the substantial impact of cost-based rates and regulatory oversight. Intersegment sales and transfers are generally based on underlying contractual arrangements and agreements. AEP’s reportable segments and their related business activities are outlined below: Vertically Integrated Utilities • Generation, transmission and distribution of electricity for sale to retail and wholesale customers through assets owned and operated by AEGCo, APCo, I&M, KGPCo, KPCo, PSO, SWEPCo and WPCo. Transmission and Distribution Utilities • Transmission and distribution of electricity for sale to retail and wholesale customers through assets owned and operated by AEP Texas and OPCo. • OPCo purchases energy and capacity to serve standard service offer customers and provides transmission and distribution services for all connected load. AEP Transmission Holdco • Development, construction and operation of transmission facilities through investments in AEPTCo. These investments have FERC-approved ROEs. • Development, construction and operation of transmission facilities through investments in AEP’s transmission-only joint ventures. These investments have PUCT-approved or FERC-approved ROEs. Generation & Marketing • Contracted renewable energy investments and management services. • Marketing, risk management and retail activities in ERCOT, PJM, SPP and MISO. • Competitive generation in PJM. The remainder of AEP’s activities is presented as Corporate and Other. While not considered a reportable segment, Corporate and Other primarily includes the purchasing of receivables from certain AEP utility subsidiaries, Parent’s guarantee revenue received from affiliates, investment income, interest income, interest expense, income tax expense and other nonallocated costs. The tables below present AEP’s reportable segment income statement information for the three months ended March 31, 2021 and 2020 and reportable segment balance sheet information as of March 31, 2021 and December 31, 2020. Three Months Ended March 31, 2021 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) Revenues from: External Customers $ 2,504.5 $ 1,082.3 $ 87.9 $ 601.7 $ 4.7 $ — $ 4,281.1 Other Operating Segments 32.8 5.8 289.1 32.5 8.2 (368.4) — Total Revenues $ 2,537.3 $ 1,088.1 $ 377.0 $ 634.2 $ 12.9 $ (368.4) $ 4,281.1 Net Income (Loss) $ 271.4 $ 114.4 $ 173.2 $ 38.2 $ (18.4) $ — $ 578.8 Three Months Ended March 31, 2020 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) Revenues from: External Customers $ 2,193.0 $ 1,075.2 $ 73.1 $ 408.4 $ (2.2) $ — $ 3,747.5 Other Operating Segments 33.7 31.7 237.1 30.2 22.1 (354.8) — Total Revenues $ 2,226.7 $ 1,106.9 $ 310.2 $ 438.6 $ 19.9 $ (354.8) $ 3,747.5 Net Income (Loss) $ 246.3 $ 116.2 $ 141.6 $ 30.5 $ (35.3) $ — $ 499.3 March 31, 2021 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Consolidated (in millions) Total Property, Plant and Equipment $ 49,448.9 $ 21,492.9 $ 12,185.2 $ 2,080.6 $ 405.3 $ — $ 85,612.9 Accumulated Depreciation and Amortization 15,950.1 3,951.3 648.1 183.8 183.5 — 20,916.8 Total Property Plant and Equipment - Net $ 33,498.8 $ 17,541.6 $ 11,537.1 $ 1,896.8 $ 221.8 $ — $ 64,696.1 Total Assets $ 44,591.3 $ 20,076.9 $ 12,925.8 $ 3,881.8 $ 6,072.0 (b) $ (4,562.7) (c) $ 82,985.1 Long-term Debt Due Within One Year: Nonaffiliated $ 1,078.3 $ 589.0 $ 52.4 $ — $ 410.5 (d) $ — $ 2,130.2 Long-term Debt: Affiliated 65.0 — — — — (65.0) — Nonaffiliated 13,185.8 7,097.4 4,089.7 — 5,841.9 (d) — 30,214.8 Total Long-term Debt $ 14,329.1 $ 7,686.4 $ 4,142.1 $ — $ 6,252.4 (d) $ (65.0) $ 32,345.0 December 31, 2020 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Consolidated (in millions) Total Property, Plant and Equipment $ 49,023.3 $ 21,145.0 $ 11,827.2 $ 1,910.2 $ 407.3 $ — $ 84,313.0 Accumulated Depreciation and Amortization 15,586.2 3,879.3 595.7 166.1 184.1 — 20,411.4 Total Property Plant and Equipment - Net $ 33,437.1 $ 17,265.7 $ 11,231.5 $ 1,744.1 $ 223.2 $ — $ 63,901.6 Total Assets $ 42,752.7 $ 19,765.9 $ 12,627.3 $ 3,585.9 $ 5,987.1 (b) $ (3,961.7) (c) $ 80,757.2 Long-term Debt Due Within One Year: Nonaffiliated $ 1,034.6 $ 588.8 $ 52.3 $ — $ 410.4 (d) $ — $ 2,086.1 Long-term Debt: Affiliated 65.0 — — — — (65.0) — Nonaffiliated 12,375.6 6,661.9 4,075.7 — 5,873.2 (d) — 28,986.4 Total Long-term Debt $ 13,475.2 $ 7,250.7 $ 4,128.0 $ — $ 6,283.6 (d) $ (65.0) $ 31,072.5 (a) Corporate and Other primarily includes the purchasing of receivables from certain AEP utility subsidiaries. This segment also includes Parent’s guarantee revenue received from affiliates, investment income, interest income, interest expense and other nonallocated costs. (b) Includes elimination of AEP Parent’s investments in wholly-owned subsidiary companies. (c) Reconciling Adjustments for Total Assets primarily include elimination of intercompany advances to affiliates and intercompany accounts receivable. (d) Amounts are inclusive of the impact of fair value hedge accounting. See “Accounting for Fair Value Hedging Strategies” section of Note 10 for additional information. Registrant Subsidiaries’ Reportable Segments (Applies to all Registrant Subsidiaries except AEPTCo) The Registrant Subsidiaries each have one reportable segment, an integrated electricity generation, transmission and distribution business for APCo, I&M, PSO and SWEPCo, and an integrated electricity transmission and distribution business for AEP Texas and OPCo. Other activities are insignificant. The Registrant Subsidiaries’ operations are managed on an integrated basis because of the substantial impact of cost-based rates and regulatory oversight on the business process, cost structures and operating results. AEPTCo’s Reportable Segments AEPTCo Parent is the holding company of seven FERC-regulated transmission-only electric utilities. The seven State Transcos have been identified as operating segments of AEPTCo under the accounting guidance for “Segment Reporting.” The State Transcos business consists of developing, constructing and operating transmission facilities at the request of the RTOs in which they operate and in replacing and upgrading facilities, assets and components of the existing AEP transmission system as needed to maintain reliability standards and provide service to AEP’s wholesale and retail customers. The State Transcos are regulated for rate-making purposes exclusively by the FERC and earn revenues through tariff rates charged for the use of their electric transmission systems. AEPTCo’s Chief Operating Decision Maker makes operating decisions, allocates resources to and assesses performance based on these operating segments. The State Transcos operating segments all have similar economic characteristics and meet all of the criteria under the accounting guidance for “Segment Reporting” to be aggregated into one operating segment. As a result, AEPTCo has one reportable segment. The remainder of AEPTCo’s activity is presented in AEPTCo Parent. While not considered a reportable segment, AEPTCo Parent represents the activity of the holding company which primarily relates to debt financing activity and general corporate activities. The tables below present AEPTCo’s reportable segment income statement information for the three months ended March 31, 2021 and 2020 and reportable segment balance sheet information as of March 31, 2021 and December 31, 2020. Three Months Ended March 31, 2021 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Revenues from: External Customers $ 76.0 $ — $ — $ 76.0 Sales to AEP Affiliates 285.6 — — 285.6 Other Revenues 0.1 — — 0.1 Total Revenues $ 361.7 $ — $ — $ 361.7 Interest Income $ — $ 38.3 $ (38.2) (a) $ 0.1 Interest Expense 34.1 38.2 (38.2) (a) 34.1 Income Tax Expense 39.6 — — 39.6 Net Income $ 151.7 $ — (b) $ — $ 151.7 Three Months Ended March 31, 2020 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Revenues from: External Customers $ 61.3 $ — $ — $ 61.3 Sales to AEP Affiliates 233.7 — — 233.7 Other Revenues 0.6 — — 0.6 Total Revenues $ 295.6 $ — $ — $ 295.6 Interest Income $ 0.2 $ 34.0 $ (33.4) (a) $ 0.8 Interest Expense 29.6 33.4 (33.4) (a) 29.6 Income Tax Expense 31.8 — — 31.8 Net Income $ 117.3 $ 0.5 (b) $ — $ 117.8 March 31, 2021 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Total Transmission Property $ 11,694.0 $ — $ — $ 11,694.0 Accumulated Depreciation and Amortization 623.6 — — 623.6 Total Transmission Property – Net $ 11,070.4 $ — $ — $ 11,070.4 Notes Receivable - Affiliated $ — $ 3,899.0 $ (3,899.0) (c) $ — Total Assets $ 11,458.3 $ 4,107.2 (d) $ (4,050.4) (e) $ 11,515.1 Total Long-term Debt $ 3,990.0 $ 3,949.0 $ (3,990.0) (c) $ 3,949.0 December 31, 2020 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Total Transmission Property $ 11,345.6 $ — $ — $ 11,345.6 Accumulated Depreciation and Amortization 572.8 — — 572.8 Total Transmission Property – Net $ 10,772.8 $ — $ — $ 10,772.8 Notes Receivable - Affiliated $ — $ 3,948.5 $ (3,948.5) (c) $ — Total Assets $ 11,185.1 $ 4,084.0 (d) $ (4,023.1) (e) $ 11,246.0 Total Long-term Debt $ 3,990.0 $ 3,948.5 $ (3,990.0) (c) $ 3,948.5 (a) Elimination of intercompany interest income/interest expense on affiliated debt arrangement. (b) Includes the elimination of AEPTCo Parent’s equity earnings in the State Transcos. (c) Elimination of intercompany debt. (d) Includes the elimination of AEPTCo Parent’s investments in State Transcos. (e) Primarily relates to the elimination of Notes Receivable from the State Transcos.

Derivatives and Hedging

Derivatives and Hedging	3 Months Ended
	Mar. 31, 2021
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 AEP subsidiaries, including the Registrant Subsidiaries. AEPEP is agent for and transacts on behalf of other AEP subsidiaries. The Registrants are exposed to certain market risks as major power producers and participants in the electricity, capacity, natural gas, coal and emission allowance markets. These risks include commodity price risks which may be subject to capacity risk, interest rate risk and credit risk. These risks represent the risk of loss that may impact the Registrants due to changes in the underlying market prices or rates. Management utilizes derivative instruments to manage these risks. STRATEGIES FOR UTILIZATION OF DERIVATIVE INSTRUMENTS TO ACHIEVE OBJECTIVES Risk Management Strategies The strategy surrounding the use of derivative instruments primarily focuses on managing risk exposures, future cash flows and creating value utilizing both economic and formal hedging strategies. The risk management strategies also include the use of derivative instruments for trading purposes which focus on seizing market opportunities to create value driven by expected changes in the market prices of the commodities. To accomplish these objectives, the Registrants primarily employ risk management contracts including physical and financial forward purchase-and-sale contracts and, to a lesser extent, OTC swaps and options. Not all risk management contracts meet the definition of a derivative under the accounting guidance for “Derivatives and Hedging.” Derivative risk management contracts elected normal under the normal purchases and normal sales scope exception are not subject to the requirements of this accounting guidance. The Registrants utilize power, capacity, coal, natural gas, interest rate and, to a lesser extent, heating oil, gasoline and other commodity contracts to manage the risk associated with the energy business. The Registrants utilize interest rate derivative contracts in order to manage the interest rate exposure associated with the commodity portfolio. For disclosure purposes, such risks are grouped as “Commodity,” as these risks are related to energy risk management activities. The Registrants also utilize derivative contracts to manage interest rate risk associated with debt financing. For disclosure purposes, these risks are grouped as “Interest Rate.” The amount of risk taken is determined by the Commercial Operations, Energy Supply and Finance groups in accordance with established risk management policies as approved by the Finance Committee of the Board of Directors. The following tables represent the gross notional volume of the Registrants’ outstanding derivative contracts: Notional Volume of Derivative Instruments March 31, 2021 Primary Risk Unit of AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power MWhs 271.2 — 23.3 10.8 2.9 3.8 1.6 Natural Gas MMBtus 22.7 — — — — — 7.0 Heating Oil and Gasoline Gallons 5.0 1.3 0.8 0.5 1.0 0.5 0.7 Interest Rate USD $ 123.6 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt USD $ 950.0 $ — $ — $ — $ — $ — $ — December 31, 2020 Primary Risk Unit of AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power MWhs 331.3 — 46.9 19.7 3.0 11.9 4.0 Natural Gas MMBtus 26.9 — — — — — 7.9 Heating Oil and Gasoline Gallons 6.9 1.8 1.1 0.6 1.4 0.7 0.9 Interest Rate USD $ 129.8 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt USD $ 1,150.0 $ — $ 200.0 $ — $ — $ — $ — Fair Value Hedging Strategies (Applies to AEP) Parent enters into interest rate derivative transactions as part of an overall strategy to manage the mix of fixed-rate and floating-rate debt. Certain interest rate derivative transactions effectively modify exposure to interest rate risk by converting a portion of fixed-rate debt to a floating-rate. Provided specific criteria are met, these interest rate derivatives may be designated as fair value hedges. Cash Flow Hedging Strategies The Registrants utilize cash flow hedges on certain derivative transactions for the purchase and sale of power (“Commodity”) in order to manage the variable price risk related to forecasted purchases and sales. Management monitors the potential impacts of commodity price changes and, where appropriate, enters into derivative transactions to protect profit margins for a portion of future electricity sales and purchases. The Registrants do not hedge all commodity price risk. The Registrants utilize a variety of interest rate derivative transactions in order to manage interest rate risk exposure. The Registrants also utilize interest rate derivative contracts to manage interest rate exposure related to future borrowings of fixed-rate debt. The Registrants do not hedge all interest rate exposure. ACCOUNTING FOR DERIVATIVE INSTRUMENTS AND THE IMPACT ON THE FINANCIAL STATEMENTS The accounting guidance for “Derivatives and Hedging” requires recognition of all qualifying derivative instruments as either assets or liabilities on the balance sheets at fair value. The fair values of derivative instruments accounted for using MTM accounting or hedge accounting are based on exchange prices and broker quotes. If a quoted market price is not available, the estimate of fair value is based on the best information available including valuation models that estimate future energy prices based on existing market and broker quotes and other assumptions. In order to determine the relevant fair values of the derivative instruments, the Registrants apply valuation adjustments for discounting, liquidity and credit quality. Credit risk is the risk that a counterparty will fail to perform on the contract or fail to pay amounts due. Liquidity risk represents the risk that imperfections in the market will cause the price to vary from estimated fair value based upon prevailing market supply and demand conditions. Since energy markets are imperfect and volatile, there are inherent risks related to the underlying assumptions in models used to fair value risk management contracts. Unforeseen events may cause reasonable price curves to differ from actual price curves throughout a contract’s term and at the time a contract settles. Consequently, there could be significant adverse or favorable effects on future net income and cash flows if market prices are not consistent with management’s estimates of current market consensus for forward prices in the current period. This is particularly true for longer term contracts. Cash flows may vary based on market conditions, margin requirements and the timing of settlement of risk management contracts. According to the accounting guidance for “Derivatives and Hedging,” the Registrants reflect the fair values of derivative instruments subject to netting agreements with the same counterparty net of related cash collateral. For certain risk management contracts, the Registrants are required to post or receive cash collateral based on third-party contractual agreements and risk profiles. AEP netted cash collateral received from third-parties against short-term and long-term risk management assets in the amounts of $3 million and $3 million as of March 31, 2021 and December 31, 2020, respectively. AEP netted cash collateral paid to third-parties against short-term and long-term risk management liabilities in the amounts of $8 million and $7 million as of March 31, 2021 and December 31, 2020, respectively. The netted cash collateral from third-parties against short-term and long-term risk management assets and netted cash collateral paid to third-parties against short-term and long-term risk management liabilities were immaterial for the Registrant Subsidiaries as of March 31, 2021 and December 31, 2020. The following tables represent the gross fair value of the Registrants’ derivative activity on the balance sheets: AEP March 31, 2021 Risk Hedging Contracts Gross Amounts Gross Net Amounts of Balance Sheet Location Commodity (a) Commodity (a) Interest Rate (a) (in millions) Current Risk Management Assets $ 164.1 $ 34.8 $ 2.7 $ 201.6 $ (129.5) $ 72.1 Long-term Risk Management Assets 266.9 18.8 — 285.7 (20.9) 264.8 Total Assets 431.0 53.6 2.7 487.3 (150.4) 336.9 Current Risk Management Liabilities 133.6 34.8 — 168.4 (129.3) 39.1 Long-term Risk Management Liabilities 219.8 41.6 37.4 298.8 (25.8) 273.0 Total Liabilities 353.4 76.4 37.4 467.2 (155.1) 312.1 Total MTM Derivative Contract Net Assets (Liabilities) $ 77.6 $ (22.8) $ (34.7) $ 20.1 $ 4.7 $ 24.8 December 31, 2020 Risk Hedging Contracts Gross Amounts Gross Net Amounts of Balance Sheet Location Commodity (a) Commodity (a) Interest Rate (a) (in millions) Current Risk Management Assets $ 239.1 $ 21.1 $ 5.0 $ 265.2 $ (170.5) $ 94.7 Long-term Risk Management Assets 275.9 18.0 — 293.9 (51.7) 242.2 Total Assets 515.0 39.1 5.0 559.1 (222.2) 336.9 Current Risk Management Liabilities 193.0 54.4 3.4 250.8 (172.0) 78.8 Long-term Risk Management Liabilities 222.2 60.1 4.1 286.4 (53.6) 232.8 Total Liabilities 415.2 114.5 7.5 537.2 (225.6) 311.6 Total MTM Derivative Contract Net Assets (Liabilities) $ 99.8 $ (75.4) $ (2.5) $ 21.9 $ 3.4 $ 25.3 AEP Texas March 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 0.8 $ (0.8) $ — Long-term Risk Management Assets — — — Total Assets 0.8 (0.8) — Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — — — Total Liabilities — — — Total MTM Derivative Contract Net Assets (Liabilities) $ 0.8 $ (0.8) $ — December 31, 2020 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 0.4 $ (0.4) $ — Long-term Risk Management Assets — — — Total Assets 0.4 (0.4) — Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — — — Total Liabilities — — — Total MTM Derivative Contract Net Assets (Liabilities) $ 0.4 $ (0.4) $ — APCo March 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 16.5 $ (9.6) $ 6.9 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets 0.5 (0.5) — Total Assets 17.0 (10.1) 6.9 Other Current Liabilities - Current Risk Management Liabilities 9.3 (9.1) 0.2 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities 0.5 (0.5) — Total Liabilities 9.8 (9.6) 0.2 Total MTM Derivative Contract Net Assets (Liabilities) $ 7.2 $ (0.5) $ 6.7 December 31, 2020 Gross Amounts Risk of Risk Gross Amounts Net Amounts of Assets/ Management Hedging Management Offset in the Liabilities Presented in Contracts – Contracts – Assets/Liabilities Statement of the Statement of Balance Sheet Location Commodity (a) Interest Rate (a) Recognized Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 38.8 $ 2.4 $ 41.2 $ (18.8) $ 22.4 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets 0.7 — 0.7 (0.6) 0.1 Total Assets 39.5 2.4 41.9 (19.4) 22.5 Other Current Liabilities - Current Risk Management Liabilities 19.7 3.4 23.1 (18.5) 4.6 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities 0.6 — 0.6 (0.5) 0.1 Total Liabilities 20.3 3.4 23.7 (19.0) 4.7 Total MTM Derivative Contract Net Assets (Liabilities) $ 19.2 $ (1.0) $ 18.2 $ (0.4) $ 17.8 I&M March 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 6.8 $ (5.9) $ 0.9 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets 0.3 (0.3) — Total Assets 7.1 (6.2) 0.9 Other Current Liabilities - Current Risk Management Liabilities 6.2 (6.0) 0.2 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities 0.3 (0.3) — Total Liabilities 6.5 (6.3) 0.2 Total MTM Derivative Contract Net Assets $ 0.6 $ 0.1 $ 0.7 December 31, 2020 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 17.2 $ (13.6) $ 3.6 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets 0.5 (0.4) 0.1 Total Assets 17.7 (14.0) 3.7 Other Current Liabilities - Current Risk Management Liabilities 12.1 (12.0) 0.1 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities 0.4 (0.3) 0.1 Total Liabilities 12.5 (12.3) 0.2 Total MTM Derivative Contract Net Assets (Liabilities) $ 5.2 $ (1.7) $ 3.5 OPCo March 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 0.6 $ (0.6) $ — Long-term Risk Management Assets — — — Total Assets 0.6 (0.6) — Current Risk Management Liabilities 8.1 — 8.1 Long-term Risk Management Liabilities 95.9 — 95.9 Total Liabilities 104.0 — 104.0 Total MTM Derivative Contract Net Liabilities $ (103.4) $ (0.6) $ (104.0) December 31, 2020 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 0.3 $ (0.3) $ — Long-term Risk Management Assets — — — Total Assets 0.3 (0.3) — Current Risk Management Liabilities 8.7 — 8.7 Long-term Risk Management Liabilities 101.6 — 101.6 Total Liabilities 110.3 — 110.3 Total MTM Derivative Contract Net Liabilities $ (110.0) $ (0.3) $ (110.3) PSO March 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 5.8 $ (0.3) $ 5.5 Long-term Risk Management Assets — — — Total Assets 5.8 (0.3) 5.5 Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — — — Total Liabilities — — — Total MTM Derivative Contract Net Assets (Liabilities) $ 5.8 $ (0.3) $ 5.5 December 31, 2020 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 10.5 $ (0.2) $ 10.3 Long-term Risk Management Assets — — — Total Assets 10.5 (0.2) 10.3 Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — — — Total Liabilities — — — Total MTM Derivative Contract Net Assets (Liabilities) $ 10.5 $ (0.2) $ 10.3 SWEPCo March 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 1.7 $ (0.4) $ 1.3 Long-term Risk Management Assets — — — Total Assets 1.7 (0.4) 1.3 Current Risk Management Liabilities — — — Long-term Risk Management Liabilities 0.9 — 0.9 Total Liabilities 0.9 — 0.9 Total MTM Derivative Contract Net Assets (Liabilities) $ 0.8 $ (0.4) $ 0.4 December 31, 2020 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 3.4 $ (0.2) $ 3.2 Long-term Risk Management Assets — — — Total Assets 3.4 (0.2) 3.2 Current Risk Management Liabilities 0.7 — 0.7 Long-term Risk Management Liabilities 1.0 — 1.0 Total Liabilities 1.7 — 1.7 Total MTM Derivative Contract Net Assets (Liabilities) $ 1.7 $ (0.2) $ 1.5 (a) Derivative instruments within these categories are reported gross. These instruments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with the accounting guidance for “Derivatives and Hedging.” (b) Amounts include counterparty netting of risk management and hedging contracts and associated cash collateral in accordance with the accounting guidance for “Derivatives and Hedging.” (c) All derivative contracts subject to a master netting arrangement or similar agreement are offset in the statement of financial position. The tables below present the Registrants’ amount of gain (loss) recognized on risk management contracts: Amount of Gain (Loss) Recognized on Risk Management Contracts Three Months Ended March 31, 2021 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 0.2 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues (0.4) — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.2 — — — — Purchased Electricity for Resale 0.4 — 0.4 — — — — Other Operation 0.3 0.1 — — 0.1 — — Maintenance 0.5 0.1 0.1 0.1 0.1 0.1 0.1 Regulatory Assets (a) 6.4 — — (0.9) 6.6 — 0.8 Regulatory Liabilities (a) 22.0 0.4 3.4 (3.2) 2.9 11.2 6.2 Total Gain (Loss) on Risk Management Contracts $ 29.4 $ 0.6 $ 4.1 $ (4.0) $ 9.7 $ 11.3 $ 7.1 Three Months Ended March 31, 2020 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 0.4 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues (10.3) — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.2 0.1 — — — Purchased Electricity for Resale 0.1 — 0.1 — — — — Other Operation (0.2) (0.1) — — (0.1) — — Maintenance (0.2) (0.1) (0.1) — — — — Regulatory Assets (a) (33.9) (1.2) (8.9) (0.7) (18.4) (0.5) (0.2) Regulatory Liabilities (a) 11.2 — (7.3) 3.2 3.5 8.1 3.3 Total Gain (Loss) on Risk Management Contracts $ (32.9) $ (1.4) $ (16.0) $ 2.6 $ (15.0) $ 7.6 $ 3.1 (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 expense line item on the statements of income as that of the associated risk. However, unrealized and some realized gains and losses in regulated jurisdictions for both trading and non-trading derivative instruments are recorded as regulatory assets (for losses) or regulatory liabilities (for gains) in accordance with the accounting guidance for “Regulated Operations.” Accounting for Fair Value Hedging Strategies (Applies to AEP) For fair value hedges (i.e. hedging the exposure to changes in the fair value of an asset, liability or an identified portion thereof attributable to a particular risk), the gain or loss on the derivative instrument as well as the offsetting gain or loss on the hedged item associated with the hedged risk impacts net income during the period of change. AEP records realized and unrealized gains or losses on interest rate swaps that are designated and qualify for fair value hedge accounting treatment and any offsetting changes in the fair value of the debt being hedged in Interest Expense on the statements of income. The following table shows the impacts recognized on the balance sheets related to the hedged items in fair value hedging relationships: Carrying Amount of the Hedged Liabilities Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of the Hedged Liabilities March 31, 2021 December 31, 2020 March 31, 2021 December 31, 2020 (in millions) Long-term Debt (a) (b) $ (959.4) $ (995.9) $ (16.6) $ (51.7) (a) Amounts included on the balance sheets within Long-term Debt Due within One Year and Long-term Debt, respectively. (b) Amounts include $(51) million and $(53) million as of March 31, 2021 and December 31, 2020, respectively, for the fair value hedge adjustment of hedged debt obligations for which hedge accounting has been discontinued. The pretax effects of fair value hedge accounting on income were as follows: Three Months Ended March 31, 2021 2020 (in millions) Gain (Loss) on Interest Rate Contracts: Fair Value Hedging Instruments (a) $ (33.2) $ 42.5 Fair Value Portion of Long-term Debt (a) 33.2 (42.5) (a) Gain (Loss) is included in Interest Expense on the statements of income. In June 2020, AEP terminated a $500 million notional amount interest rate swap resulting in the discontinuance of the hedging relationship. A gain of $57 million on the fair value of the hedging instrument was settled in cash and recorded within operating activities on the statements of cash flows. Subsequent to the discontinuation of hedge accounting, the remaining adjustment to the carrying amount of the hedged item of $57 million will be amortized on a straight line basis through November 2027 in Interest Expense on the statements of income. Accounting for Cash Flow Hedging Strategies For cash flow hedges (i.e. hedging the exposure to variability in expected future cash flows that is attributable to a particular risk), the Registrants initially report the gain or loss on the derivative instrument as a component of Accumulated Other Comprehensive Income (Loss) on the balance sheets until the period the hedged item affects net income. Realized gains and losses on derivative contracts for the purchase and sale of power designated as cash flow hedges are included in Total Revenues or Purchased Electricity for Resale on the statements of income or in Regulatory Assets or Regulatory Liabilities on the balance sheets, depending on the specific nature of the risk being hedged. During the three months ended March 31, 2021 and 2020, AEP applied cash flow hedging to outstanding power derivatives. During the three months ended March 31, 2021 and 2020, the Registrant Subsidiaries did not apply cash flow hedging to outstanding power derivatives. The Registrants reclassify gains and losses on interest rate derivative hedges related to debt financings from Accumulated Other Comprehensive Income (Loss) on the balance sheets into Interest Expense on the statements of income in those periods in which hedged interest payments occur. During the three months ended March 31, 2021 and 2020, AEP and APCo applied cash flow hedging to outstanding interest rate derivatives and the other Registrant Subsidiaries did not. For details on effective cash flow hedges included in Accumulated Other Comprehensive Income (Loss) on the balance sheets and the reasons for changes in cash flow hedges, see Note 3 - Comprehensive Income. Cash flow hedges included in Accumulated Other Comprehensive Income (Loss) on the balance sheets were: Impact of Cash Flow Hedges on AEP’s Balance Sheets March 31, 2021 December 31, 2020 Commodity Interest Rate Commodity Interest Rate (in millions) AOCI Loss Net of Tax $ (18.5) $ (33.3) $ (60.6) $ (47.5) Portion Expected to be Reclassed to Net Income During the Next Twelve Months (0.3) (5.1) (27.1) (5.7) As of March 31, 2021 the maximum length of time that AEP is hedging its exposure to variability in future cash flows related to forecasted transactions is 120 months and 117 months for commodity and interest rate hedges, respectively. Impact of Cash Flow Hedges on the Registrant Subsidiaries’ Balance Sheets March 31, 2021 December 31, 2020 Interest Rate Expected to be Expected to be Reclassified to Reclassified to Net Income During Net Income During AOCI Gain (Loss) the Next AOCI Gain (Loss) the Next Company Net of Tax Twelve Months Net of Tax Twelve Months (in millions) AEP Texas $ (2.0) $ (1.1) $ (2.3) $ (1.1) APCo 8.2 0.8 (0.8) 0.4 I&M (7.8) (1.6) (8.3) (1.6) PSO — — 0.1 0.1 SWEPCo 0.1 (1.2) (0.3) (1.5) 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. Collateral Triggering Events Credit Downgrade Triggers (Applies to AEP, APCo, I&M, PSO and SWEPCo) A limited number of derivative contracts include collateral triggering events, which include a requirement to maintain certain credit ratings. On an ongoing basis, AEP’s risk management organization assesses the appropriateness of these collateral triggering events in contracts. The Registrants have not experienced a downgrade below a specified credit rating threshold that would require the posting of additional collateral. AEP had two derivative contracts with collateral triggering events in a net liability position as of March 31, 2021, however the exposure is immaterial. The Registrant Subsidiaries had no derivative contracts with collateral triggering events in a net liability position as of March 31, 2021. The Registrants had no derivative contracts with collateral triggering events in a net liability position as of December 31, 2020. Cross-Default Triggers (Applies to AEP, APCo, I&M and SWEPCo) In addition, a majority of non-exchange traded commodity contracts contain cross-default provisions that, if triggered, would permit the counterparty to declare a default and require settlement of the outstanding payable. These cross-default provisions could be triggered if there was a non-performance event by Parent or the obligor under outstanding debt or a third-party obligation that is $50 million or greater. On an ongoing basis, AEP’s risk management organization assesses the appropriateness of these cross-default provisions in the contracts. The following tables represent: (a) the fair value of these derivative liabilities subject to cross-default provisions prior to consideration of contractual netting arrangements, (b) the amount that the exposure has been reduced by cash collateral posted and (c) if a cross-default provision would have been triggered, the settlement amount that would be required after considering contractual netting arrangements: March 31, 2021 Liabilities for Additional Contracts with Cross Settlement Default Provisions Liability if Cross Prior to Contractual Amount of Cash Default Provision Company Netting Arrangements Collateral Posted is Triggered (in millions) AEP $ 156.8 $ — $ 127.7 APCo 0.6 — 0.1 I&M 0.4 — 0.1 SWEPCo 0.9 — 0.9 December 31, 2020 Liabilities for Additional Contracts with Cross Settlement Default Provisions Liability if Cross Prior to Contractual Amount of Cash Default Provision Company Netting Arrangements Collateral Posted is Triggered (in millions) AEP $ 188.4 $ — $ 169.2 APCo 4.3 — 3.5 I&M 0.5 — 0.1 SWEPCo 1.8 — 1.8 Warrants Held in Investee (Applies to AEP) AEP holds an investment in ChargePoint, which completed an initial public offering (IPO) in February 2021 via a reverse merger with a public special purpose acquisition company. Before the IPO, AEP’s interests in ChargePoint consisted of a noncontrolling equity interest of preferred shares, which were accounted for at their historical cost of $8 million as of December 31, 2020, and common share warrants. After the IPO, AEP’s interests in ChargePoint consisted of a noncontrolling equity interest of common shares, which were accounted for at their fair value of $35 million as of March 31, 2021, and common share warrants. AEP recorded an unrealized gain of $27 million associated with the common shares for the three months ended March 31, 2021, presented in Other Income (Expense) on AEP’s statements of income. Management has determined the common share warrants are derivative instruments based on the accounting guidance for “Derivatives and Hedging”. As of March 31, 2021 and December 31, 2020, the warrants were valued at $22 million and $32 million, respectively, and were recorded in Deferred Charges and Other Noncurrent Assets on AEP’s balance sheets. AEP recognized an unrealized loss of $10 million associated with the warrants for the three months ended March 31, 2021, presented in Other Income (Expense) on AEP’s statements of income. Management utilized a Black-Scholes options pricing model to value the warrants as of March 31, 2021 and December 31, 2020. The valuation contemplated a liquidity adjustment that resulted in the overall fair value of the warrants being categorized as Level 3 in the fair value hierarchy as of December 31, 2020. After the IPO, there was an observable publicly traded stock price to use in the Black-Scholes options pricing model, which resulted in the warrants being categorized as Level 2 as of March 31, 2021. The common shares are also categorized as Level 2 as management applied a discount to the shares due to a six month lock-up agreement post IPO. After the six month lock-up period, the common shares will be valued as Level 1 based on the publicly traded share prices. See “Fair Value Measurements of Financial Assets and Liabilities” section of Note 10 for additional information.

Fair Value Measurements

Fair Value Measurements	3 Months Ended
	Mar. 31, 2021
Fair Value Measurements	FAIR VALUE MEASUREMENTS The disclosures in this note apply to all Registrants except AEPTCo unless indicated otherwise. Fair Value Hierarchy and Valuation Techniques The accounting guidance for “Fair Value Measurements and Disclosures” establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). Where observable inputs are available for substantially the full term of the asset or liability, the instrument is categorized in Level 2. When quoted market prices are not available, pricing may be completed using comparable securities, dealer values, operating data and general market conditions to determine fair value. Valuation models utilize various inputs such as commodity, interest rate and, to a lesser degree, volatility and credit that include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, market corroborated inputs (i.e. inputs derived principally from, or correlated to, observable market data) and other observable inputs for the asset or liability. For commercial activities, exchange-traded derivatives, namely futures contracts, are generally fair valued based on unadjusted quoted prices in active markets and are classified as Level 1. Level 2 inputs primarily consist of OTC broker quotes in moderately active or less active markets, as well as exchange-traded derivatives where there is insufficient market liquidity to warrant inclusion in Level 1. Management verifies price curves using these broker quotes and classifies these fair values within Level 2 when substantially all of the fair value can be corroborated. Management typically obtains multiple broker quotes, which are nonbinding in nature but are based on recent trades in the marketplace. When multiple broker quotes are obtained, the quoted bid and ask prices are averaged. In certain circumstances, a broker quote may be discarded if it is a clear outlier. Management uses a historical correlation analysis between the broker quoted location and the illiquid locations. If the points are highly correlated, these locations are included within Level 2 as well. Certain OTC and bilaterally executed derivative instruments are executed in less active markets with a lower availability of pricing information. Illiquid transactions, complex structured transactions, FTRs and counterparty credit risk may require nonmarket-based inputs. Some of these inputs may be internally developed or extrapolated and utilized to estimate fair value. When such inputs have a significant impact on the measurement of fair value, the instrument is categorized as Level 3. The main driver of contracts being classified as Level 3 is the inability to substantiate energy price curves in the market. A portion of the Level 3 instruments have been economically hedged which limits potential earnings volatility. AEP utilizes its trustee’s external pricing service to estimate the fair value of the underlying investments held in the nuclear trusts. AEP’s investment managers review and validate the prices utilized by the trustee to determine fair value. AEP’s management performs its own valuation testing to verify the fair values of the securities. AEP receives audit reports of the trustee’s operating controls and valuation processes. Assets in the nuclear trusts, cash and cash equivalents, other temporary investments restricted cash for securitized funding are classified using the following methods. Equities are classified as Level 1 holdings if they are actively traded on exchanges. Items classified as Level 1 are investments in money market funds, fixed income and equity mutual funds and equity securities. They are valued based on observable inputs, primarily unadjusted quoted prices in active markets for identical assets. Items classified as Level 2 are primarily investments in individual fixed income securities. Fixed income securities generally do not trade on exchanges and do not have an official closing price but their valuation inputs are based on observable market data. Pricing vendors calculate bond valuations using financial models and matrices. The models use observable inputs including yields on benchmark securities, quotes by securities brokers, rating agency actions, discounts or premiums on securities compared to par prices, changes in yields for U.S. Treasury securities, corporate actions by bond issuers, prepayment schedules and histories, economic events and, for certain securities, adjustments to yields to reflect changes in the rate of inflation. Other securities with model-derived valuation inputs that are observable are also classified as Level 2 investments. Investments with unobservable valuation inputs are classified as Level 3 investments. Fair Value Measurements of Long-term Debt (Applies to all Registrants) The fair values of Long-term Debt are based on quoted market prices, without credit enhancements, for the same or similar issues and the current interest rates offered for instruments with similar maturities classified as Level 2 measurement inputs. These instruments are not marked-to-market. The estimates presented are not necessarily indicative of the amounts that could be realized in a current market exchange. The fair value of AEP’s Equity Units (Level 1) are valued based on publicly traded securities issued by AEP. The book values and fair values of Long-term Debt are summarized in the following table: March 31, 2021 December 31, 2020 Company Book Value Fair Value Book Value Fair Value (in millions) AEP (a) $ 32,345.0 $ 35,802.4 $ 31,072.5 $ 37,457.0 AEP Texas 4,810.2 5,235.6 4,820.4 5,682.6 AEPTCo 3,949.0 4,460.1 3,948.5 4,984.3 APCo 4,966.2 5,871.1 4,834.1 6,391.8 I&M 3,006.3 3,422.9 3,029.9 3,775.3 OPCo 2,876.3 3,316.1 2,430.2 3,154.9 PSO 1,623.8 1,842.4 1,373.8 1,732.1 SWEPCo 3,131.4 3,444.8 2,636.4 3,210.1 (a) The fair value amounts include debt related to AEP’s Equity Units and had a fair value of $1.6 billion and $1.7 billion as of March 31, 2021 and December 31, 2020, respectively. See “Equity Units” section of Note 12 for additional information. 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. The following is a summary of Other Temporary Investments: March 31, 2021 Gross Gross Unrealized Unrealized Fair Other Temporary Investments Cost Gains Losses Value (in millions) Restricted Cash and Other Cash Deposits (a) $ 74.6 $ — $ — $ 74.6 Fixed Income Securities – Mutual Funds (b) 116.7 2.0 — 118.7 Equity Securities – Mutual Funds 24.9 31.7 — 56.6 Total Other Temporary Investments $ 216.2 $ 33.7 $ — $ 249.9 December 31, 2020 Gross Gross Unrealized Unrealized Fair Other Temporary Investments Cost Gains Losses Value (in millions) Restricted Cash and Other Cash Deposits (a) $ 68.3 $ — $ — $ 68.3 Fixed Income Securities – Mutual Funds (b) 120.7 2.8 — 123.5 Equity Securities – Mutual Funds 25.9 28.7 — 54.6 Total Other Temporary Investments $ 214.9 $ 31.5 $ — $ 246.4 (a) Primarily represents amounts held for the repayment of debt. (b) Primarily short and intermediate maturities which may be sold and do not contain maturity dates. The following table provides the activity for fixed income and equity securities within Other Temporary Investments: Three Months Ended March 31, 2021 2020 (in millions) Proceeds from Investment Sales $ 5.5 $ 23.2 Purchases of Investments 0.7 6.7 Gross Realized Gains on Investment Sales 0.1 2.0 Gross Realized Losses on Investment Sales — 0.1 Fair Value Measurements of Trust Assets for Decommissioning and SNF Disposal (Applies to AEP and I&M) Nuclear decommissioning and SNF trust funds represent funds that regulatory commissions allow I&M to collect through rates to fund future decommissioning and SNF disposal liabilities. By rules or orders, the IURC, the MPSC and the FERC established investment limitations and general risk management guidelines. In general, limitations include: • Acceptable investments (rated investment grade or above when purchased). • Maximum percentage invested in a specific type of investment. • Prohibition of investment in obligations of AEP, I&M or their affiliates. • Withdrawals permitted only for payment of decommissioning costs and trust expenses. I&M maintains trust funds for each regulatory jurisdiction. Regulatory approval is required to withdraw decommissioning funds. These funds are managed by an external investment manager that must comply with the guidelines and rules of the applicable regulatory authorities. The trust assets are invested to optimize the net of tax earnings of the trust giving consideration to liquidity, risk, diversification and other prudent investment objectives. I&M records securities held in these trust funds in Spent Nuclear Fuel and Decommissioning Trusts on its balance sheets. I&M records these securities at fair value. I&M classifies debt securities in the trust funds as available-for-sale due to their long-term purpose. Other-than-temporary impairments for investments in debt securities are considered realized losses as a result of securities being managed by an external investment management firm. The external investment management firm makes specific investment decisions regarding the debt and equity investments held in these trusts and generally intends to sell debt securities in an unrealized loss position as part of a tax optimization strategy. Impairments reduce the cost basis of the securities which will affect any future unrealized gain or realized gain or loss due to the adjusted cost of investment. I&M records unrealized gains, unrealized losses and other-than-temporary impairments from securities in these trust funds as adjustments to the regulatory liability account for the nuclear decommissioning trust funds and to regulatory assets or liabilities for the SNF disposal trust funds in accordance with their treatment in rates. Consequently, changes in fair value of trust assets do not affect earnings or AOCI. The following is a summary of nuclear trust fund investments: March 31, 2021 December 31, 2020 Gross Other-Than- Gross Other-Than- Fair Unrealized Temporary Fair Unrealized Temporary Value Gains Impairments Value Gains Impairments (in millions) Cash and Cash Equivalents $ 47.7 $ — $ — $ 25.8 $ — $ — Fixed Income Securities: United States Government 998.9 54.8 (13.0) 1,025.6 98.5 (7.1) Corporate Debt 76.4 4.8 (2.6) 86.3 9.6 (1.7) State and Local Government 83.8 0.4 (0.7) 114.3 0.9 (0.4) Subtotal Fixed Income Securities 1,159.1 60.0 (16.3) 1,226.2 109.0 (9.2) Equity Securities - Domestic (a) 2,207.5 1,543.5 — 2,054.7 1,400.8 — Spent Nuclear Fuel and Decommissioning Trusts $ 3,414.3 $ 1,603.5 $ (16.3) $ 3,306.7 $ 1,509.8 $ (9.2) (a) Amount reported as Gross Unrealized Gains includes unrealized gains of $1.5 billion and $1.4 billion and unrealized losses of $5 million and $9 million as of March 31, 2021 and December 31, 2020, respectively. The following table provides the securities activity within the decommissioning and SNF trusts: Three Months Ended March 31, 2021 2020 (in millions) Proceeds from Investment Sales $ 320.0 $ 612.4 Purchases of Investments 336.9 626.0 Gross Realized Gains on Investment Sales 5.4 10.9 Gross Realized Losses on Investment Sales 4.2 17.0 The base cost of fixed income securities was $1.1 billion and $1.1 billion as of March 31, 2021 and December 31, 2020, respectively. The base cost of equity securities was $664 million and $654 million as of March 31, 2021 and December 31, 2020, respectively. The fair value of fixed income securities held in the nuclear trust funds, summarized by contractual maturities, as of March 31, 2021 was as follows: Fair Value of Fixed Income Securities (in millions) Within 1 year $ 320.5 After 1 year through 5 years 334.7 After 5 years through 10 years 233.6 After 10 years 270.3 Total $ 1,159.1 Fair Value Measurements of Financial Assets and Liabilities The following tables set forth, by level within the fair value hierarchy, the Registrants’ financial assets and liabilities that were accounted for at fair value on a recurring basis. As required by the accounting guidance for “Fair Value Measurements and Disclosures,” financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. Management’s assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. There have not been any significant changes in management’s valuation techniques. AEP Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments Restricted Cash and Other Cash Deposits (a) $ 62.9 $ — $ — $ 11.7 $ 74.6 Fixed Income Securities – Mutual Funds 118.7 — — — 118.7 Equity Securities – Mutual Funds (b) 56.6 — — — 56.6 Total Other Temporary Investments 238.2 — — 11.7 249.9 Risk Management Assets Risk Management Commodity Contracts (c) (d) 1.2 217.9 194.8 (94.8) 319.1 Cash Flow Hedges: Commodity Hedges (c) — 44.4 2.7 (32.0) 15.1 Fair Value Hedges — 2.7 — — 2.7 Total Risk Management Assets 1.2 265.0 197.5 (126.8) 336.9 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 39.5 — — 8.2 47.7 Fixed Income Securities: United States Government — 998.9 — — 998.9 Corporate Debt — 76.4 — — 76.4 State and Local Government — 83.8 — — 83.8 Subtotal Fixed Income Securities — 1,159.1 — — 1,159.1 Equity Securities – Domestic (b) 2,207.5 — — — 2,207.5 Total Spent Nuclear Fuel and Decommissioning Trusts 2,247.0 1,159.1 — 8.2 3,414.3 Other Investments (h) — 56.7 — — 56.7 Total Assets $ 2,486.4 $ 1,480.8 $ 197.5 $ (106.9) $ 4,057.8 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (d) $ 0.8 $ 182.7 $ 152.8 $ (99.5) $ 236.8 Cash Flow Hedges: Commodity Hedges (c) — 67.0 2.9 (32.0) 37.9 Fair Value Hedges — 37.4 — — 37.4 Total Risk Management Liabilities $ 0.8 $ 287.1 $ 155.7 $ (131.5) $ 312.1 AEP Assets and Liabilities Measured at Fair Value on a Recurring Basis December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments Restricted Cash and Other Cash Deposits (a) $ 57.8 $ — $ — $ 10.5 $ 68.3 Fixed Income Securities – Mutual Funds 123.5 — — — 123.5 Equity Securities – Mutual Funds (b) 54.6 — — — 54.6 Total Other Temporary Investments 235.9 — — 10.5 246.4 Risk Management Assets Risk Management Commodity Contracts (c) (f) 0.9 258.8 252.4 (190.0) 322.1 Cash Flow Hedges: Commodity Hedges (c) — 34.4 3.9 (28.5) 9.8 Interest Rate Hedges — 2.4 — — 2.4 Fair Value Hedges — 2.6 — — 2.6 Total Risk Management Assets 0.9 298.2 256.3 (218.5) 336.9 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 16.8 — — 9.0 25.8 Fixed Income Securities: United States Government — 1,025.6 — — 1,025.6 Corporate Debt — 86.3 — — 86.3 State and Local Government — 114.3 — — 114.3 Subtotal Fixed Income Securities — 1,226.2 — — 1,226.2 Equity Securities – Domestic (b) 2,054.7 — — — 2,054.7 Total Spent Nuclear Fuel and Decommissioning Trusts 2,071.5 1,226.2 — 9.0 3,306.7 Other Investments (h) — — 31.8 — 31.8 Total Assets $ 2,308.3 $ 1,524.4 $ 288.1 $ (199.0) $ 3,921.8 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (f) $ 0.9 $ 244.2 $ 167.2 $ (193.4) $ 218.9 Cash Flow Hedges: Commodity Hedges (c) — 106.1 7.6 (28.5) 85.2 Interest Rate Hedges — 3.4 — — 3.4 Fair Value Hedges — 4.1 — — 4.1 Total Risk Management Liabilities $ 0.9 $ 357.8 $ 174.8 $ (221.9) $ 311.6 AEP Texas Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 39.3 $ — $ — $ — $ 39.3 Risk Management Assets Risk Management Commodity Contracts (c) — 0.8 — (0.8) — Total Assets $ 39.3 $ 0.8 $ — $ (0.8) $ 39.3 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 28.7 $ — $ — $ — $ 28.7 Risk Management Assets Risk Management Commodity Contracts (c) — 0.4 — (0.4) — Total Assets $ 28.7 $ 0.4 $ — $ (0.4) $ 28.7 APCo Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 11.6 $ — $ — $ — $ 11.6 Risk Management Assets Risk Management Commodity Contracts (c) (g) — 9.8 7.1 (10.0) 6.9 Total Assets $ 11.6 $ 9.8 $ 7.1 $ (10.0) $ 18.5 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 9.2 $ 0.5 $ (9.5) $ 0.2 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 16.9 $ — $ — $ — $ 16.9 Risk Management Assets Risk Management Commodity Contracts (c) (g) — 19.4 19.9 (19.2) 20.1 Cash Flow Hedges: Interest Rate Hedges — 2.4 — — 2.4 Total Risk Management Assets — 21.8 19.9 (19.2) 22.5 Total Assets $ 16.9 $ 21.8 $ 19.9 $ (19.2) $ 39.4 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 19.5 $ 0.6 $ (18.8) $ 1.3 Cash Flow Hedges: Interest Rate Hedges — 3.4 — — 3.4 Total Risk Management Liabilities $ — $ 22.9 $ 0.6 $ (18.8) $ 4.7 I&M Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 6.0 $ 1.1 $ (6.2) $ 0.9 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 39.5 — — 8.2 47.7 Fixed Income Securities: United States Government — 998.9 — — 998.9 Corporate Debt — 76.4 — — 76.4 State and Local Government — 83.8 — — 83.8 Subtotal Fixed Income Securities — 1,159.1 — — 1,159.1 Equity Securities - Domestic (b) 2,207.5 — — — 2,207.5 Total Spent Nuclear Fuel and Decommissioning Trusts 2,247.0 1,159.1 — 8.2 3,414.3 Total Assets $ 2,247.0 $ 1,165.1 $ 1.1 $ 2.0 $ 3,415.2 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 6.1 $ 0.4 $ (6.3) $ 0.2 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 15.1 $ 2.5 $ (13.9) $ 3.7 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 16.8 — — 9.0 25.8 Fixed Income Securities: United States Government — 1,025.6 — — 1,025.6 Corporate Debt — 86.3 — — 86.3 State and Local Government — 114.3 — — 114.3 Subtotal Fixed Income Securities — 1,226.2 — — 1,226.2 Equity Securities - Domestic (b) 2,054.7 — — — 2,054.7 Total Spent Nuclear Fuel and Decommissioning Trusts 2,071.5 1,226.2 — 9.0 3,306.7 Total Assets $ 2,071.5 $ 1,241.3 $ 2.5 $ (4.9) $ 3,310.4 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 12.0 $ 0.4 $ (12.2) $ 0.2 OPCo Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.6 $ — $ (0.6) $ — Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 104.0 $ — $ 104.0 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.3 $ — $ (0.3) $ — Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 110.3 $ — $ 110.3 PSO Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.3 $ 5.5 $ (0.3) $ 5.5 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.2 $ 10.3 $ (0.2) $ 10.3 SWEPCo Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.3 $ 1.4 $ (0.4) $ 1.3 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 0.9 $ — $ 0.9 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.1 $ 3.3 $ (0.2) $ 3.2 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 1.7 $ — $ 1.7 (a) Amounts in “Other’’ column primarily represent cash deposits in bank accounts with financial institutions or third-parties. Level 1 and Level 2 amounts primarily represent investments in money market funds. (b) Amounts represent publicly traded equity securities and equity-based mutual funds. (c) Amounts in “Other’’ column primarily represent counterparty netting of risk management and hedging contracts and associated cash collateral under the accounting guidance for “Derivatives and Hedging.’’ (d) The March 31, 2021 maturity of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 2 matures $(3) million in 2021, $11 million in periods 2022-2024, $17 million in periods 2025-2026 and $10 million in periods 2027-2033; Level 3 matures $23 million in 2021, $32 million in periods 2022-2024, $8 million in periods 2025-2026 and $(21) million in periods 2027-2033. Risk management commodity contracts are substantially comprised of power contracts. (e) Amounts in “Other’’ column primarily represent accrued interest receivables from financial institutions. Level 1 amounts primarily represent investments in money market funds. (f) The December 31, 2020 maturity of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 2 matures $3 million in periods 2022-2024, $11 million in periods 2025-2026 and $1 million in periods 2027-2033; Level 3 matures $47 million in 2021, $37 million in periods 2022-2024, $14 million in periods 2025-2026 and $(13) million in periods 2027-2033. Risk management commodity contracts are substantially comprised of power contracts. (g) Substantially comprised of power contracts for the Registrant Subsidiaries. (h) See “Warrants Held in Investee” section of Note 9 for additional information. The following tables set forth a reconciliation of changes in the fair value of net trading derivatives classified as Level 3 in the fair value hierarchy: Three Months Ended March 31, 2021 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of December 31, 2020 $ 113.3 $ 19.3 $ 2.1 $ (110.3) $ 10.3 $ 1.6 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 19.8 2.1 0.3 — 9.3 6.1 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (21.3) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 3.1 — — — — — Settlements (47.9) (15.6) (1.4) 2.7 (16.3) (8.2) Transfers into Level 3 (d) (e) 0.5 — — — — — Transfers out of Level 3 (e) (33.0) — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 7.3 0.8 (0.3) 3.6 2.2 1.0 Balance as of March 31, 2021 $ 41.8 $ 6.6 $ 0.7 $ (104.0) $ 5.5 $ 0.5 Three Months Ended March 31, 2020 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of December 31, 2019 $ 109.9 $ 37.7 $ 5.8 $ (103.6) $ 15.8 $ 1.4 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 0.9 (9.2) 0.2 (0.3) 8.0 1.9 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) 10.9 — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) (4.1) — — — — — Settlements (59.2) (21.9) (4.0) 2.5 (17.7) (5.3) Transfers into Level 3 (d) (e) (0.5) — — — — — Transfers out of Level 3 (e) 5.3 0.7 0.4 — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) (20.7) (0.7) (0.3) (19.5) 0.2 (0.5) Balance as of March 31, 2020 $ 42.5 $ 6.6 $ 2.1 $ (120.9) $ 6.3 $ (2.5) (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 net gains (losses) are recorded as regulatory assets/liabilities or accounts payable. The following tables quantify the significant unobservable inputs used in developing the fair value of Level 3 positions: AEP Significant Unobservable Inputs March 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (in millions) Energy Contracts $ 178.5 $ 151.7 Discounted Cash Flow Forward Market Price (a) (c) $ 0.10 $ 98.66 $ 28.85 Natural Gas Contracts — 0.9 Discounted Cash Flow Forward Market Price (b) (c) 2.24 2.92 2.50 FTRs 19.0 3.1 Discounted Cash Flow Forward Market Price (a) (c) (13.61) 9.08 0.02 Total $ 197.5 $ 155.7 December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (in millions) Energy Contracts $ 213.5 $ 169.7 Discounted Cash Flow Forward Market Price (a) (c) $ 5.33 $ 100.47 $ 32.73 Natural Gas Contracts — 1.7 Discounted Cash Flow Forward Market Price (b) (c) 2.18 2.77 2.40 FTRs 42.8 3.4 Discounted Cash Flow Forward Market Price (a) (c) (15.08) 9.66 0.19 Other Investments 31.8 — Black-Scholes Model Liquidity Adjustment (d) 10 % 20 % 15 % Total $ 288.1 $ 174.8 APCo Significant Unobservable Inputs March 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ 0.4 $ 0.5 Discounted Cash Flow Forward Market Price $ 10.92 $ 44.29 $ 25.13 FTRs 6.7 — Discounted Cash Flow Forward Market Price 0.08 4.99 0.99 Total $ 7.1 $ 0.5 December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ 1.0 $ 0.6 Discounted Cash Flow Forward Market Price $ 10.84 $ 41.09 $ 25.08 FTRs 18.9 — Discounted Cash Flow Forward Market Price 0.04 5.61 1.13 Total $ 19.9 $ 0.6 I&M Significant Unobservable Inputs March 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ 0.3 $ 0.3 Discounted Cash Flow Forward Market Price $ 10.92 $ 44.29 $ 25.13 FTRs 0.8 0.1 Discounted Cash Flow Forward Market Price (2.29) 3.66 0.33 Total $ 1.1 $ 0.4 December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ 0.6 $ 0.3 Discounted Cash Flow Forward Market Price $ 10.84 $ 41.09 $ 25.08 FTRs 1.9 0.1 Discounted Cash Flow Forward Market Price (1.96) 3.69 0.33 Total $ 2.5 $ 0.4 OPCo Significant Unobservable Inputs March 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ — $ 104.0 Discounted Cash Flow Forward Market Price $ 15.08 $ 49.09 $ 27.79 December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ — $ 110.3 Discounted Cash Flow Forward Market Price $ 16.19 $ 46.98 $ 28.30 PSO Significant Unobservable Inputs March 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) FTRs $ 5.5 $ — Discounted Cash Flow Forward Market Price $ (13.61) $ 2.04 $ (3.01) December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) FTRs $ 10.3 $ — Discounted Cash Flow Forward Market Price $ (6.93) $ 0.48 $ (1.93) SWEPCo Significant Unobservable Inputs March 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (c) (in millions) Natural Gas Contracts $ — $ 0.9 Discounted Cash Flow Forward Market Price (b) $ 2.24 $ 2.92 $ 2.50 FTRs 1.4 — Discounted Cash Flow Forward Market Price (a) (13.61) 2.04 (3.01) Total $ 1.4 $ 0.9 December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (c) (in millions) Natural Gas Contracts $ — $ 1.7 Discounted Cash Flow Forward Market Price (b) $ 2.18 $ 2.77 $ 2.41 FTRs 3.3 — Discounted Cash Flow Forward Market Price (a) (6.93) 0.48 (1.93) Total $ 3.3 $ 1.7 (a) Represents market prices in dollars per MWh. (b) Represents market prices in dollars per MMBtu. (c) The weighted average is the product of the forward market price of the underlying commodity and volume weighted by term. (d) Represents percentage discount applied to the publically available share price. 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 March 31, 2021 and December 31, 2020: 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) Liquidity Adjustment Buy Increase (Decrease) Lower (Higher)

Income Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2021
Income Taxes	INCOME TAXES The disclosures in this note apply to all Registrants unless indicated otherwise. Effective Tax Rates (ETR) The Registrants’ interim ETR reflect the estimated annual ETR for 2021 and 2020, adjusted for tax expense associated with certain discrete items. The Registrants include the amortization of Excess ADIT not subject to normalization requirements in the annual estimated ETR when regulatory proceedings instruct the Registrants to provide the benefits of Tax Reform to customers over multiple interim periods. Certain regulatory proceedings instruct the Registrants to provide the benefits of Tax Reform to customers in a single period (e.g. by applying the Excess ADIT not subject to normalization requirements against an existing regulatory asset balance) and in these circumstances, the Registrants recognize the tax benefit discretely in the period recorded. The annual amount of Excess ADIT approved by the Registrant’s regulatory commissions may not impact the ETR ratably during each interim period due to the variability of pretax book income between interim periods and the application of an annual estimated ETR. The ETR for each of the Registrants are included in the following tables: Three Months Ended March 31, 2021 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo U.S. Federal Statutory Rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % Increase (decrease) due to: State Income Tax, net of Federal Benefit 2.3 % 1.4 % 2.7 % 3.2 % 1.3 % 0.7 % 4.7 % (0.8) % Tax Reform Excess ADIT Reversal (9.2) % (7.8) % 0.3 % (18.0) % (17.9) % (9.7) % (24.7) % (5.9) % Production and Investment Tax Credits (5.5) % (0.3) % — % — % (1.7) % — % (8.2) % (5.1) % Flow Through 0.3 % 0.3 % 0.2 % 1.6 % (1.0) % 1.1 % 0.6 % (0.7) % AFUDC Equity (0.9) % (1.4) % (1.7) % (1.1) % (0.2) % (1.1) % (0.5) % (0.4) % Parent Company Loss Benefit — % — % (1.9) % (2.9) % (2.5) % — % — % — % Discrete Tax Adjustments 0.5 % — % — % — % — % (4.0) % — % — % Other 0.1 % 0.1 % 0.1 % 0.1 % — % 0.2 % (0.9) % 0.1 % Effective Income Tax Rate 8.6 % 13.3 % 20.7 % 3.9 % (1.0) % 8.2 % (8.0) % 8.2 % Three Months Ended March 31, 2020 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo U.S. Federal Statutory Rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % Increase (decrease) due to: State Income Tax, net of Federal Benefit 2.5 % 1.5 % 2.9 % 3.0 % 3.2 % 0.7 % 4.6 % 2.7 % Tax Reform Excess ADIT Reversal (9.4) % (6.2) % 0.4 % (13.0) % (19.6) % (10.2) % (23.1) % (94.7) % Production and Investment Tax Credits (4.3) % (0.4) % — % — % (1.9) % — % (1.3) % (0.5) % Flow Through 0.5 % 0.1 % 0.5 % 1.5 % 0.2 % 1.0 % 0.6 % (1.0) % AFUDC Equity (1.4) % (2.6) % (2.6) % (1.0) % (1.1) % (1.0) % (0.7) % (0.4) % Parent Company Loss Benefit — % (0.2) % (0.9) % (3.3) % (3.9) % (0.1) % (2.2) % (2.4) % Discrete Tax Adjustments — % — % — % — % 2.7 % — % — % — % Other (0.4) % 0.3 % — % 0.1 % (0.2) % — % 0.1 % 7.2 % Effective Income Tax Rate 8.5 % 13.5 % 21.3 % 8.3 % 0.4 % 11.4 % (1.0) % (68.1) % Federal and State Income Tax Audit Status The statute of limitations for the IRS to examine AEP and subsidiaries originally filed federal return has expired for tax years 2016 and earlier. In the third quarter of 2019, AEP and subsidiaries elected to amend the 2014 and 2015 federal returns. In the first quarter of 2020, the IRS notified AEP that it was beginning an examination of these amended returns, including the net operating losses (NOL) carryback to 2015 that originated in the 2017 return. As of March 31, 2021, the IRS has not challenged any items on these returns and the IRS is limited in their proposed adjustments to the amount AEP claimed on the amended returns. Federal Legislation In March 2020, the CARES Act was signed into law. The CARES Act includes tax relief provisions including a 5-year NOL carryback from years 2018-2020. In the third quarter of 2020, AEP requested a $95 million refund of taxes paid in 2014 under the 5-year NOL carryback provision of the CARES Act. AEP carried back a NOL generated on the 2019 Federal income tax return at a 21% federal corporate income tax rate to the 2014 Federal income tax return at a 35% corporate income tax rate. As a result of the change in the corporate income tax rates between the two periods, AEP realized a tax benefit of $48 million primarily at the Generation & Marketing segment in 2020. Management expects to receive the $95 million refund in the second quarter of 2021.

Financing Activities

Financing Activities	3 Months Ended
	Mar. 31, 2021
Financing Activities	FINANCING ACTIVITIES The disclosures in this note apply to all Registrants, unless indicated otherwise. Common Stock (Applies to AEP) At-the-Market (ATM) Program In 2020, AEP filed a prospectus supplement and executed an Equity Distribution Agreement, pursuant to which AEP may sell, from time to time, up to an aggregate of $1 billion of its common stock through an ATM offering program, including an equity forward sales component. The compensation paid to the selling agents by AEP may be up to 2% of the gross offering proceeds of the shares. In the first quarter of 2021, AEP issued 1,917,140 shares of common stock and received net cash proceeds of $158 million under the ATM program . In April 2021, AEP issued an additional 438,165 shares of common stock and received net cash proceeds of $37 million. Long-term Debt Outstanding (Applies to AEP) The following table details long-term debt outstanding, net of issuance costs and premiums or discounts: Type of Debt March 31, 2021 December 31, 2020 (in millions) Senior Unsecured Notes $ 25,919.8 $ 25,116.1 Pollution Control Bonds 1,937.0 1,936.7 Notes Payable 213.9 239.1 Securitization Bonds 693.0 716.4 Spent Nuclear Fuel Obligation (a) 281.2 281.2 Junior Subordinated Notes (b) 1,626.0 1,624.1 Other Long-term Debt 1,674.1 1,158.9 Total Long-term Debt Outstanding 32,345.0 31,072.5 Long-term Debt Due Within One Year 2,130.2 2,086.1 Long-term Debt $ 30,214.8 $ 28,986.4 (a) Pursuant to the Nuclear Waste Policy Act of 1982, I&M, a nuclear licensee, has an obligation to the United States Department of Energy for SNF disposal. The obligation includes a one-time fee for nuclear fuel consumed prior to April 7, 1983. Trust fund assets related to this obligation were $326 million and $324 million as of March 31, 2021 and December 31, 2020, respectively, and are included in Spent Nuclear Fuel and Decommissioning Trusts on the balance sheets. (b) See “Equity Units” section below for additional information. Long-term Debt Activity Long-term debt and other securities issued, retired and principal payments made during the first three months of 2021 are shown in the following tables: Principal Interest Company Type of Debt Amount (a) Rate Due Date Issuances: (in millions) (%) APCo Senior Unsecured Notes $ 500.0 2.70 2031 OPCo Senior Unsecured Notes 450.0 1.63 2031 PSO Other Long-term Debt 500.0 Variable 2022 SWEPCo Senior Unsecured Notes 500.0 1.65 2026 Non-Registrant: Transource Energy Other Long-term Debt 14.6 Variable 2023 Total Issuances $ 1,964.6 (a) Amounts indicated on the statements of cash flows are net of issuance costs and premium or discount and will not tie to the issuance amounts. Principal Interest Company Type of Debt Amount Paid Rate Due Date Retirements and Principal Payments: (in millions) (%) AEP Texas Securitization Bonds $ 11.2 2.06 2025 APCo Senior Unsecured Notes 350.0 4.60 2021 APCo Securitization Bonds 12.5 2.01 2023 I&M Notes Payable 1.5 Variable 2021 I&M Notes Payable 1.5 Variable 2022 I&M Notes Payable 3.4 Variable 2022 I&M Notes Payable 4.8 Variable 2023 I&M Notes Payable 5.9 Variable 2024 I&M Notes Payable 6.5 Variable 2025 I&M Other Long-term Debt 0.5 6.00 2025 PSO Senior Unsecured Notes 250.0 4.40 2021 PSO Other Long-term Debt 0.1 3.00 2027 SWEPCo Notes Payable 1.6 4.58 2032 Non-Registrant: Transource Energy Senior Unsecured Notes 1.2 2.75 2050 Total Retirements and Principal Payments $ 650.7 Long-term Debt Subsequent Events In April 2021, APCo retired $18 million of Pollution Control Bonds. In April 2021, I&M retired $6 million of Notes Payable related to DCC Fuel. Equity Units (Applies to AEP) 2020 Equity Units In August 2020, AEP issued 17 million Equity Units initially in the form of corporate units, at a stated amount of $50 per unit, for a total stated amount of $850 million. Net proceeds from the issuance were approximately $833 million. The proceeds were used to support AEP’s overall capital expenditure plans. Each corporate unit represents a 1/20 undivided beneficial ownership interest in $1,000 principal amount of AEP’s 1.30% Junior Subordinated Notes (notes) due in 2025 and a forward equity purchase contract which settles after three years in 2023. The notes are expected to be remarketed in 2023, at which time the interest rate will reset at the then current market rate. Investors may choose to remarket their notes to receive the remarketing proceeds and use those funds to settle the forward equity purchase contract, or accept the remarketed debt and use other funds for the equity purchase. If the remarketing is unsuccessful, investors have the right to put their notes to AEP at a price equal to the principal. The Equity Units carry an annual distribution rate of 6.125%, which is comprised of a quarterly coupon rate of interest of 1.30% and a quarterly forward equity purchase contract payment of 4.825%. Each forward equity purchase contract obligates the holder to purchase, and AEP to sell, for $50 a number of shares in common stock in accordance with the conversion ratios set forth below (subject to an anti-dilution adjustment): • If the AEP common stock market price is equal to or greater than $99.95: 0.5003 shares per contract. • If the AEP common stock market price is less than $99.95 but greater than $83.29: a number of shares per contract equal to $50 divided by the applicable market price. The holder receives a variable number of shares at $50. • If the AEP common stock market price is less than or equal to $83.29: 0.6003 shares per contract. A holder’s ownership interest in the notes is pledged to AEP to secure the holder’s obligation under the related forward equity purchase contract. If a holder of the forward equity purchase contract chooses at any time to no longer be a holder of the notes, such holder’s obligation under the forward equity purchase contract must be secured by a U.S. Treasury security which must be equal to the aggregate principal amount of the notes. At the time of issuance, the $850 million of notes were recorded within Long-term Debt on the balance sheets. The present value of the purchase contract payments of $121 million were recorded in Deferred Credits and Other Noncurrent Liabilities with a current portion in Other Current Liabilities at the time of issuance, representing the obligation to make forward equity contract payments, with an offsetting reduction to Paid-in Capital. The difference between the face value and present value of the purchase contract payments will be accreted to Interest Expense on the statements of income over the three year period ending in 2023. The liability recorded for the contract payments is considered non-cash and excluded from the statements of cash flows. Until settlement of the forward equity purchase contract, earnings per share dilution resulting from the equity unit issuance will be determined under the treasury stock method. The maximum amount of shares AEP will be required to issue to settle the purchase contract is 10,205,100 shares (subject to an anti-dilution adjustment). 2019 Equity Units In March 2019, AEP issued 16.1 million Equity Units initially in the form of corporate units, at a stated amount of $50 per unit, for a total stated amount of $805 million. Net proceeds from the issuance were approximately $785 million. The proceeds were used to support AEP’s overall capital expenditure plans including the acquisition of Sempra Renewables LLC. Each corporate unit represents a 1/20 undivided beneficial ownership interest in $1,000 principal amount of AEP’s 3.40% Junior Subordinated Notes (notes) due in 2024 and a forward equity purchase contract which settles after three years in 2022. The notes are expected to be remarketed in 2022, at which time the interest rate will reset at the then current market rate. Investors may choose to remarket their notes to receive the remarketing proceeds and use those funds to settle the forward equity purchase contract, or accept the remarketed debt and use other funds for the equity purchase. If the remarketing is unsuccessful, investors have the right to put their notes to AEP at a price equal to the principal. The Equity Units carry an annual distribution rate of 6.125%, which is comprised of a quarterly coupon rate of interest of 3.40% and a quarterly forward equity purchase contract payment of 2.725%. Each forward equity purchase contract obligates the holder to purchase, and AEP to sell, for $50 a number of shares in common stock in accordance with the conversion ratios set forth below (subject to an anti-dilution adjustment): • If the AEP common stock market price is equal to or greater than $99.58: 0.5021 shares per contract. • If the AEP common stock market price is less than $99.58 but greater than $82.98: a number of shares per contract equal to $50 divided by the applicable market price. The holder receives a variable number of shares at $50. • If the AEP common stock market price is less than or equal to $82.98: 0.6026 shares per contract. A holder’s ownership interest in the notes is pledged to AEP to secure the holder’s obligation under the related forward equity purchase contract. If a holder of the forward equity purchase contract chooses at any time to no longer be a holder of the notes, such holder’s obligation under the forward equity purchase contract must be secured by a U.S. Treasury security which must be equal to the aggregate principal amount of the notes. At the time of issuance, the $805 million of notes were recorded within Long-term Debt on the balance sheets. The present value of the purchase contract payments of $62 million were recorded in Deferred Credits and Other Noncurrent Liabilities with a current portion in Other Current Liabilities at the time of issuance, representing the obligation to make forward equity contract payments, with an offsetting reduction to Paid-in Capital. The difference between the face value and present value of the purchase contract payments will be accreted to Interest Expense on the statements of income over the three year period ending in 2022. The liability recorded for the contract payments is considered non-cash and excluded from the statements of cash flows. Until settlement of the forward equity purchase contract, earnings per share dilution resulting from the equity unit issuance will be determined under the treasury stock method. The maximum amount of shares AEP will be required to issue to settle the purchase contract is 9,701,860 shares (subject to an anti-dilution adjustment). Debt Covenants (Applies to AEP and AEPTCo) Covenants in AEPTCo’s note purchase agreements and indenture limit the amount of contractually-defined priority debt (which includes a further sub-limit of $50 million of secured debt) to 10% of consolidated tangible net assets. AEPTCo’s contractually-defined priority debt was 2.5% of consolidated tangible net assets as of March 31, 2021. The method for calculating the consolidated tangible net assets is contractually-defined in the note purchase agreements. Dividend Restrictions Utility Subsidiaries’ Restrictions Parent depends on its utility subsidiaries to pay dividends to shareholders. AEP utility subsidiaries pay dividends to Parent provided funds are legally available. Various financing arrangements and regulatory requirements may impose certain restrictions on the ability of the subsidiaries to transfer funds to Parent in the form of dividends. All of the dividends declared by AEP’s utility subsidiaries that provide transmission or local distribution services are subject to a Federal Power Act restriction that prohibits the payment of dividends out of capital accounts without regulatory approval; payment of dividends is allowed out of retained earnings only. 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 AGR, APCo and I&M. Certain AEP subsidiaries have credit agreements that contain covenants that limit their debt to capitalization ratio to 67.5%. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. The Federal Power Act restriction does not limit the ability of the AEP subsidiaries to pay dividends out of retained earnings. Parent Restrictions (Applies to AEP) The holders of AEP’s common stock are entitled to receive the dividends declared by the Board of Directors provided funds are legally available for such dividends. Parent’s income primarily derives from common stock equity in the earnings of its utility subsidiaries. Pursuant to the leverage restrictions in credit agreements, AEP must maintain a percentage of debt to total capitalization at a level that does not exceed 67.5%. The method for calculating outstanding debt and capitalization is contractually-defined in the credit agreements. Corporate Borrowing Program - AEP System (Applies to all Registrant Subsidiaries) The AEP System uses a corporate borrowing program to meet the short-term borrowing needs of AEP’s subsidiaries. The corporate borrowing program includes a Utility Money Pool, which funds AEP’s utility subsidiaries; a Nonutility Money Pool, which funds certain AEP nonutility subsidiaries; and direct borrowing from AEP. The AEP System Utility Money Pool operates in accordance with the terms and conditions of its agreement filed with the FERC. The amounts of outstanding loans to (borrowings from) the Utility Money Pool as of March 31, 2021 and December 31, 2020 are included in Advances to Affiliates and Advances from Affiliates, respectively, on the Registrant Subsidiaries’ balance sheets. The Utility Money Pool participants’ activity and corresponding authorized borrowing limits for the three months ended March 31, 2021 are described in the following table: Maximum Average Net Loans to Borrowings Maximum Borrowings Average (Borrowings) from Authorized from the Loans to the from the Loans to the the Utility Money Short-term Utility Utility Utility Utility Pool as of Borrowing Company Money Pool Money Pool Money Pool Money Pool March 31, 2021 Limit (in millions) AEP Texas $ 295.5 $ — $ 197.8 $ — $ (284.0) $ 500.0 AEPTCo 330.6 3.5 230.1 1.6 (227.8) 820.0 (a) APCo 27.8 616.9 13.2 152.4 261.1 500.0 I&M 166.5 13.3 118.2 13.3 (111.3) 500.0 OPCo 259.2 222.4 175.1 107.4 0.5 500.0 PSO 262.0 210.1 130.3 122.0 (245.7) 300.0 SWEPCo 280.3 156.4 169.3 142.0 (86.9) 350.0 (a) Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions. The activity in the above table does not include short-term lending activity of certain AEP nonutility subsidiaries. AEP Texas’ wholly-owned subsidiary, AEP Texas North Generation Company, LLC and SWEPCo’s wholly-owned subsidiary, Mutual Energy SWEPCo, LLC participate in the Nonutility Money Pool. The amounts of outstanding loans to the Nonutility Money Pool as of March 31, 2021 and December 31, 2020 are included in Advances to Affiliates on the subsidiaries’ balance sheets. The Nonutility Money Pool participants’ activity for the three months ended March 31, 2021 is described in the following table: Maximum Loans Average Loans Loans to the Nonutility to the Nonutility to the Nonutility Money Pool as of Company Money Pool Money Pool March 31, 2021 (in millions) AEP Texas $ 7.1 $ 6.9 $ 6.8 SWEPCo 2.1 2.1 2.1 AEP has a direct financing relationship with AEPTCo to meet its short-term borrowing needs. The amounts of outstanding loans to and borrowings from AEP as of March 31, 2021 and December 31, 2020 are included in Advances to Affiliates and Advances from Affiliates, respectively, on AEPTCo’s balance sheets. AEPTCo’s direct borrowing and lending activity with AEP and corresponding authorized borrowing limit for the three months ended March 31, 2021 are described in the following table: Maximum Maximum Average Average Borrowings from Loans to Authorized Borrowings Loans Borrowings Loans AEP as of AEP as of Short-term from AEP to AEP from AEP to AEP March 31, 2021 March 31, 2021 Borrowing Limit (in millions) $ 1.2 $ 220.6 $ 1.2 $ 148.7 $ 1.2 $ 105.8 $ 50.0 (a) (a) Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions. The maximum and minimum interest rates for funds either borrowed from or loaned to the Utility Money Pool are summarized in the following table: Three Months Ended March 31, 2021 2020 Maximum Interest Rate 0.40 % 2.24 % Minimum Interest Rate 0.25 % 1.76 % The average interest rates for funds borrowed from and loaned to the Utility Money Pool are summarized for all Registrant Subsidiaries in the following table: Average Interest Rate for Funds Average Interest Rate for Funds Borrowed from the Utility Money Pool Loaned to the Utility Money Pool for Three Months Ended March 31, for Three Months Ended March 31, Company 2021 2020 2021 2020 AEP Texas 0.31 % 2.05 % — % 1.97 % AEPTCo 0.31 % 1.95 % 0.28 % 1.91 % APCo 0.28 % 1.95 % 0.36 % 1.94 % I&M 0.31 % 1.95 % 0.30 % 1.94 % OPCo 0.29 % 1.90 % 0.29 % 2.06 % PSO 0.33 % 2.00 % 0.28 % 1.95 % SWEPCo 0.28 % 1.95 % 0.38 % — % Maximum, minimum and average interest rates for funds loaned to the Nonutility Money Pool are summarized in the following table: Three Months Ended March 31, 2021 Three Months Ended March 31, 2020 Maximum Minimum Average Maximum Minimum Average Interest Rate Interest Rate Interest Rate Interest Rate Interest Rate Interest Rate for Funds for Funds for Funds for Funds for Funds for Funds Loaned to Loaned to Loaned to Loaned to Loaned to Loaned to the Nonutility the Nonutility the Nonutility the Nonutility the Nonutility the Nonutility Company Money Pool Money Pool Money Pool Money Pool Money Pool Money Pool AEP Texas 0.40 % 0.25 % 0.30 % 2.24 % 1.76 % 1.94 % SWEPCo 0.40 % 0.25 % 0.30 % 2.24 % 1.76 % 1.94 % AEPTCo’s maximum, minimum and average interest rates for funds either borrowed from or loaned to AEP are summarized in the following table: Maximum Minimum Maximum Minimum Average Average Interest Rate Interest Rate Interest Rate Interest Rate Interest Rate Interest Rate Three Months for Funds for Funds for Funds for Funds for Funds for Funds Ended Borrowed Borrowed Loaned Loaned Borrowed Loaned March 31, from AEP from AEP to AEP to AEP from AEP to AEP 2021 0.86 % 0.25 % 0.86 % 0.25 % 0.31 % 0.31 % 2020 2.24 % 1.76 % 2.24 % 1.76 % 1.94 % 1.94 % Short-term Debt (Applies to AEP and SWEPCo) Outstanding short-term debt was as follows: March 31, 2021 December 31, 2020 Outstanding Interest Outstanding Interest Company Type of Debt Amount Rate (a) Amount Rate (a) (dollars in millions) AEP Securitized Debt for Receivables (b) $ 669.0 0.20 % $ 592.0 0.85 % AEP Commercial Paper 1,874.4 0.27 % 1,852.3 0.29 % AEP 364-Day Term Loan 500.0 0.71 % — — % SWEPCo Notes Payable 5.0 2.75 % 35.0 2.55 % Total Short-term Debt $ 3,048.4 $ 2,479.3 (a) Weighted-average rate. (b) Amount of securitized debt for receivables as accounted for under the “Transfers and Servicing” accounting guidance. Credit Facilities For a discussion of credit facilities, see “Letters of Credit” section of Note 5. Securitized Accounts Receivables – AEP Credit (Applies to AEP) AEP Credit has a receivables securitization agreement that provides a commitment of $750 million from bank conduits to purchase receivables and expires in September 2022. 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. In March 2021, AEP Credit amended its receivables securitization agreement to extend trigger levels established in October 2020 and to also provide a step down approach to these levels as management continues to monitor the accounts receivable balances across the affiliated utility subsidiaries in response to the COVID-19 pandemic. As of March 31, 2021, the affiliated utility subsidiaries are in compliance with all requirements under the agreement. To the extent that an affiliated utility subsidiary is deemed ineligible under the agreement, the affiliated utility subsidiary would no longer participate in the receivables securitization agreement and the Registrants would need to rely on additional sources of funding for operation and working capital, which may adversely impact liquidity. The receivables that are ineligible under the receivables securitization agreement are financed with short-term debt at AEP Credit. Accounts receivable information for AEP Credit was as follows: Three Months Ended March 31, 2021 2020 (dollars in millions) Effective Interest Rates on Securitization of Accounts Receivable 0.20 % 1.75 % Net Uncollectible Accounts Receivable Written-Off $ 9.3 $ 4.2 March 31, 2021 December 31, 2020 (in millions) Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts $ 871.4 $ 958.4 Short-term – Securitized Debt of Receivables 669.0 592.0 Delinquent Securitized Accounts Receivable 67.7 62.3 Bad Debt Reserves Related to Securitization 47.6 60.0 Unbilled Receivables Related to Securitization 211.2 296.8 AEP Credit’s delinquent customer accounts receivable represent accounts greater than 30 days past due. Securitized Accounts Receivables – AEP Credit (Applies to all Registrant Subsidiaries except AEP Texas and AEPTCo) Under this sale of receivables arrangement, the Registrant Subsidiaries sell, without recourse, certain of their customer accounts receivable and accrued unbilled revenue balances to AEP Credit and are charged a fee based on AEP Credit’s financing costs, administrative costs and uncollectible accounts experience for each Registrant Subsidiary’s receivables. APCo does not have regulatory authority to sell its West Virginia accounts receivable. The costs of customer accounts receivable sold are reported in Other Operation expense on the Registrant Subsidiaries’ statements of income. The Registrant Subsidiaries manage and service their customer accounts receivable, which are sold to AEP Credit. AEP Credit securitizes the eligible receivables for the operating companies and retains the remainder. The amount of accounts receivable and accrued unbilled revenues under the sale of receivables agreements were: Company March 31, 2021 December 31, 2020 (in millions) APCo $ 132.6 $ 136.0 I&M 154.0 170.5 OPCo 360.2 398.8 PSO 76.2 85.0 SWEPCo 132.9 158.6 The fees paid to AEP Credit for customer accounts receivable sold were: Three Months Ended March 31, Company 2021 2020 (in millions) APCo $ 1.2 $ 1.7 I&M 1.6 2.8 OPCo 1.3 4.8 PSO 0.7 1.3 SWEPCo 1.5 2.1 The proceeds on the sale of receivables to AEP Credit were: Three Months Ended March 31, Company 2021 2020 (in millions) APCo $ 362.4 $ 352.6 I&M 478.8 471.4 OPCo 601.3 570.3 PSO 284.9 294.9 SWEPCo 384.4 365.6

Revenue from Contracts with Cus

Revenue from Contracts with Customers	3 Months Ended
	Mar. 31, 2021
Revenue from Contract with Customer	13. REVENUE FROM CONTRACTS WITH CUSTOMERS The disclosures in this note apply to all Registrants, unless indicated otherwise. Disaggregated Revenues from Contracts with Customers The tables below represent AEP’s reportable segment revenues from contracts with customers, net of respective provisions for refund, by type of revenue: Three Months Ended March 31, 2021 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation & Marketing Corporate and Other Reconciling Adjustments AEP Consolidated (in millions) Retail Revenues: Residential Revenues $ 1,046.1 $ 548.1 $ — $ — $ — $ — $ 1,594.2 Commercial Revenues 486.2 239.2 — — — — 725.4 Industrial Revenues 484.0 85.7 — — — (0.2) 569.5 Other Retail Revenues 37.8 10.0 — — — — 47.8 Total Retail Revenues 2,054.1 883.0 — — — (0.2) 2,936.9 Wholesale and Competitive Retail Revenues: Generation Revenues 352.6 — — 40.5 — — 393.1 Transmission Revenues (a) 89.0 130.5 360.4 — — (299.3) 280.6 Renewable Generation Revenues (b) — — — 22.4 — (0.7) 21.7 Retail, Trading and Marketing Revenues (c) — — — 569.8 1.2 (31.8) 539.2 Total Wholesale and Competitive Retail Revenues 441.6 130.5 360.4 632.7 1.2 (331.8) 1,234.6 Other Revenues from Contracts with Customers (b) 42.3 52.1 4.6 1.5 8.6 (21.2) 87.9 Total Revenues from Contracts with Customers 2,538.0 1,065.6 365.0 634.2 9.8 (353.2) 4,259.4 Other Revenues: Alternative Revenues (b) (0.7) 17.2 12.0 — — (11.6) 16.9 Other Revenues (b) — 5.3 — — 3.1 (3.6) 4.8 Total Other Revenues (0.7) 22.5 12.0 — 3.1 (15.2) 21.7 Total Revenues $ 2,537.3 $ 1,088.1 $ 377.0 $ 634.2 $ 12.9 $ (368.4) $ 4,281.1 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $273 million. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $32 million. The remaining affiliated amounts were immaterial. Three Months Ended March 31, 2020 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation & Marketing Corporate and Other Reconciling Adjustments AEP Consolidated (in millions) Retail Revenues: Residential Revenues $ 915.1 $ 521.3 $ — $ — $ — $ — $ 1,436.4 Commercial Revenues 489.4 276.9 — — — — 766.3 Industrial Revenues 518.2 97.8 — — — (0.2) 615.8 Other Retail Revenues 39.9 11.8 — — — — 51.7 Total Retail Revenues 1,962.6 907.8 — — — (0.2) 2,870.2 Wholesale and Competitive Retail Revenues: Generation Revenues 140.4 — — 44.1 — — 184.5 Transmission Revenues (a) 79.9 114.1 309.8 — — (263.0) 240.8 Renewable Generation Revenues (b) — — — 17.2 — (0.6) 16.6 Retail, Trading and Marketing Revenues (c) — — — 358.7 (6.0) (29.4) 323.3 Total Wholesale and Competitive Retail Revenues 220.3 114.1 309.8 420.0 (6.0) (293.0) 765.2 Other Revenues from Contracts with Customers (b) 43.6 36.4 3.7 0.3 28.1 (40.6) 71.5 Total Revenues from Contracts with Customers 2,226.5 1,058.3 313.5 420.3 22.1 (333.8) 3,706.9 Other Revenues: Alternative Revenues (b) 0.2 19.3 (3.3) — — 4.5 20.7 Other Revenues (b) — 29.3 — 18.3 (2.2) (25.5) 19.9 Total Other Revenues 0.2 48.6 (3.3) 18.3 (2.2) (21.0) 40.6 Total Revenues $ 2,226.7 $ 1,106.9 $ 310.2 $ 438.6 $ 19.9 $ (354.8) $ 3,747.5 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $239 million. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $35 million. The remaining affiliated amounts were immaterial. Three Months Ended March 31, 2021 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 122.7 $ — $ 416.9 $ 213.6 $ 425.3 $ 136.8 $ 166.3 Commercial Revenues 80.7 — 130.2 113.6 158.5 72.7 112.9 Industrial Revenues 26.5 — 130.9 128.4 59.2 56.4 70.6 Other Retail Revenues 6.8 — 16.9 1.4 3.2 15.7 2.3 Total Retail Revenues 236.7 — 694.9 457.0 646.2 281.6 352.1 Wholesale Revenues: Generation Revenues (a) — — 72.4 79.6 — (7.1) 228.6 Transmission Revenues (b) 112.0 345.2 34.2 8.3 18.5 9.4 28.9 Total Wholesale Revenues 112.0 345.2 106.6 87.9 18.5 2.3 257.5 Other Revenues from Contracts with Customers (c) 16.2 4.6 13.1 20.7 36.0 12.6 6.4 Total Revenues from Contracts with Customers 364.9 349.8 814.6 565.6 700.7 296.5 616.0 Other Revenues: Alternative Revenues (d) (0.7) 11.9 2.2 (1.1) 17.9 (0.4) 0.1 Other Revenues (d) — — 0.2 — 5.3 — — Total Other Revenues (0.7) 11.9 2.4 (1.1) 23.2 (0.4) 0.1 Total Revenues $ 364.2 $ 361.7 $ 817.0 $ 564.5 $ 723.9 $ 296.1 $ 616.1 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $32 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $270 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $16 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. Three Months Ended March 31, 2020 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 132.9 $ — $ 357.5 $ 201.3 $ 388.4 $ 128.5 $ 131.6 Commercial Revenues 112.8 — 132.3 122.2 164.0 76.1 105.6 Industrial Revenues 35.2 — 141.1 137.8 62.7 61.3 79.8 Other Retail Revenues 8.4 — 17.9 1.8 3.4 16.6 2.0 Total Retail Revenues 289.3 — 648.8 463.1 618.5 282.5 319.0 Wholesale Revenues: Generation Revenues (a) — — 54.1 78.4 — 1.9 34.1 Transmission Revenues (b) 96.9 298.2 30.4 7.4 17.1 7.8 25.4 Total Wholesale Revenues 96.9 298.2 84.5 85.8 17.1 9.7 59.5 Other Revenues from Contracts with Customers (c) 7.9 3.4 17.2 21.0 28.6 4.7 5.8 Total Revenues from Contracts with Customers 394.1 301.6 750.5 569.9 664.2 296.9 384.3 Other Revenues: Alternative Revenues (d) (0.7) (6.0) (1.1) 0.4 20.0 0.4 1.6 Other Revenues (d) 30.2 — — — 6.1 — — Total Other Revenues 29.5 (6.0) (1.1) 0.4 26.1 0.4 1.6 Total Revenues $ 423.6 $ 295.6 $ 749.4 $ 570.3 $ 690.3 $ 297.3 $ 385.9 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $33 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $235 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $16 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. Fixed Performance Obligations The following table represents the Registrants’ remaining fixed performance obligations satisfied over time as of March 31, 2021. Fixed performance obligations primarily include wholesale transmission services, electricity sales for fixed amounts of energy and stand ready services into PJM’s RPM market. The Registrant Subsidiaries amounts shown in the table below include affiliated and nonaffiliated revenues. Company 2021 2022-2023 2024-2025 After 2025 Total (in millions) AEP $ 873.4 $ 171.3 $ 160.4 $ 161.5 $ 1,366.6 AEP Texas 349.0 — — — 349.0 AEPTCo 1,001.3 — — — 1,001.3 APCo 130.4 32.3 24.3 11.7 198.7 I&M 25.8 8.8 8.8 4.4 47.8 OPCo 49.7 — — 0.1 49.8 PSO 14.8 — — — 14.8 SWEPCo 41.6 — — — 41.6 Contract Assets and Liabilities Contract assets are recognized when the Registrants have a right to consideration that is conditional upon the occurrence of an event other than the passage of time, such as future performance under a contract. The Registrants did not have material contract assets as of March 31, 2021 and December 31, 2020. When the Registrants receive consideration, or such consideration is unconditionally due from a customer prior to transferring goods or services to the customer under the terms of a sales contract, they recognize a contract liability on the balance sheets in the amount of that consideration. Revenue for such consideration is subsequently recognized in the period or periods in which the remaining performance obligations in the contract are satisfied. The Registrants’ contract liabilities typically arise from services provided under joint use agreements for utility poles. The Registrants did not have material contract liabilities as of March 31, 2021 and December 31, 2020. Accounts Receivable from Contracts with Customers Accounts receivable from contracts with customers are presented on the Registrant Subsidiaries’ balance sheets within the Accounts Receivable - Customers line item. The Registrant Subsidiaries’ balances for receivables from contracts that are not recognized in accordance with the accounting guidance for “Revenue from Contracts with Customers” included in Accounts Receivable - Customers were not material as of March 31, 2021 and December 31, 2020. See “Securitized Accounts Receivable - AEP Credit” section of Note 12 for additional information. The following table represents the amount of affiliated accounts receivable from contracts with customers included in Accounts Receivable - Affiliated Companies on the Registrant Subsidiaries’ balance sheets: Company March 31, 2021 December 31, 2020 (in millions) AEPTCo $ 92.3 $ 81.0 APCo 52.6 52.7 I&M 31.4 34.8 OPCo 47.8 45.9 PSO 14.9 7.8 SWEPCo 22.8 11.2

Significant Accounting Matters

Significant Accounting Matters (Policies)	3 Months Ended
	Mar. 31, 2021
Basis of Accounting	General The unaudited condensed financial statements and footnotes were prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X of the SEC. Accordingly, they do not include all of the information and footnotes required by GAAP for complete annual financial statements. In the opinion of management, the unaudited condensed interim financial statements reflect all normal and recurring accruals and adjustments necessary for a fair statement of the net income, financial position and cash flows for the interim periods for each Registrant. Net income for the three months ended March 31, 2021 is not necessarily indicative of results that may be expected for the year ending December 31, 2021. The condensed financial statements are unaudited and should be read in conjunction with the audited 2020 financial statements and notes thereto, which are included in the Registrants’ Annual Reports on Form 10-K as filed with the SEC on February 25, 2021.
Earnings Per Share	Earnings Per Share (EPS) (Applies to AEP) Basic EPS is calculated by dividing net earnings available to common shareholders by the weighted-average number of common shares outstanding during the period. Diluted EPS is calculated by adjusting the weighted-average outstanding common shares, assuming conversion of all potentially dilutive stock awards.

Derivatives and Hedging (Polici

Derivatives and Hedging (Policies)	3 Months Ended
	Mar. 31, 2021
Derivatives and Hedging	OBJECTIVES FOR UTILIZATION OF DERIVATIVE INSTRUMENTS AEPSC is agent for and transacts on behalf of 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 expense line item on the statements of income as that of the associated risk. 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 For cash flow hedges (i.e. hedging the exposure to variability in expected future cash flows that is attributable to a particular risk), the Registrants initially report the gain or loss on the derivative instrument as a component of Accumulated Other Comprehensive Income (Loss) on the balance sheets until the period the hedged item affects net income. Credit Risk Management mitigates credit risk in wholesale marketing and trading activities by assessing the creditworthiness of potential counterparties before entering into transactions with them and continuing to evaluate their creditworthiness on an ongoing basis. Management uses credit agency ratings and current market-based qualitative and quantitative data as well as financial statements to assess the financial health of counterparties on an ongoing basis. Master agreements are typically used to facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Collateral requirements in the form of cash, letters of credit and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. Some master agreements include margining, which requires a counterparty to post cash or letters of credit in the event exposure exceeds the established threshold. The threshold represents an unsecured credit limit which may be supported by a parental/affiliate guaranty, as determined in accordance with AEP’s credit policy. In addition, master agreements allow for termination and liquidation of all positions in the event of a default including a failure or inability to post collateral when required. Collateral Triggering Events Credit Downgrade Triggers (Applies to AEP, APCo, I&M, PSO and SWEPCo)

Fair Value Measurements (Polici

Fair Value Measurements (Policies)	3 Months Ended
	Mar. 31, 2021
Valuation Techniques	Fair Value Hierarchy and Valuation Techniques The accounting guidance for “Fair Value Measurements and Disclosures” establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). Where observable inputs are available for substantially the full term of the asset or liability, the instrument is categorized in Level 2. When quoted market prices are not available, pricing may be completed using comparable securities, dealer values, operating data and general market conditions to determine fair value. Valuation models utilize various inputs such as commodity, interest rate and, to a lesser degree, volatility and credit that include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, market corroborated inputs (i.e. inputs derived principally from, or correlated to, observable market data) and other observable inputs for the asset or liability. For commercial activities, exchange-traded derivatives, namely futures contracts, are generally fair valued based on unadjusted quoted prices in active markets and are classified as Level 1. Level 2 inputs primarily consist of OTC broker quotes in moderately active or less active markets, as well as exchange-traded derivatives where there is insufficient market liquidity to warrant inclusion in Level 1. Management verifies price curves using these broker quotes and classifies these fair values within Level 2 when substantially all of the fair value can be corroborated. Management typically obtains multiple broker quotes, which are nonbinding in nature but are based on recent trades in the marketplace. When multiple broker quotes are obtained, the quoted bid and ask prices are averaged. In certain circumstances, a broker quote may be discarded if it is a clear outlier. Management uses a historical correlation analysis between the broker quoted location and the illiquid locations. If the points are highly correlated, these locations are included within Level 2 as well. Certain OTC and bilaterally executed derivative instruments are executed in less active markets with a lower availability of pricing information. Illiquid transactions, complex structured transactions, FTRs and counterparty credit risk may require nonmarket-based inputs. Some of these inputs may be internally developed or extrapolated and utilized to estimate fair value. When such inputs have a significant impact on the measurement of fair value, the instrument is categorized as Level 3. The main driver of contracts being classified as Level 3 is the inability to substantiate energy price curves in the market. A portion of the Level 3 instruments have been economically hedged which limits potential earnings volatility. AEP utilizes its trustee’s external pricing service to estimate the fair value of the underlying investments held in the nuclear trusts. AEP’s investment managers review and validate the prices utilized by the trustee to determine fair value. AEP’s management performs its own valuation testing to verify the fair values of the securities. AEP receives audit reports of the trustee’s operating controls and valuation processes. Assets in the nuclear trusts, cash and cash equivalents, other temporary investments restricted cash for securitized funding are classified using the following methods. Equities are classified as Level 1 holdings if they are actively traded on exchanges. Items classified as Level 1 are investments in money market funds, fixed income and equity mutual funds and equity securities. They are valued based on observable inputs, primarily unadjusted quoted prices in active markets for identical assets. Items classified as Level 2 are primarily investments in individual fixed income securities. Fixed income securities generally do not trade on exchanges and do not have an official closing price but their valuation inputs are based on observable market data. Pricing vendors calculate bond valuations using financial models and matrices. The models use observable inputs including yields on benchmark securities, quotes by securities brokers, rating agency actions, discounts or premiums on securities compared to par prices, changes in yields for U.S. Treasury securities, corporate actions by bond issuers, prepayment schedules and histories, economic events and, for certain securities, adjustments to yields to reflect changes in the rate of inflation. Other securities with model-derived valuation inputs that are observable are also classified as Level 2 investments. Investments with unobservable valuation inputs are classified as Level 3 investments.
Fair Values of Long-term Debt	Fair Value Measurements of Long-term Debt (Applies to all Registrants) The fair values of Long-term Debt are based on quoted market prices, without credit enhancements, for the same or similar issues and the current interest rates offered for instruments with similar maturities classified as Level 2 measurement inputs. These instruments are not marked-to-market. The estimates presented are not necessarily indicative of the amounts that could be realized in a current market exchange. The fair value of AEP’s Equity Units (Level 1) are valued based on publicly traded securities issued by AEP.
Trust Assets for Decommissioning and Spent Nuclear Fuel Disposal	Fair Value Measurements of Trust Assets for Decommissioning and SNF Disposal (Applies to AEP and I&M) Nuclear decommissioning and SNF trust funds represent funds that regulatory commissions allow I&M to collect through rates to fund future decommissioning and SNF disposal liabilities. By rules or orders, the IURC, the MPSC and the FERC established investment limitations and general risk management guidelines. In general, limitations include: • Acceptable investments (rated investment grade or above when purchased). • Maximum percentage invested in a specific type of investment. • Prohibition of investment in obligations of AEP, I&M or their affiliates. • Withdrawals permitted only for payment of decommissioning costs and trust expenses. I&M maintains trust funds for each regulatory jurisdiction. Regulatory approval is required to withdraw decommissioning funds. These funds are managed by an external investment manager that must comply with the guidelines and rules of the applicable regulatory authorities. The trust assets are invested to optimize the net of tax earnings of the trust giving consideration to liquidity, risk, diversification and other prudent investment objectives. I&M records securities held in these trust funds in Spent Nuclear Fuel and Decommissioning Trusts on its balance sheets. I&M records these securities at fair value. I&M classifies debt securities in the trust funds as available-for-sale due to their long-term purpose. Other-than-temporary impairments for investments in debt securities are considered realized losses as a result of securities being managed by an external investment management firm. The external investment management firm makes specific investment decisions regarding the debt and equity investments held in these trusts and generally intends to sell debt securities in an unrealized loss position as part of a tax optimization strategy. Impairments reduce the cost basis of the securities which will affect any future unrealized gain or realized gain or loss due to the adjusted cost of investment. I&M records unrealized gains, unrealized losses and other-than-temporary impairments from securities in these trust funds as adjustments to the regulatory liability account for the nuclear decommissioning trust funds and to regulatory assets or liabilities for the SNF disposal trust funds in accordance with their treatment in rates. Consequently, changes in fair value of trust assets do not affect earnings or AOCI.
Fair Value Assets and Liabilities Measured on Recurring Basis	Fair Value Measurements of Financial Assets and Liabilities The following tables set forth, by level within the fair value hierarchy, the Registrants’ financial assets and liabilities that were accounted for at fair value on a recurring basis. As required by the accounting guidance for “Fair Value Measurements and Disclosures,” financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. Management’s assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. There have not been any significant changes in management’s valuation techniques.

Income Taxes (Policies)

Income Taxes (Policies)	3 Months Ended
	Mar. 31, 2021
Amortization of Excess ADIT Not Subject to Normalization Requirements Policy	The Registrants include the amortization of Excess ADIT not subject to normalization requirements in the annual estimated ETR when regulatory proceedings instruct the Registrants to provide the benefits of Tax Reform to customers over multiple interim periods.  Certain regulatory proceedings instruct the Registrants to provide the benefits of Tax Reform to customers in a single period (e.g. by applying the Excess ADIT not subject to normalization requirements against an existing regulatory asset balance) and in these circumstances, the Registrants recognize the tax benefit discretely in the period recorded. The annual amount of Excess ADIT approved by the Registrant’s regulatory commissions may not impact the ETR ratably during each interim period due to the variability of pretax book income between interim periods and the application of an annual estimated ETR.

Significant Accounting Matter_2

Significant Accounting Matters (Tables)	3 Months Ended
	Mar. 31, 2021
Earnings Per Share	Three Months Ended March 31, 2021 2020 (in millions, except per share data) $/share $/share Earnings Attributable to AEP Common Shareholders $ 575.0 $ 495.2 Weighted-Average Number of Basic AEP Common Shares Outstanding 497.1 $ 1.16 494.6 $ 1.00 Weighted-Average Dilutive Effect of Stock-Based Awards 1.1 (0.01) 2.0 — Weighted-Average Number of Diluted AEP Common Shares Outstanding 498.2 $ 1.15 496.6 $ 1.00
Supplementary Information	March 31, 2021 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 273.2 $ 0.1 $ 4.8 Restricted Cash 50.8 39.3 11.6 Total Cash, Cash Equivalents and Restricted Cash $ 324.0 $ 39.4 $ 16.4 December 31, 2020 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 392.7 $ 0.1 $ 5.8 Restricted Cash 45.6 28.7 16.9 Total Cash, Cash Equivalents and Restricted Cash $ 438.3 $ 28.8 $ 22.7

Comprehensive Income (Tables)

Comprehensive Income (Tables)	3 Months Ended
	Mar. 31, 2021
Changes in Accumulated Other Comprehensive Income (Loss) by Component	AEP Cash Flow Hedges Pension Three Months Ended March 31, 2021 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2020 $ (60.6) $ (47.5) $ 23.0 $ (85.1) Change in Fair Value Recognized in AOCI 177.3 13.1 (a) — 190.4 Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (b) 0.8 — — 0.8 Purchased Electricity for Resale (b) (172.0) — — (172.0) Interest Expense (b) — 1.5 — 1.5 Amortization of Prior Service Cost (Credit) — — (4.8) (4.8) Amortization of Actuarial (Gains) Losses — — 2.3 2.3 Reclassifications from AOCI, before Income Tax (Expense) Benefit (171.2) 1.5 (2.5) (172.2) Income Tax (Expense) Benefit (36.0) 0.4 (0.5) (36.1) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (135.2) 1.1 (2.0) (136.1) Net Current Period Other Comprehensive Income (Loss) 42.1 14.2 (2.0) 54.3 Balance in AOCI as of March 31, 2021 $ (18.5) $ (33.3) $ 21.0 $ (30.8) Cash Flow Hedges Pension Three Months Ended March 31, 2020 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2019 $ (103.5) $ (11.5) $ (32.7) $ (147.7) Change in Fair Value Recognized in AOCI (65.3) (42.7) (a) — (108.0) Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (b) (0.1) — — (0.1) Purchased Electricity for Resale (b) 51.1 — — 51.1 Interest Expense (b) — 0.9 — 0.9 Amortization of Prior Service Cost (Credit) — — (4.9) (4.9) Amortization of Actuarial (Gains) Losses — — 2.6 2.6 Reclassifications from AOCI, before Income Tax (Expense) Benefit 51.0 0.9 (2.3) 49.6 Income Tax (Expense) Benefit 10.7 0.2 (0.5) 10.4 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 40.3 0.7 (1.8) 39.2 Net Current Period Other Comprehensive Income (Loss) (25.0) (42.0) (1.8) (68.8) Balance in AOCI as of March 31, 2020 $ (128.5) $ (53.5) $ (34.5) $ (216.5) AEP Texas Cash Flow Hedge – Pension Three Months Ended March 31, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2020 $ (2.3) $ (6.6) $ (8.9) Change in Fair Value Recognized in AOCI 0.1 — 0.1 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.3 — 0.3 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.3 — 0.3 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.2 — 0.2 Net Current Period Other Comprehensive Income (Loss) 0.3 — 0.3 Balance in AOCI as of March 31, 2021 $ (2.0) $ (6.6) $ (8.6) Cash Flow Hedge – Pension Three Months Ended March 31, 2020 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2019 $ (3.4) $ (9.4) $ (12.8) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.4 — 0.4 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.4 — 0.4 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.3 — 0.3 Net Current Period Other Comprehensive Income (Loss) 0.3 — 0.3 Balance in AOCI as of March 31, 2020 $ (3.1) $ (9.4) $ (12.5) APCo Cash Flow Hedge – Pension Three Months Ended March 31, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2020 $ (0.8) $ 8.0 $ 7.2 Change in Fair Value Recognized in AOCI 9.3 — 9.3 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (0.4) — (0.4) Amortization of Prior Service Cost (Credit) — (1.4) (1.4) Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.4) (1.4) (1.8) Income Tax (Expense) Benefit (0.1) (0.3) (0.4) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.3) (1.1) (1.4) Net Current Period Other Comprehensive Income (Loss) 9.0 (1.1) 7.9 Balance in AOCI as of March 31, 2021 $ 8.2 $ 6.9 $ 15.1 Cash Flow Hedge – Pension Three Months Ended March 31, 2020 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2019 $ 0.9 $ 4.1 $ 5.0 Change in Fair Value Recognized in AOCI (3.9) — (3.9) Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (0.4) — (0.4) Amortization of Prior Service Cost (Credit) — (1.3) (1.3) Amortization of Actuarial (Gains) Losses — 0.1 0.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.4) (1.2) (1.6) Income Tax (Expense) Benefit (0.1) (0.3) (0.4) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.3) (0.9) (1.2) Net Current Period Other Comprehensive Income (Loss) (4.2) (0.9) (5.1) Balance in AOCI as of March 31, 2020 $ (3.3) $ 3.2 $ (0.1) I&M Cash Flow Hedge – Pension Three Months Ended March 31, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2020 $ (8.3) $ 1.3 $ (7.0) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.6 — 0.6 Amortization of Prior Service Cost (Credit) — (0.2) (0.2) Amortization of Actuarial (Gains) Losses — 0.2 0.2 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.6 — 0.6 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.5 — 0.5 Net Current Period Other Comprehensive Income (Loss) 0.5 — 0.5 Balance in AOCI as of March 31, 2021 $ (7.8) $ 1.3 $ (6.5) Cash Flow Hedge – Pension Three Months Ended March 31, 2020 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2019 $ (9.9) $ (1.7) $ (11.6) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.5 — 0.5 Amortization of Prior Service Cost (Credit) — (0.2) (0.2) Amortization of Actuarial (Gains) Losses — 0.2 0.2 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.5 — 0.5 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.4 — 0.4 Net Current Period Other Comprehensive Income (Loss) 0.4 — 0.4 Balance in AOCI as of March 31, 2020 $ (9.5) $ (1.7) $ (11.2) OPCo Cash Flow Hedge – Three Months Ended March 31, 2021 Interest Rate (in millions) Balance in AOCI as of December 31, 2020 $ — Change in Fair Value Recognized in AOCI — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) — Reclassifications from AOCI, before Income Tax (Expense) Benefit — Income Tax (Expense) Benefit — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit — Net Current Period Other Comprehensive Income (Loss) — Balance in AOCI as of March 31, 2021 $ — Cash Flow Hedge – Three Months Ended March 31, 2020 Interest Rate (in millions) Balance in AOCI as of December 31, 2019 $ — Change in Fair Value Recognized in AOCI — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) — Reclassifications from AOCI, before Income Tax (Expense) Benefit — Income Tax (Expense) Benefit — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit — Net Current Period Other Comprehensive Income (Loss) — Balance in AOCI as of March 31, 2020 $ — PSO Cash Flow Hedge – Three Months Ended March 31, 2021 Interest Rate (in millions) Balance in AOCI as of December 31, 2020 $ 0.1 Change in Fair Value Recognized in AOCI — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (0.1) Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.1) Income Tax (Expense) Benefit — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.1) Net Current Period Other Comprehensive Income (Loss) (0.1) Balance in AOCI as of March 31, 2021 $ — Cash Flow Hedge – Three Months Ended March 31, 2020 Interest Rate (in millions) Balance in AOCI as of December 31, 2019 $ 1.1 Change in Fair Value Recognized in AOCI — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (0.3) Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.3) Income Tax (Expense) Benefit (0.1) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.2) Net Current Period Other Comprehensive Income (Loss) (0.2) Balance in AOCI as of March 31, 2020 $ 0.9 SWEPCo Cash Flow Hedge – Pension Three Months Ended March 31, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2020 $ (0.3) $ 2.2 $ 1.9 Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.5 — 0.5 Amortization of Prior Service Cost (Credit) — (0.5) (0.5) Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.5 (0.5) — Income Tax (Expense) Benefit 0.1 (0.1) — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.4 (0.4) — Net Current Period Other Comprehensive Income (Loss) 0.4 (0.4) — Balance in AOCI as of March 31, 2021 $ 0.1 $ 1.8 $ 1.9 Cash Flow Hedge – Pension Three Months Ended March 31, 2020 Interest Rate and OPEB Total (in millions) Balance in AOCI as of December 31, 2019 $ (1.8) $ 0.5 $ (1.3) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.5 — 0.5 Amortization of Prior Service Cost (Credit) — (0.5) (0.5) Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.5 (0.5) — Income Tax (Expense) Benefit 0.1 (0.1) — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.4 (0.4) — Net Current Period Other Comprehensive Income (Loss) 0.4 (0.4) — Balance in AOCI as of March 31, 2020 $ (1.4) $ 0.1 $ (1.3) (a) The change in fair value includes $4 million and $5 million related to AEP's investment in joint venture wind farms acquired as part of the purchase of Sempra Renewables LLC for the three months ended March 31, 2021 and 2020, respectively. (b) Amounts reclassified to the referenced line item on the statements of income.

Rate Matters (Tables)

Rate Matters (Tables)	3 Months Ended
	Mar. 31, 2021
Regulated Generating Units to be Retired	Plant Net Accelerated Depreciation Regulatory Asset Cost of Removal Projected Current Authorized Annual (dollars in millions) Northeastern Plant, Unit 3 $ 190.5 $ 114.8 $ 19.8 (b) 2026 (c) $ 14.9 Dolet Hills Power Station 51.3 92.6 1.1 2021 (d) 7.7 Pirkey Power Plant 178.3 30.8 18.4 2023 (e) 13.7 Welsh Plant, Units 1 and 3 528.8 14.2 11.4 (f) 2028 (g) 33.3 (a) Represents the amount of annual depreciation that has been collected from customers over the prior 12-month period. (b) Includes Northeastern Plant, Unit 4, which was retired in 2016. Removal of Northeastern Plant, Unit 4, will be performed with Northeastern Plant, Unit 3, after retirement. (c) Northeastern Plant, Unit 3 is currently being recovered through 2040. (d) Dolet Hills Power Station is currently being recovered through 2026 in the Louisiana jurisdiction and through 2046 in the Arkansas and Texas jurisdictions. (e) Pirkey Power Plant is currently being recovered through 2025 in the Louisiana jurisdiction and through 2045 in the Arkansas and Texas jurisdictions. (f) Includes Welsh Plant, Unit 2, which was retired in 2016. Removal of Welsh Plant, Unit 2, will be performed with Welsh Plant, Units 1 and 3, after retirement.
Regulatory Assets Pending Final Regulatory Approval	AEP March 31, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Unrecovered Winter Storm Fuel Costs (a) $ 1,185.0 $ — Dolet Hills Power Station Accelerated Depreciation 92.6 71.2 Kentucky Deferred Purchase Power Expenses 42.8 41.3 Plant Retirement Costs – Unrecovered Plant, Louisiana 35.2 35.2 Oklaunion Power Station Accelerated Depreciation 34.0 34.4 Pirkey Power Plant Accelerated Depreciation 30.8 12.2 Other Regulatory Assets Pending Final Regulatory Approval 37.5 26.4 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 285.0 134.2 Plant Retirement Costs – Asset Retirement Obligation Costs 25.9 25.9 COVID-19 19.5 24.9 Environmental Expense Deferral - Virginia 12.3 9.3 Other Regulatory Assets Pending Final Regulatory Approval 33.0 27.2 Total Regulatory Assets Pending Final Regulatory Approval $ 1,833.6 $ 442.2 (a) PSO and SWEPCo have active fuel clauses that allow for the recovery of prudently incurred fuel and purchased power expenses. However, the recovery of these costs from customers may be extended over longer than usual time periods to mitigate the impact on customer bills. See “Impacts of Severe Winter Weather” section below for additional information. AEP Texas March 31, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Advanced Metering System $ 16.4 $ 16.3 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 10.5 0.8 COVID-19 8.6 10.5 Texas Retail Electric Provider Bad Debt Expense 4.1 — Vegetation Management Program 3.8 3.8 Other Regulatory Assets Pending Final Regulatory Approval 2.6 1.5 Total Regulatory Assets Pending Final Regulatory Approval $ 46.0 $ 32.9 APCo March 31, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return COVID-19 – Virginia $ 4.0 $ 3.7 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 49.1 3.4 Plant Retirement Costs – Asset Retirement Obligation Costs 25.9 25.9 Environmental Expense Deferral - Virginia 12.3 9.3 COVID-19 – West Virginia 1.6 1.5 Total Regulatory Assets Pending Final Regulatory Approval $ 92.9 $ 43.8 I&M March 31, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Other Regulatory Assets Pending Final Regulatory Approval $ — $ 0.5 Regulatory Assets Currently Not Earning a Return COVID-19 2.8 3.8 Other Regulatory Assets Pending Final Regulatory Approval 0.6 — Total Regulatory Assets Pending Final Regulatory Approval $ 3.4 $ 4.3 OPCo March 31, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Not Earning a Return Storm-Related Costs $ 6.8 $ 4.0 COVID-19 1.5 4.4 Other Regulatory Assets Pending Final Regulatory Approval 0.1 — Total Regulatory Assets Pending Final Regulatory Approval $ 8.4 $ 8.4 PSO March 31, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Unrecovered Winter Storm Fuel Costs (a) $ 688.7 $ — Oklaunion Power Station Accelerated Depreciation 34.0 34.4 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 24.8 15.8 Other Regulatory Assets Pending Final Regulatory Approval 0.8 0.3 Total Regulatory Assets Pending Final Regulatory Approval $ 748.3 $ 50.5 (a) PSO has an active fuel clause that allows for the recovery of prudently incurred fuel and purchased power expenses. However, the recovery of these costs from customers may be extended over longer than usual time periods to mitigate the impact on customer bills. See “Impacts of Severe Winter Weather” section below for additional information. SWEPCo March 31, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Unrecovered Winter Storm Fuel Costs (a) $ 496.3 $ — Dolet Hills Power Station Accelerated Depreciation 92.6 71.2 Plant Retirement Costs – Unrecovered Plant, Louisiana 35.2 35.2 Pirkey Power Plant Accelerated Depreciation 30.8 12.2 Welsh Plant, Units 1 and 3 Accelerated Depreciation 14.2 3.6 Other Regulatory Assets Pending Final Regulatory Approval 2.8 2.2 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 139.1 99.3 Asset Retirement Obligation - Louisiana 9.4 9.1 Other Regulatory Assets Pending Final Regulatory Approval 15.4 14.5 Total Regulatory Assets Pending Final Regulatory Approval $ 835.8 $ 247.3 (a) SWEPCo has an active fuel clause that allows for the recovery of prudently incurred fuel and purchased power expenses. However, the recovery of these costs from customers may be extended over longer than usual time periods to mitigate the impact on customer bills. See “Impacts of Severe Winter Weather” section below for additional information.
February 2021 Winter Storm Costs	March 31, 2021 Company Jurisdiction Capital O&M Regulatory Asset Total (in millions) APCo Virginia $ 5.4 $ 2.2 $ 5.6 $ 13.2 APCo West Virginia 19.6 — 39.1 58.7 SWEPCo Louisiana 4.9 — 42.1 47.0 KPCo Kentucky 26.7 3.8 44.1 74.6 Total $ 56.6 $ 6.0 $ 130.9 $ 193.5
February 2021 Winter Storm Fuel Costs	PSO SWEPCo Total (in millions) Retail Customers (a) $ 688.7 $ 496.3 $ 1,185.0 Wholesale Customers — 88.4 88.4 Total $ 688.7 $ 584.7 $ 1,273.4 (a) These costs were deferred as regulatory assets as of March 31, 2021.

Commitments, Guarantees and C_2

Commitments, Guarantees and Contingencies (Tables)	3 Months Ended
	Mar. 31, 2021
Maximum Future Payments for Letters of Credit Uncommitted Facilities	Company Amount Maturity (in millions) AEP $ 183.2 April 2021 to March 2022 AEP Texas 2.2 July 2021
Max Potential Loss on Master Lease Agreements	Company Maximum (in millions) AEP $ 48.6 AEP Texas 11.3 APCo 6.3 I&M 4.2 OPCo 7.7 PSO 4.7 SWEPCo 5.4
Future Minimum Lease Payments for Sale and Leaseback	Future Minimum Lease Payments AEP (a) I&M (in millions) 2021 $ 147.8 $ 73.9 2022 147.6 73.8 Total Future Minimum Lease Payments $ 295.4 $ 147.7 (a) AEP’s future minimum lease payments include equal shares from AEGCo and I&M.

Benefit Plans (Tables)

Benefit Plans (Tables)	3 Months Ended
	Mar. 31, 2021
Components of Net Periodic Benefit Cost	AEP Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2021 2020 2021 2020 (in millions) Service Cost $ 32.3 $ 28.0 $ 2.4 $ 2.5 Interest Cost 34.3 42.0 7.6 9.9 Expected Return on Plan Assets (57.5) (66.2) (22.8) (23.9) Amortization of Prior Service Credit — — (17.7) (17.4) Amortization of Net Actuarial Loss 25.4 23.4 — 1.5 Net Periodic Benefit Cost (Credit) $ 34.5 $ 27.2 $ (30.5) $ (27.4) AEP Texas Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2021 2020 2021 2020 (in millions) Service Cost $ 3.0 $ 2.6 $ 0.2 $ 0.2 Interest Cost 2.8 3.5 0.6 0.8 Expected Return on Plan Assets (4.9) (5.7) (1.9) (2.0) Amortization of Prior Service Credit — — (1.5) (1.4) Amortization of Net Actuarial Loss 2.1 1.9 — 0.1 Net Periodic Benefit Cost (Credit) $ 3.0 $ 2.3 $ (2.6) $ (2.3) APCo Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2021 2020 2021 2020 (in millions) Service Cost $ 3.0 $ 2.6 $ 0.3 $ 0.3 Interest Cost 4.1 5.1 1.2 1.6 Expected Return on Plan Assets (7.3) (8.4) (3.4) (3.6) Amortization of Prior Service Credit — — (2.6) (2.5) Amortization of Net Actuarial Loss 3.0 2.8 — 0.2 Net Periodic Benefit Cost (Credit) $ 2.8 $ 2.1 $ (4.5) $ (4.0) I&M Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2021 2020 2021 2020 (in millions) Service Cost $ 4.4 $ 3.9 $ 0.3 $ 0.3 Interest Cost 4.0 4.9 0.9 1.2 Expected Return on Plan Assets (7.2) (8.3) (2.8) (2.9) Amortization of Prior Service Credit — — (2.4) (2.4) Amortization of Net Actuarial Loss 2.9 2.7 — 0.2 Net Periodic Benefit Cost (Credit) $ 4.1 $ 3.2 $ (4.0) $ (3.6) OPCo Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2021 2020 2021 2020 (in millions) Service Cost $ 2.9 $ 2.4 $ 0.2 $ 0.2 Interest Cost 3.1 3.9 0.8 1.0 Expected Return on Plan Assets (5.6) (6.6) (2.4) (2.6) Amortization of Prior Service Credit — — (1.8) (1.8) Amortization of Net Actuarial Loss 2.2 2.1 — 0.2 Net Periodic Benefit Cost (Credit) $ 2.6 $ 1.8 $ (3.2) $ (3.0) PSO Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2021 2020 2021 2020 (in millions) Service Cost $ 1.9 $ 1.8 $ 0.2 $ 0.2 Interest Cost 1.7 2.1 0.4 0.5 Expected Return on Plan Assets (3.1) (3.6) (1.3) (1.3) Amortization of Prior Service Credit — — (1.1) (1.1) Amortization of Net Actuarial Loss 1.3 1.2 — 0.1 Net Periodic Benefit Cost (Credit) $ 1.8 $ 1.5 $ (1.8) $ (1.6) SWEPCo Pension Plans OPEB Three Months Ended March 31, Three Months Ended March 31, 2021 2020 2021 2020 (in millions) Service Cost $ 2.9 $ 2.5 $ 0.1 $ 0.2 Interest Cost 2.1 2.5 0.5 0.6 Expected Return on Plan Assets (3.4) (3.9) (1.5) (1.5) Amortization of Prior Service Credit — — (1.3) (1.3) Amortization of Net Actuarial Loss 1.5 1.4 — 0.1 Net Periodic Benefit Cost (Credit) $ 3.1 $ 2.5 $ (2.2) $ (1.9)

Business Segments (Tables)

Business Segments (Tables)	3 Months Ended
	Mar. 31, 2021
Segment Reporting Information [Line Items]
Reportable Segment Information	Three Months Ended March 31, 2021 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) Revenues from: External Customers $ 2,504.5 $ 1,082.3 $ 87.9 $ 601.7 $ 4.7 $ — $ 4,281.1 Other Operating Segments 32.8 5.8 289.1 32.5 8.2 (368.4) — Total Revenues $ 2,537.3 $ 1,088.1 $ 377.0 $ 634.2 $ 12.9 $ (368.4) $ 4,281.1 Net Income (Loss) $ 271.4 $ 114.4 $ 173.2 $ 38.2 $ (18.4) $ — $ 578.8 Three Months Ended March 31, 2020 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Adjustments Consolidated (in millions) Revenues from: External Customers $ 2,193.0 $ 1,075.2 $ 73.1 $ 408.4 $ (2.2) $ — $ 3,747.5 Other Operating Segments 33.7 31.7 237.1 30.2 22.1 (354.8) — Total Revenues $ 2,226.7 $ 1,106.9 $ 310.2 $ 438.6 $ 19.9 $ (354.8) $ 3,747.5 Net Income (Loss) $ 246.3 $ 116.2 $ 141.6 $ 30.5 $ (35.3) $ — $ 499.3 March 31, 2021 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Consolidated (in millions) Total Property, Plant and Equipment $ 49,448.9 $ 21,492.9 $ 12,185.2 $ 2,080.6 $ 405.3 $ — $ 85,612.9 Accumulated Depreciation and Amortization 15,950.1 3,951.3 648.1 183.8 183.5 — 20,916.8 Total Property Plant and Equipment - Net $ 33,498.8 $ 17,541.6 $ 11,537.1 $ 1,896.8 $ 221.8 $ — $ 64,696.1 Total Assets $ 44,591.3 $ 20,076.9 $ 12,925.8 $ 3,881.8 $ 6,072.0 (b) $ (4,562.7) (c) $ 82,985.1 Long-term Debt Due Within One Year: Nonaffiliated $ 1,078.3 $ 589.0 $ 52.4 $ — $ 410.5 (d) $ — $ 2,130.2 Long-term Debt: Affiliated 65.0 — — — — (65.0) — Nonaffiliated 13,185.8 7,097.4 4,089.7 — 5,841.9 (d) — 30,214.8 Total Long-term Debt $ 14,329.1 $ 7,686.4 $ 4,142.1 $ — $ 6,252.4 (d) $ (65.0) $ 32,345.0 December 31, 2020 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation Corporate and Other (a) Reconciling Consolidated (in millions) Total Property, Plant and Equipment $ 49,023.3 $ 21,145.0 $ 11,827.2 $ 1,910.2 $ 407.3 $ — $ 84,313.0 Accumulated Depreciation and Amortization 15,586.2 3,879.3 595.7 166.1 184.1 — 20,411.4 Total Property Plant and Equipment - Net $ 33,437.1 $ 17,265.7 $ 11,231.5 $ 1,744.1 $ 223.2 $ — $ 63,901.6 Total Assets $ 42,752.7 $ 19,765.9 $ 12,627.3 $ 3,585.9 $ 5,987.1 (b) $ (3,961.7) (c) $ 80,757.2 Long-term Debt Due Within One Year: Nonaffiliated $ 1,034.6 $ 588.8 $ 52.3 $ — $ 410.4 (d) $ — $ 2,086.1 Long-term Debt: Affiliated 65.0 — — — — (65.0) — Nonaffiliated 12,375.6 6,661.9 4,075.7 — 5,873.2 (d) — 28,986.4 Total Long-term Debt $ 13,475.2 $ 7,250.7 $ 4,128.0 $ — $ 6,283.6 (d) $ (65.0) $ 31,072.5 (a) Corporate and Other primarily includes the purchasing of receivables from certain AEP utility subsidiaries. This segment also includes Parent’s guarantee revenue received from affiliates, investment income, interest income, interest expense and other nonallocated costs. (b) Includes elimination of AEP Parent’s investments in wholly-owned subsidiary companies. (c) Reconciling Adjustments for Total Assets primarily include elimination of intercompany advances to affiliates and intercompany accounts receivable. (d) Amounts are inclusive of the impact of fair value hedge accounting. See “Accounting for Fair Value Hedging Strategies” section of Note 10 for additional information. Three Months Ended March 31, 2021 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Revenues from: External Customers $ 76.0 $ — $ — $ 76.0 Sales to AEP Affiliates 285.6 — — 285.6 Other Revenues 0.1 — — 0.1 Total Revenues $ 361.7 $ — $ — $ 361.7 Interest Income $ — $ 38.3 $ (38.2) (a) $ 0.1 Interest Expense 34.1 38.2 (38.2) (a) 34.1 Income Tax Expense 39.6 — — 39.6 Net Income $ 151.7 $ — (b) $ — $ 151.7 Three Months Ended March 31, 2020 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Revenues from: External Customers $ 61.3 $ — $ — $ 61.3 Sales to AEP Affiliates 233.7 — — 233.7 Other Revenues 0.6 — — 0.6 Total Revenues $ 295.6 $ — $ — $ 295.6 Interest Income $ 0.2 $ 34.0 $ (33.4) (a) $ 0.8 Interest Expense 29.6 33.4 (33.4) (a) 29.6 Income Tax Expense 31.8 — — 31.8 Net Income $ 117.3 $ 0.5 (b) $ — $ 117.8 March 31, 2021 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Total Transmission Property $ 11,694.0 $ — $ — $ 11,694.0 Accumulated Depreciation and Amortization 623.6 — — 623.6 Total Transmission Property – Net $ 11,070.4 $ — $ — $ 11,070.4 Notes Receivable - Affiliated $ — $ 3,899.0 $ (3,899.0) (c) $ — Total Assets $ 11,458.3 $ 4,107.2 (d) $ (4,050.4) (e) $ 11,515.1 Total Long-term Debt $ 3,990.0 $ 3,949.0 $ (3,990.0) (c) $ 3,949.0 December 31, 2020 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Total Transmission Property $ 11,345.6 $ — $ — $ 11,345.6 Accumulated Depreciation and Amortization 572.8 — — 572.8 Total Transmission Property – Net $ 10,772.8 $ — $ — $ 10,772.8 Notes Receivable - Affiliated $ — $ 3,948.5 $ (3,948.5) (c) $ — Total Assets $ 11,185.1 $ 4,084.0 (d) $ (4,023.1) (e) $ 11,246.0 Total Long-term Debt $ 3,990.0 $ 3,948.5 $ (3,990.0) (c) $ 3,948.5 (a) Elimination of intercompany interest income/interest expense on affiliated debt arrangement. (b) Includes the elimination of AEPTCo Parent’s equity earnings in the State Transcos. (c) Elimination of intercompany debt. (d) Includes the elimination of AEPTCo Parent’s investments in State Transcos. (e) Primarily relates to the elimination of Notes Receivable from the State Transcos.	[1]
[1]	Includes elimination of AEP Parent’s investments in wholly-owned subsidiary companies.

Derivatives and Hedging (Tables

Derivatives and Hedging (Tables)	3 Months Ended
	Mar. 31, 2021
Notional Volume of Derivative Instruments	Notional Volume of Derivative Instruments March 31, 2021 Primary Risk Unit of AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power MWhs 271.2 — 23.3 10.8 2.9 3.8 1.6 Natural Gas MMBtus 22.7 — — — — — 7.0 Heating Oil and Gasoline Gallons 5.0 1.3 0.8 0.5 1.0 0.5 0.7 Interest Rate USD $ 123.6 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt USD $ 950.0 $ — $ — $ — $ — $ — $ — December 31, 2020 Primary Risk Unit of AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power MWhs 331.3 — 46.9 19.7 3.0 11.9 4.0 Natural Gas MMBtus 26.9 — — — — — 7.9 Heating Oil and Gasoline Gallons 6.9 1.8 1.1 0.6 1.4 0.7 0.9 Interest Rate USD $ 129.8 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt USD $ 1,150.0 $ — $ 200.0 $ — $ — $ — $ —
Fair Value of Derivative Instruments	AEP March 31, 2021 Risk Hedging Contracts Gross Amounts Gross Net Amounts of Balance Sheet Location Commodity (a) Commodity (a) Interest Rate (a) (in millions) Current Risk Management Assets $ 164.1 $ 34.8 $ 2.7 $ 201.6 $ (129.5) $ 72.1 Long-term Risk Management Assets 266.9 18.8 — 285.7 (20.9) 264.8 Total Assets 431.0 53.6 2.7 487.3 (150.4) 336.9 Current Risk Management Liabilities 133.6 34.8 — 168.4 (129.3) 39.1 Long-term Risk Management Liabilities 219.8 41.6 37.4 298.8 (25.8) 273.0 Total Liabilities 353.4 76.4 37.4 467.2 (155.1) 312.1 Total MTM Derivative Contract Net Assets (Liabilities) $ 77.6 $ (22.8) $ (34.7) $ 20.1 $ 4.7 $ 24.8 December 31, 2020 Risk Hedging Contracts Gross Amounts Gross Net Amounts of Balance Sheet Location Commodity (a) Commodity (a) Interest Rate (a) (in millions) Current Risk Management Assets $ 239.1 $ 21.1 $ 5.0 $ 265.2 $ (170.5) $ 94.7 Long-term Risk Management Assets 275.9 18.0 — 293.9 (51.7) 242.2 Total Assets 515.0 39.1 5.0 559.1 (222.2) 336.9 Current Risk Management Liabilities 193.0 54.4 3.4 250.8 (172.0) 78.8 Long-term Risk Management Liabilities 222.2 60.1 4.1 286.4 (53.6) 232.8 Total Liabilities 415.2 114.5 7.5 537.2 (225.6) 311.6 Total MTM Derivative Contract Net Assets (Liabilities) $ 99.8 $ (75.4) $ (2.5) $ 21.9 $ 3.4 $ 25.3 AEP Texas March 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 0.8 $ (0.8) $ — Long-term Risk Management Assets — — — Total Assets 0.8 (0.8) — Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — — — Total Liabilities — — — Total MTM Derivative Contract Net Assets (Liabilities) $ 0.8 $ (0.8) $ — December 31, 2020 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 0.4 $ (0.4) $ — Long-term Risk Management Assets — — — Total Assets 0.4 (0.4) — Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — — — Total Liabilities — — — Total MTM Derivative Contract Net Assets (Liabilities) $ 0.4 $ (0.4) $ — APCo March 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement Balance Sheet Location Commodity (a) Financial Position (b) of Financial Position (c) (in millions) Current Risk Management Assets $ 16.5 $ (9.6) $ 6.9 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets 0.5 (0.5) — Total Assets 17.0 (10.1) 6.9 Other Current Liabilities - Current Risk Management Liabilities 9.3 (9.1) 0.2 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities 0.5 (0.5) — Total Liabilities 9.8 (9.6) 0.2 Total MTM Derivative Contract Net Assets (Liabilities) $ 7.2 $ (0.5) $ 6.7 December 31, 2020 Gross Amounts Risk of Risk Gross Amounts Net Amounts of Assets/ Management Hedging Management Offset in the Liabilities Presented in Contracts – Contracts – Assets/Liabilities Statement of the Statement of Balance Sheet Location Commodity (a) Interest Rate (a) Recognized Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 38.8 $ 2.4 $ 41.2 $ (18.8) $ 22.4 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets 0.7 — 0.7 (0.6) 0.1 Total Assets 39.5 2.4 41.9 (19.4) 22.5 Other Current Liabilities - Current Risk Management Liabilities 19.7 3.4 23.1 (18.5) 4.6 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities 0.6 — 0.6 (0.5) 0.1 Total Liabilities 20.3 3.4 23.7 (19.0) 4.7 Total MTM Derivative Contract Net Assets (Liabilities) $ 19.2 $ (1.0) $ 18.2 $ (0.4) $ 17.8 I&M March 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 6.8 $ (5.9) $ 0.9 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets 0.3 (0.3) — Total Assets 7.1 (6.2) 0.9 Other Current Liabilities - Current Risk Management Liabilities 6.2 (6.0) 0.2 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities 0.3 (0.3) — Total Liabilities 6.5 (6.3) 0.2 Total MTM Derivative Contract Net Assets $ 0.6 $ 0.1 $ 0.7 December 31, 2020 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 17.2 $ (13.6) $ 3.6 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets 0.5 (0.4) 0.1 Total Assets 17.7 (14.0) 3.7 Other Current Liabilities - Current Risk Management Liabilities 12.1 (12.0) 0.1 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities 0.4 (0.3) 0.1 Total Liabilities 12.5 (12.3) 0.2 Total MTM Derivative Contract Net Assets (Liabilities) $ 5.2 $ (1.7) $ 3.5 OPCo March 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 0.6 $ (0.6) $ — Long-term Risk Management Assets — — — Total Assets 0.6 (0.6) — Current Risk Management Liabilities 8.1 — 8.1 Long-term Risk Management Liabilities 95.9 — 95.9 Total Liabilities 104.0 — 104.0 Total MTM Derivative Contract Net Liabilities $ (103.4) $ (0.6) $ (104.0) December 31, 2020 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 0.3 $ (0.3) $ — Long-term Risk Management Assets — — — Total Assets 0.3 (0.3) — Current Risk Management Liabilities 8.7 — 8.7 Long-term Risk Management Liabilities 101.6 — 101.6 Total Liabilities 110.3 — 110.3 Total MTM Derivative Contract Net Liabilities $ (110.0) $ (0.3) $ (110.3) PSO March 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 5.8 $ (0.3) $ 5.5 Long-term Risk Management Assets — — — Total Assets 5.8 (0.3) 5.5 Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — — — Total Liabilities — — — Total MTM Derivative Contract Net Assets (Liabilities) $ 5.8 $ (0.3) $ 5.5 December 31, 2020 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 10.5 $ (0.2) $ 10.3 Long-term Risk Management Assets — — — Total Assets 10.5 (0.2) 10.3 Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — — — Total Liabilities — — — Total MTM Derivative Contract Net Assets (Liabilities) $ 10.5 $ (0.2) $ 10.3 SWEPCo March 31, 2021 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 1.7 $ (0.4) $ 1.3 Long-term Risk Management Assets — — — Total Assets 1.7 (0.4) 1.3 Current Risk Management Liabilities — — — Long-term Risk Management Liabilities 0.9 — 0.9 Total Liabilities 0.9 — 0.9 Total MTM Derivative Contract Net Assets (Liabilities) $ 0.8 $ (0.4) $ 0.4 December 31, 2020 Risk Management Gross Amounts Offset Net Amounts of Assets/Liabilities Contracts – in the Statement of Presented in the Statement of Balance Sheet Location Commodity (a) Financial Position (b) Financial Position (c) (in millions) Current Risk Management Assets $ 3.4 $ (0.2) $ 3.2 Long-term Risk Management Assets — — — Total Assets 3.4 (0.2) 3.2 Current Risk Management Liabilities 0.7 — 0.7 Long-term Risk Management Liabilities 1.0 — 1.0 Total Liabilities 1.7 — 1.7 Total MTM Derivative Contract Net Assets (Liabilities) $ 1.7 $ (0.2) $ 1.5 (a) Derivative instruments within these categories are reported gross. These instruments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with the accounting guidance for “Derivatives and Hedging.” (b) Amounts include counterparty netting of risk management and hedging contracts and associated cash collateral in accordance with the accounting guidance for “Derivatives and Hedging.” (c) All derivative contracts subject to a master netting arrangement or similar agreement are offset in the statement of financial position.
Amount of Gain (Loss) Recognized on Risk Management Contracts	Amount of Gain (Loss) Recognized on Risk Management Contracts Three Months Ended March 31, 2021 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 0.2 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues (0.4) — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.2 — — — — Purchased Electricity for Resale 0.4 — 0.4 — — — — Other Operation 0.3 0.1 — — 0.1 — — Maintenance 0.5 0.1 0.1 0.1 0.1 0.1 0.1 Regulatory Assets (a) 6.4 — — (0.9) 6.6 — 0.8 Regulatory Liabilities (a) 22.0 0.4 3.4 (3.2) 2.9 11.2 6.2 Total Gain (Loss) on Risk Management Contracts $ 29.4 $ 0.6 $ 4.1 $ (4.0) $ 9.7 $ 11.3 $ 7.1 Three Months Ended March 31, 2020 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 0.4 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues (10.3) — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.2 0.1 — — — Purchased Electricity for Resale 0.1 — 0.1 — — — — Other Operation (0.2) (0.1) — — (0.1) — — Maintenance (0.2) (0.1) (0.1) — — — — Regulatory Assets (a) (33.9) (1.2) (8.9) (0.7) (18.4) (0.5) (0.2) Regulatory Liabilities (a) 11.2 — (7.3) 3.2 3.5 8.1 3.3 Total Gain (Loss) on Risk Management Contracts $ (32.9) $ (1.4) $ (16.0) $ 2.6 $ (15.0) $ 7.6 $ 3.1 (a) Represents realized and unrealized gains and losses subject to regulatory accounting treatment recorded as either current or noncurrent on the balance sheets.
Impact of Fair Value Hedges on the Condensed Balance Sheet	Carrying Amount of the Hedged Liabilities Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of the Hedged Liabilities March 31, 2021 December 31, 2020 March 31, 2021 December 31, 2020 (in millions) Long-term Debt (a) (b) $ (959.4) $ (995.9) $ (16.6) $ (51.7) (a) Amounts included on the balance sheets within Long-term Debt Due within One Year and Long-term Debt, respectively.
Gain (Loss) on Hedging Instruments	Three Months Ended March 31, 2021 2020 (in millions) Gain (Loss) on Interest Rate Contracts: Fair Value Hedging Instruments (a) $ (33.2) $ 42.5 Fair Value Portion of Long-term Debt (a) 33.2 (42.5) (a) Gain (Loss) is included in Interest Expense on the statements of income.
Impact of Cash Flow Hedges on the Condensed Balance Sheet	Impact of Cash Flow Hedges on AEP’s Balance Sheets March 31, 2021 December 31, 2020 Commodity Interest Rate Commodity Interest Rate (in millions) AOCI Loss Net of Tax $ (18.5) $ (33.3) $ (60.6) $ (47.5) Portion Expected to be Reclassed to Net Income During the Next Twelve Months (0.3) (5.1) (27.1) (5.7) Impact of Cash Flow Hedges on the Registrant Subsidiaries’ Balance Sheets March 31, 2021 December 31, 2020 Interest Rate Expected to be Expected to be Reclassified to Reclassified to Net Income During Net Income During AOCI Gain (Loss) the Next AOCI Gain (Loss) the Next Company Net of Tax Twelve Months Net of Tax Twelve Months (in millions) AEP Texas $ (2.0) $ (1.1) $ (2.3) $ (1.1) APCo 8.2 0.8 (0.8) 0.4 I&M (7.8) (1.6) (8.3) (1.6) PSO — — 0.1 0.1 SWEPCo 0.1 (1.2) (0.3) (1.5)
Liabilities Subject to Cross Default Provisions	March 31, 2021 Liabilities for Additional Contracts with Cross Settlement Default Provisions Liability if Cross Prior to Contractual Amount of Cash Default Provision Company Netting Arrangements Collateral Posted is Triggered (in millions) AEP $ 156.8 $ — $ 127.7 APCo 0.6 — 0.1 I&M 0.4 — 0.1 SWEPCo 0.9 — 0.9 December 31, 2020 Liabilities for Additional Contracts with Cross Settlement Default Provisions Liability if Cross Prior to Contractual Amount of Cash Default Provision Company Netting Arrangements Collateral Posted is Triggered (in millions) AEP $ 188.4 $ — $ 169.2 APCo 4.3 — 3.5 I&M 0.5 — 0.1 SWEPCo 1.8 — 1.8

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2021
Book Values and Fair Values of Long-term Debt	March 31, 2021 December 31, 2020 Company Book Value Fair Value Book Value Fair Value (in millions) AEP (a) $ 32,345.0 $ 35,802.4 $ 31,072.5 $ 37,457.0 AEP Texas 4,810.2 5,235.6 4,820.4 5,682.6 AEPTCo 3,949.0 4,460.1 3,948.5 4,984.3 APCo 4,966.2 5,871.1 4,834.1 6,391.8 I&M 3,006.3 3,422.9 3,029.9 3,775.3 OPCo 2,876.3 3,316.1 2,430.2 3,154.9 PSO 1,623.8 1,842.4 1,373.8 1,732.1 SWEPCo 3,131.4 3,444.8 2,636.4 3,210.1 (a) The fair value amounts include debt related to AEP’s Equity Units and had a fair value of $1.6 billion and $1.7 billion as of March 31, 2021 and December 31, 2020, respectively. See “Equity Units” section of Note 12 for additional information.
Other Temporary Investments	March 31, 2021 Gross Gross Unrealized Unrealized Fair Other Temporary Investments Cost Gains Losses Value (in millions) Restricted Cash and Other Cash Deposits (a) $ 74.6 $ — $ — $ 74.6 Fixed Income Securities – Mutual Funds (b) 116.7 2.0 — 118.7 Equity Securities – Mutual Funds 24.9 31.7 — 56.6 Total Other Temporary Investments $ 216.2 $ 33.7 $ — $ 249.9 December 31, 2020 Gross Gross Unrealized Unrealized Fair Other Temporary Investments Cost Gains Losses Value (in millions) Restricted Cash and Other Cash Deposits (a) $ 68.3 $ — $ — $ 68.3 Fixed Income Securities – Mutual Funds (b) 120.7 2.8 — 123.5 Equity Securities – Mutual Funds 25.9 28.7 — 54.6 Total Other Temporary Investments $ 214.9 $ 31.5 $ — $ 246.4 (a) Primarily represents amounts held for the repayment of debt. (b) Primarily short and intermediate maturities which may be sold and do not contain maturity dates.
Debt and Equity Securities Within Other Temporary Investments	Three Months Ended March 31, 2021 2020 (in millions) Proceeds from Investment Sales $ 5.5 $ 23.2 Purchases of Investments 0.7 6.7 Gross Realized Gains on Investment Sales 0.1 2.0 Gross Realized Losses on Investment Sales — 0.1
Nuclear Trust Fund Investments	March 31, 2021 December 31, 2020 Gross Other-Than- Gross Other-Than- Fair Unrealized Temporary Fair Unrealized Temporary Value Gains Impairments Value Gains Impairments (in millions) Cash and Cash Equivalents $ 47.7 $ — $ — $ 25.8 $ — $ — Fixed Income Securities: United States Government 998.9 54.8 (13.0) 1,025.6 98.5 (7.1) Corporate Debt 76.4 4.8 (2.6) 86.3 9.6 (1.7) State and Local Government 83.8 0.4 (0.7) 114.3 0.9 (0.4) Subtotal Fixed Income Securities 1,159.1 60.0 (16.3) 1,226.2 109.0 (9.2) Equity Securities - Domestic (a) 2,207.5 1,543.5 — 2,054.7 1,400.8 — Spent Nuclear Fuel and Decommissioning Trusts $ 3,414.3 $ 1,603.5 $ (16.3) $ 3,306.7 $ 1,509.8 $ (9.2)
Securities Activity Within the Decommissioning and SNF Trusts	Three Months Ended March 31, 2021 2020 (in millions) Proceeds from Investment Sales $ 320.0 $ 612.4 Purchases of Investments 336.9 626.0 Gross Realized Gains on Investment Sales 5.4 10.9 Gross Realized Losses on Investment Sales 4.2 17.0
Contractual Maturities, Fair Value of Debt Securities in Nuclear Trusts	Fair Value of Fixed Income Securities (in millions) Within 1 year $ 320.5 After 1 year through 5 years 334.7 After 5 years through 10 years 233.6 After 10 years 270.3 Total $ 1,159.1
Fair Value, Assets and Liabilities Measured on Recurring Basis	AEP Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments Restricted Cash and Other Cash Deposits (a) $ 62.9 $ — $ — $ 11.7 $ 74.6 Fixed Income Securities – Mutual Funds 118.7 — — — 118.7 Equity Securities – Mutual Funds (b) 56.6 — — — 56.6 Total Other Temporary Investments 238.2 — — 11.7 249.9 Risk Management Assets Risk Management Commodity Contracts (c) (d) 1.2 217.9 194.8 (94.8) 319.1 Cash Flow Hedges: Commodity Hedges (c) — 44.4 2.7 (32.0) 15.1 Fair Value Hedges — 2.7 — — 2.7 Total Risk Management Assets 1.2 265.0 197.5 (126.8) 336.9 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 39.5 — — 8.2 47.7 Fixed Income Securities: United States Government — 998.9 — — 998.9 Corporate Debt — 76.4 — — 76.4 State and Local Government — 83.8 — — 83.8 Subtotal Fixed Income Securities — 1,159.1 — — 1,159.1 Equity Securities – Domestic (b) 2,207.5 — — — 2,207.5 Total Spent Nuclear Fuel and Decommissioning Trusts 2,247.0 1,159.1 — 8.2 3,414.3 Other Investments (h) — 56.7 — — 56.7 Total Assets $ 2,486.4 $ 1,480.8 $ 197.5 $ (106.9) $ 4,057.8 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (d) $ 0.8 $ 182.7 $ 152.8 $ (99.5) $ 236.8 Cash Flow Hedges: Commodity Hedges (c) — 67.0 2.9 (32.0) 37.9 Fair Value Hedges — 37.4 — — 37.4 Total Risk Management Liabilities $ 0.8 $ 287.1 $ 155.7 $ (131.5) $ 312.1 AEP Assets and Liabilities Measured at Fair Value on a Recurring Basis December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments Restricted Cash and Other Cash Deposits (a) $ 57.8 $ — $ — $ 10.5 $ 68.3 Fixed Income Securities – Mutual Funds 123.5 — — — 123.5 Equity Securities – Mutual Funds (b) 54.6 — — — 54.6 Total Other Temporary Investments 235.9 — — 10.5 246.4 Risk Management Assets Risk Management Commodity Contracts (c) (f) 0.9 258.8 252.4 (190.0) 322.1 Cash Flow Hedges: Commodity Hedges (c) — 34.4 3.9 (28.5) 9.8 Interest Rate Hedges — 2.4 — — 2.4 Fair Value Hedges — 2.6 — — 2.6 Total Risk Management Assets 0.9 298.2 256.3 (218.5) 336.9 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 16.8 — — 9.0 25.8 Fixed Income Securities: United States Government — 1,025.6 — — 1,025.6 Corporate Debt — 86.3 — — 86.3 State and Local Government — 114.3 — — 114.3 Subtotal Fixed Income Securities — 1,226.2 — — 1,226.2 Equity Securities – Domestic (b) 2,054.7 — — — 2,054.7 Total Spent Nuclear Fuel and Decommissioning Trusts 2,071.5 1,226.2 — 9.0 3,306.7 Other Investments (h) — — 31.8 — 31.8 Total Assets $ 2,308.3 $ 1,524.4 $ 288.1 $ (199.0) $ 3,921.8 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (f) $ 0.9 $ 244.2 $ 167.2 $ (193.4) $ 218.9 Cash Flow Hedges: Commodity Hedges (c) — 106.1 7.6 (28.5) 85.2 Interest Rate Hedges — 3.4 — — 3.4 Fair Value Hedges — 4.1 — — 4.1 Total Risk Management Liabilities $ 0.9 $ 357.8 $ 174.8 $ (221.9) $ 311.6 AEP Texas Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 39.3 $ — $ — $ — $ 39.3 Risk Management Assets Risk Management Commodity Contracts (c) — 0.8 — (0.8) — Total Assets $ 39.3 $ 0.8 $ — $ (0.8) $ 39.3 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 28.7 $ — $ — $ — $ 28.7 Risk Management Assets Risk Management Commodity Contracts (c) — 0.4 — (0.4) — Total Assets $ 28.7 $ 0.4 $ — $ (0.4) $ 28.7 APCo Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 11.6 $ — $ — $ — $ 11.6 Risk Management Assets Risk Management Commodity Contracts (c) (g) — 9.8 7.1 (10.0) 6.9 Total Assets $ 11.6 $ 9.8 $ 7.1 $ (10.0) $ 18.5 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 9.2 $ 0.5 $ (9.5) $ 0.2 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 16.9 $ — $ — $ — $ 16.9 Risk Management Assets Risk Management Commodity Contracts (c) (g) — 19.4 19.9 (19.2) 20.1 Cash Flow Hedges: Interest Rate Hedges — 2.4 — — 2.4 Total Risk Management Assets — 21.8 19.9 (19.2) 22.5 Total Assets $ 16.9 $ 21.8 $ 19.9 $ (19.2) $ 39.4 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 19.5 $ 0.6 $ (18.8) $ 1.3 Cash Flow Hedges: Interest Rate Hedges — 3.4 — — 3.4 Total Risk Management Liabilities $ — $ 22.9 $ 0.6 $ (18.8) $ 4.7 I&M Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 6.0 $ 1.1 $ (6.2) $ 0.9 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 39.5 — — 8.2 47.7 Fixed Income Securities: United States Government — 998.9 — — 998.9 Corporate Debt — 76.4 — — 76.4 State and Local Government — 83.8 — — 83.8 Subtotal Fixed Income Securities — 1,159.1 — — 1,159.1 Equity Securities - Domestic (b) 2,207.5 — — — 2,207.5 Total Spent Nuclear Fuel and Decommissioning Trusts 2,247.0 1,159.1 — 8.2 3,414.3 Total Assets $ 2,247.0 $ 1,165.1 $ 1.1 $ 2.0 $ 3,415.2 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 6.1 $ 0.4 $ (6.3) $ 0.2 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 15.1 $ 2.5 $ (13.9) $ 3.7 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 16.8 — — 9.0 25.8 Fixed Income Securities: United States Government — 1,025.6 — — 1,025.6 Corporate Debt — 86.3 — — 86.3 State and Local Government — 114.3 — — 114.3 Subtotal Fixed Income Securities — 1,226.2 — — 1,226.2 Equity Securities - Domestic (b) 2,054.7 — — — 2,054.7 Total Spent Nuclear Fuel and Decommissioning Trusts 2,071.5 1,226.2 — 9.0 3,306.7 Total Assets $ 2,071.5 $ 1,241.3 $ 2.5 $ (4.9) $ 3,310.4 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 12.0 $ 0.4 $ (12.2) $ 0.2 OPCo Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.6 $ — $ (0.6) $ — Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 104.0 $ — $ 104.0 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.3 $ — $ (0.3) $ — Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 110.3 $ — $ 110.3 PSO Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.3 $ 5.5 $ (0.3) $ 5.5 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.2 $ 10.3 $ (0.2) $ 10.3 SWEPCo Assets and Liabilities Measured at Fair Value on a Recurring Basis March 31, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.3 $ 1.4 $ (0.4) $ 1.3 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 0.9 $ — $ 0.9 December 31, 2020 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.1 $ 3.3 $ (0.2) $ 3.2 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 1.7 $ — $ 1.7 (a) Amounts in “Other’’ column primarily represent cash deposits in bank accounts with financial institutions or third-parties. Level 1 and Level 2 amounts primarily represent investments in money market funds. (b) Amounts represent publicly traded equity securities and equity-based mutual funds. (c) Amounts in “Other’’ column primarily represent counterparty netting of risk management and hedging contracts and associated cash collateral under the accounting guidance for “Derivatives and Hedging.’’ (d) The March 31, 2021 maturity of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 2 matures $(3) million in 2021, $11 million in periods 2022-2024, $17 million in periods 2025-2026 and $10 million in periods 2027-2033; Level 3 matures $23 million in 2021, $32 million in periods 2022-2024, $8 million in periods 2025-2026 and $(21) million in periods 2027-2033. Risk management commodity contracts are substantially comprised of power contracts. (e) Amounts in “Other’’ column primarily represent accrued interest receivables from financial institutions. Level 1 amounts primarily represent investments in money market funds. (f) The December 31, 2020 maturity of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 2 matures $3 million in periods 2022-2024, $11 million in periods 2025-2026 and $1 million in periods 2027-2033; Level 3 matures $47 million in 2021, $37 million in periods 2022-2024, $14 million in periods 2025-2026 and $(13) million in periods 2027-2033. Risk management commodity contracts are substantially comprised of power contracts. (g) Substantially comprised of power contracts for the Registrant Subsidiaries. (h) See “Warrants Held in Investee” section of Note 9 for additional information.
Changes in Fair Value of Net Trading Derivatives and Other Investments	Three Months Ended March 31, 2021 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of December 31, 2020 $ 113.3 $ 19.3 $ 2.1 $ (110.3) $ 10.3 $ 1.6 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 19.8 2.1 0.3 — 9.3 6.1 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (21.3) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 3.1 — — — — — Settlements (47.9) (15.6) (1.4) 2.7 (16.3) (8.2) Transfers into Level 3 (d) (e) 0.5 — — — — — Transfers out of Level 3 (e) (33.0) — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 7.3 0.8 (0.3) 3.6 2.2 1.0 Balance as of March 31, 2021 $ 41.8 $ 6.6 $ 0.7 $ (104.0) $ 5.5 $ 0.5 Three Months Ended March 31, 2020 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of December 31, 2019 $ 109.9 $ 37.7 $ 5.8 $ (103.6) $ 15.8 $ 1.4 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 0.9 (9.2) 0.2 (0.3) 8.0 1.9 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) 10.9 — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) (4.1) — — — — — Settlements (59.2) (21.9) (4.0) 2.5 (17.7) (5.3) Transfers into Level 3 (d) (e) (0.5) — — — — — Transfers out of Level 3 (e) 5.3 0.7 0.4 — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) (20.7) (0.7) (0.3) (19.5) 0.2 (0.5) Balance as of March 31, 2020 $ 42.5 $ 6.6 $ 2.1 $ (120.9) $ 6.3 $ (2.5) (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 net gains (losses) are recorded as regulatory assets/liabilities or accounts payable.
Significant Unobservable Inputs for Level 3	AEP Significant Unobservable Inputs March 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (in millions) Energy Contracts $ 178.5 $ 151.7 Discounted Cash Flow Forward Market Price (a) (c) $ 0.10 $ 98.66 $ 28.85 Natural Gas Contracts — 0.9 Discounted Cash Flow Forward Market Price (b) (c) 2.24 2.92 2.50 FTRs 19.0 3.1 Discounted Cash Flow Forward Market Price (a) (c) (13.61) 9.08 0.02 Total $ 197.5 $ 155.7 December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (in millions) Energy Contracts $ 213.5 $ 169.7 Discounted Cash Flow Forward Market Price (a) (c) $ 5.33 $ 100.47 $ 32.73 Natural Gas Contracts — 1.7 Discounted Cash Flow Forward Market Price (b) (c) 2.18 2.77 2.40 FTRs 42.8 3.4 Discounted Cash Flow Forward Market Price (a) (c) (15.08) 9.66 0.19 Other Investments 31.8 — Black-Scholes Model Liquidity Adjustment (d) 10 % 20 % 15 % Total $ 288.1 $ 174.8 APCo Significant Unobservable Inputs March 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ 0.4 $ 0.5 Discounted Cash Flow Forward Market Price $ 10.92 $ 44.29 $ 25.13 FTRs 6.7 — Discounted Cash Flow Forward Market Price 0.08 4.99 0.99 Total $ 7.1 $ 0.5 December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ 1.0 $ 0.6 Discounted Cash Flow Forward Market Price $ 10.84 $ 41.09 $ 25.08 FTRs 18.9 — Discounted Cash Flow Forward Market Price 0.04 5.61 1.13 Total $ 19.9 $ 0.6 I&M Significant Unobservable Inputs March 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ 0.3 $ 0.3 Discounted Cash Flow Forward Market Price $ 10.92 $ 44.29 $ 25.13 FTRs 0.8 0.1 Discounted Cash Flow Forward Market Price (2.29) 3.66 0.33 Total $ 1.1 $ 0.4 December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ 0.6 $ 0.3 Discounted Cash Flow Forward Market Price $ 10.84 $ 41.09 $ 25.08 FTRs 1.9 0.1 Discounted Cash Flow Forward Market Price (1.96) 3.69 0.33 Total $ 2.5 $ 0.4 OPCo Significant Unobservable Inputs March 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ — $ 104.0 Discounted Cash Flow Forward Market Price $ 15.08 $ 49.09 $ 27.79 December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ — $ 110.3 Discounted Cash Flow Forward Market Price $ 16.19 $ 46.98 $ 28.30 PSO Significant Unobservable Inputs March 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) FTRs $ 5.5 $ — Discounted Cash Flow Forward Market Price $ (13.61) $ 2.04 $ (3.01) December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) FTRs $ 10.3 $ — Discounted Cash Flow Forward Market Price $ (6.93) $ 0.48 $ (1.93) SWEPCo Significant Unobservable Inputs March 31, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (c) (in millions) Natural Gas Contracts $ — $ 0.9 Discounted Cash Flow Forward Market Price (b) $ 2.24 $ 2.92 $ 2.50 FTRs 1.4 — Discounted Cash Flow Forward Market Price (a) (13.61) 2.04 (3.01) Total $ 1.4 $ 0.9 December 31, 2020 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (c) (in millions) Natural Gas Contracts $ — $ 1.7 Discounted Cash Flow Forward Market Price (b) $ 2.18 $ 2.77 $ 2.41 FTRs 3.3 — Discounted Cash Flow Forward Market Price (a) (6.93) 0.48 (1.93) Total $ 3.3 $ 1.7 (a) Represents market prices in dollars per MWh. (b) Represents market prices in dollars per MMBtu. (c) The weighted average is the product of the forward market price of the underlying commodity and volume weighted by term. (d) Represents percentage discount applied to the publically available share price.
Sensitivity of Fair Value Measurements	Uncertainty of Fair Value Measurements Significant Unobservable Input Position Change in Input Impact on Fair Value Forward Market Price Buy Increase (Decrease) Higher (Lower) Forward Market Price Sell Increase (Decrease) Lower (Higher) Liquidity Adjustment Buy Increase (Decrease) Lower (Higher)

Income Taxes (Tables)

Income Taxes (Tables)	3 Months Ended
	Mar. 31, 2021
Schedule of Effective Income Tax Rate Reconciliation	Three Months Ended March 31, 2021 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo U.S. Federal Statutory Rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % Increase (decrease) due to: State Income Tax, net of Federal Benefit 2.3 % 1.4 % 2.7 % 3.2 % 1.3 % 0.7 % 4.7 % (0.8) % Tax Reform Excess ADIT Reversal (9.2) % (7.8) % 0.3 % (18.0) % (17.9) % (9.7) % (24.7) % (5.9) % Production and Investment Tax Credits (5.5) % (0.3) % — % — % (1.7) % — % (8.2) % (5.1) % Flow Through 0.3 % 0.3 % 0.2 % 1.6 % (1.0) % 1.1 % 0.6 % (0.7) % AFUDC Equity (0.9) % (1.4) % (1.7) % (1.1) % (0.2) % (1.1) % (0.5) % (0.4) % Parent Company Loss Benefit — % — % (1.9) % (2.9) % (2.5) % — % — % — % Discrete Tax Adjustments 0.5 % — % — % — % — % (4.0) % — % — % Other 0.1 % 0.1 % 0.1 % 0.1 % — % 0.2 % (0.9) % 0.1 % Effective Income Tax Rate 8.6 % 13.3 % 20.7 % 3.9 % (1.0) % 8.2 % (8.0) % 8.2 % Three Months Ended March 31, 2020 AEP AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo U.S. Federal Statutory Rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % Increase (decrease) due to: State Income Tax, net of Federal Benefit 2.5 % 1.5 % 2.9 % 3.0 % 3.2 % 0.7 % 4.6 % 2.7 % Tax Reform Excess ADIT Reversal (9.4) % (6.2) % 0.4 % (13.0) % (19.6) % (10.2) % (23.1) % (94.7) % Production and Investment Tax Credits (4.3) % (0.4) % — % — % (1.9) % — % (1.3) % (0.5) % Flow Through 0.5 % 0.1 % 0.5 % 1.5 % 0.2 % 1.0 % 0.6 % (1.0) % AFUDC Equity (1.4) % (2.6) % (2.6) % (1.0) % (1.1) % (1.0) % (0.7) % (0.4) % Parent Company Loss Benefit — % (0.2) % (0.9) % (3.3) % (3.9) % (0.1) % (2.2) % (2.4) % Discrete Tax Adjustments — % — % — % — % 2.7 % — % — % — % Other (0.4) % 0.3 % — % 0.1 % (0.2) % — % 0.1 % 7.2 % Effective Income Tax Rate 8.5 % 13.5 % 21.3 % 8.3 % 0.4 % 11.4 % (1.0) % (68.1) %

Financing Activities (Tables)

Financing Activities (Tables)	3 Months Ended
	Mar. 31, 2021
Long-term Debt	Type of Debt March 31, 2021 December 31, 2020 (in millions) Senior Unsecured Notes $ 25,919.8 $ 25,116.1 Pollution Control Bonds 1,937.0 1,936.7 Notes Payable 213.9 239.1 Securitization Bonds 693.0 716.4 Spent Nuclear Fuel Obligation (a) 281.2 281.2 Junior Subordinated Notes (b) 1,626.0 1,624.1 Other Long-term Debt 1,674.1 1,158.9 Total Long-term Debt Outstanding 32,345.0 31,072.5 Long-term Debt Due Within One Year 2,130.2 2,086.1 Long-term Debt $ 30,214.8 $ 28,986.4 (a) Pursuant to the Nuclear Waste Policy Act of 1982, I&M, a nuclear licensee, has an obligation to the United States Department of Energy for SNF disposal. The obligation includes a one-time fee for nuclear fuel consumed prior to April 7, 1983. Trust fund assets related to this obligation were $326 million and $324 million as of March 31, 2021 and December 31, 2020, respectively, and are included in Spent Nuclear Fuel and Decommissioning Trusts on the balance sheets. (b) See “Equity Units” section below for additional information.
Long-term Debt Issuances	Principal Interest Company Type of Debt Amount (a) Rate Due Date Issuances: (in millions) (%) APCo Senior Unsecured Notes $ 500.0 2.70 2031 OPCo Senior Unsecured Notes 450.0 1.63 2031 PSO Other Long-term Debt 500.0 Variable 2022 SWEPCo Senior Unsecured Notes 500.0 1.65 2026 Non-Registrant: Transource Energy Other Long-term Debt 14.6 Variable 2023 Total Issuances $ 1,964.6 (a) Amounts indicated on the statements of cash flows are net of issuance costs and premium or discount and will not tie to the issuance amounts.
Retirements and Principal Payments	Principal Interest Company Type of Debt Amount Paid Rate Due Date Retirements and Principal Payments: (in millions) (%) AEP Texas Securitization Bonds $ 11.2 2.06 2025 APCo Senior Unsecured Notes 350.0 4.60 2021 APCo Securitization Bonds 12.5 2.01 2023 I&M Notes Payable 1.5 Variable 2021 I&M Notes Payable 1.5 Variable 2022 I&M Notes Payable 3.4 Variable 2022 I&M Notes Payable 4.8 Variable 2023 I&M Notes Payable 5.9 Variable 2024 I&M Notes Payable 6.5 Variable 2025 I&M Other Long-term Debt 0.5 6.00 2025 PSO Senior Unsecured Notes 250.0 4.40 2021 PSO Other Long-term Debt 0.1 3.00 2027 SWEPCo Notes Payable 1.6 4.58 2032 Non-Registrant: Transource Energy Senior Unsecured Notes 1.2 2.75 2050 Total Retirements and Principal Payments $ 650.7
Utility Money Pool Participants' Money Pool Activity and Authorized Borrowing Limits	Maximum Average Net Loans to Borrowings Maximum Borrowings Average (Borrowings) from Authorized from the Loans to the from the Loans to the the Utility Money Short-term Utility Utility Utility Utility Pool as of Borrowing Company Money Pool Money Pool Money Pool Money Pool March 31, 2021 Limit (in millions) AEP Texas $ 295.5 $ — $ 197.8 $ — $ (284.0) $ 500.0 AEPTCo 330.6 3.5 230.1 1.6 (227.8) 820.0 (a) APCo 27.8 616.9 13.2 152.4 261.1 500.0 I&M 166.5 13.3 118.2 13.3 (111.3) 500.0 OPCo 259.2 222.4 175.1 107.4 0.5 500.0 PSO 262.0 210.1 130.3 122.0 (245.7) 300.0 SWEPCo 280.3 156.4 169.3 142.0 (86.9) 350.0 (a) Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions.
Nonutility Money Pool Activity	Maximum Loans Average Loans Loans to the Nonutility to the Nonutility to the Nonutility Money Pool as of Company Money Pool Money Pool March 31, 2021 (in millions) AEP Texas $ 7.1 $ 6.9 $ 6.8 SWEPCo 2.1 2.1 2.1
Direct Borrowing Activity	Maximum Maximum Average Average Borrowings from Loans to Authorized Borrowings Loans Borrowings Loans AEP as of AEP as of Short-term from AEP to AEP from AEP to AEP March 31, 2021 March 31, 2021 Borrowing Limit (in millions) $ 1.2 $ 220.6 $ 1.2 $ 148.7 $ 1.2 $ 105.8 $ 50.0 (a) (a) Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions.
Maximum and Minimum Interest Rates for Funds Either Borrowed from or Loaned to Utility Money Pool	Three Months Ended March 31, 2021 2020 Maximum Interest Rate 0.40 % 2.24 % Minimum Interest Rate 0.25 % 1.76 %
Average Interest Rates for Funds Borrowed from and Loaned to Utility Money Pool	Average Interest Rate for Funds Average Interest Rate for Funds Borrowed from the Utility Money Pool Loaned to the Utility Money Pool for Three Months Ended March 31, for Three Months Ended March 31, Company 2021 2020 2021 2020 AEP Texas 0.31 % 2.05 % — % 1.97 % AEPTCo 0.31 % 1.95 % 0.28 % 1.91 % APCo 0.28 % 1.95 % 0.36 % 1.94 % I&M 0.31 % 1.95 % 0.30 % 1.94 % OPCo 0.29 % 1.90 % 0.29 % 2.06 % PSO 0.33 % 2.00 % 0.28 % 1.95 % SWEPCo 0.28 % 1.95 % 0.38 % — %
Maximum Minimum Average Interest Rates for Funds Borrowed from Loaned to Nonutility Money Pool	Three Months Ended March 31, 2021 Three Months Ended March 31, 2020 Maximum Minimum Average Maximum Minimum Average Interest Rate Interest Rate Interest Rate Interest Rate Interest Rate Interest Rate for Funds for Funds for Funds for Funds for Funds for Funds Loaned to Loaned to Loaned to Loaned to Loaned to Loaned to the Nonutility the Nonutility the Nonutility the Nonutility the Nonutility the Nonutility Company Money Pool Money Pool Money Pool Money Pool Money Pool Money Pool AEP Texas 0.40 % 0.25 % 0.30 % 2.24 % 1.76 % 1.94 % SWEPCo 0.40 % 0.25 % 0.30 % 2.24 % 1.76 % 1.94 %
Maximum Minimum and Average Interest Rates for Funds Borrowed from and Loaned to AEP	Maximum Minimum Maximum Minimum Average Average Interest Rate Interest Rate Interest Rate Interest Rate Interest Rate Interest Rate Three Months for Funds for Funds for Funds for Funds for Funds for Funds Ended Borrowed Borrowed Loaned Loaned Borrowed Loaned March 31, from AEP from AEP to AEP to AEP from AEP to AEP 2021 0.86 % 0.25 % 0.86 % 0.25 % 0.31 % 0.31 % 2020 2.24 % 1.76 % 2.24 % 1.76 % 1.94 % 1.94 %
Short Term Debt	March 31, 2021 December 31, 2020 Outstanding Interest Outstanding Interest Company Type of Debt Amount Rate (a) Amount Rate (a) (dollars in millions) AEP Securitized Debt for Receivables (b) $ 669.0 0.20 % $ 592.0 0.85 % AEP Commercial Paper 1,874.4 0.27 % 1,852.3 0.29 % AEP 364-Day Term Loan 500.0 0.71 % — — % SWEPCo Notes Payable 5.0 2.75 % 35.0 2.55 % Total Short-term Debt $ 3,048.4 $ 2,479.3 (a) Weighted-average rate. (b) Amount of securitized debt for receivables as accounted for under the “Transfers and Servicing” accounting guidance.
Comparative Accounts Receivable Information	Three Months Ended March 31, 2021 2020 (dollars in millions) Effective Interest Rates on Securitization of Accounts Receivable 0.20 % 1.75 % Net Uncollectible Accounts Receivable Written-Off $ 9.3 $ 4.2
Customer Accounts Receivable Managed Portfolio	March 31, 2021 December 31, 2020 (in millions) Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts $ 871.4 $ 958.4 Short-term – Securitized Debt of Receivables 669.0 592.0 Delinquent Securitized Accounts Receivable 67.7 62.3 Bad Debt Reserves Related to Securitization 47.6 60.0 Unbilled Receivables Related to Securitization 211.2 296.8
Accounts Receivable and Accrued Unbilled Revenues	Company March 31, 2021 December 31, 2020 (in millions) APCo $ 132.6 $ 136.0 I&M 154.0 170.5 OPCo 360.2 398.8 PSO 76.2 85.0 SWEPCo 132.9 158.6
Fees Paid to AEP Credit for Customer Accounts Receivable Sold	Three Months Ended March 31, Company 2021 2020 (in millions) APCo $ 1.2 $ 1.7 I&M 1.6 2.8 OPCo 1.3 4.8 PSO 0.7 1.3 SWEPCo 1.5 2.1
Proceeds on Sale of Receivables to AEP Credit	Three Months Ended March 31, Company 2021 2020 (in millions) APCo $ 362.4 $ 352.6 I&M 478.8 471.4 OPCo 601.3 570.3 PSO 284.9 294.9 SWEPCo 384.4 365.6

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	3 Months Ended
	Mar. 31, 2021
Disaggregated Revenues from Contracts with Customers	Three Months Ended March 31, 2021 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation & Marketing Corporate and Other Reconciling Adjustments AEP Consolidated (in millions) Retail Revenues: Residential Revenues $ 1,046.1 $ 548.1 $ — $ — $ — $ — $ 1,594.2 Commercial Revenues 486.2 239.2 — — — — 725.4 Industrial Revenues 484.0 85.7 — — — (0.2) 569.5 Other Retail Revenues 37.8 10.0 — — — — 47.8 Total Retail Revenues 2,054.1 883.0 — — — (0.2) 2,936.9 Wholesale and Competitive Retail Revenues: Generation Revenues 352.6 — — 40.5 — — 393.1 Transmission Revenues (a) 89.0 130.5 360.4 — — (299.3) 280.6 Renewable Generation Revenues (b) — — — 22.4 — (0.7) 21.7 Retail, Trading and Marketing Revenues (c) — — — 569.8 1.2 (31.8) 539.2 Total Wholesale and Competitive Retail Revenues 441.6 130.5 360.4 632.7 1.2 (331.8) 1,234.6 Other Revenues from Contracts with Customers (b) 42.3 52.1 4.6 1.5 8.6 (21.2) 87.9 Total Revenues from Contracts with Customers 2,538.0 1,065.6 365.0 634.2 9.8 (353.2) 4,259.4 Other Revenues: Alternative Revenues (b) (0.7) 17.2 12.0 — — (11.6) 16.9 Other Revenues (b) — 5.3 — — 3.1 (3.6) 4.8 Total Other Revenues (0.7) 22.5 12.0 — 3.1 (15.2) 21.7 Total Revenues $ 2,537.3 $ 1,088.1 $ 377.0 $ 634.2 $ 12.9 $ (368.4) $ 4,281.1 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $273 million. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $32 million. The remaining affiliated amounts were immaterial. Three Months Ended March 31, 2020 Vertically Integrated Utilities Transmission and Distribution Utilities AEP Transmission Holdco Generation & Marketing Corporate and Other Reconciling Adjustments AEP Consolidated (in millions) Retail Revenues: Residential Revenues $ 915.1 $ 521.3 $ — $ — $ — $ — $ 1,436.4 Commercial Revenues 489.4 276.9 — — — — 766.3 Industrial Revenues 518.2 97.8 — — — (0.2) 615.8 Other Retail Revenues 39.9 11.8 — — — — 51.7 Total Retail Revenues 1,962.6 907.8 — — — (0.2) 2,870.2 Wholesale and Competitive Retail Revenues: Generation Revenues 140.4 — — 44.1 — — 184.5 Transmission Revenues (a) 79.9 114.1 309.8 — — (263.0) 240.8 Renewable Generation Revenues (b) — — — 17.2 — (0.6) 16.6 Retail, Trading and Marketing Revenues (c) — — — 358.7 (6.0) (29.4) 323.3 Total Wholesale and Competitive Retail Revenues 220.3 114.1 309.8 420.0 (6.0) (293.0) 765.2 Other Revenues from Contracts with Customers (b) 43.6 36.4 3.7 0.3 28.1 (40.6) 71.5 Total Revenues from Contracts with Customers 2,226.5 1,058.3 313.5 420.3 22.1 (333.8) 3,706.9 Other Revenues: Alternative Revenues (b) 0.2 19.3 (3.3) — — 4.5 20.7 Other Revenues (b) — 29.3 — 18.3 (2.2) (25.5) 19.9 Total Other Revenues 0.2 48.6 (3.3) 18.3 (2.2) (21.0) 40.6 Total Revenues $ 2,226.7 $ 1,106.9 $ 310.2 $ 438.6 $ 19.9 $ (354.8) $ 3,747.5 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $239 million. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $35 million. The remaining affiliated amounts were immaterial. Three Months Ended March 31, 2021 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 122.7 $ — $ 416.9 $ 213.6 $ 425.3 $ 136.8 $ 166.3 Commercial Revenues 80.7 — 130.2 113.6 158.5 72.7 112.9 Industrial Revenues 26.5 — 130.9 128.4 59.2 56.4 70.6 Other Retail Revenues 6.8 — 16.9 1.4 3.2 15.7 2.3 Total Retail Revenues 236.7 — 694.9 457.0 646.2 281.6 352.1 Wholesale Revenues: Generation Revenues (a) — — 72.4 79.6 — (7.1) 228.6 Transmission Revenues (b) 112.0 345.2 34.2 8.3 18.5 9.4 28.9 Total Wholesale Revenues 112.0 345.2 106.6 87.9 18.5 2.3 257.5 Other Revenues from Contracts with Customers (c) 16.2 4.6 13.1 20.7 36.0 12.6 6.4 Total Revenues from Contracts with Customers 364.9 349.8 814.6 565.6 700.7 296.5 616.0 Other Revenues: Alternative Revenues (d) (0.7) 11.9 2.2 (1.1) 17.9 (0.4) 0.1 Other Revenues (d) — — 0.2 — 5.3 — — Total Other Revenues (0.7) 11.9 2.4 (1.1) 23.2 (0.4) 0.1 Total Revenues $ 364.2 $ 361.7 $ 817.0 $ 564.5 $ 723.9 $ 296.1 $ 616.1 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $32 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $270 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $16 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. Three Months Ended March 31, 2020 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 132.9 $ — $ 357.5 $ 201.3 $ 388.4 $ 128.5 $ 131.6 Commercial Revenues 112.8 — 132.3 122.2 164.0 76.1 105.6 Industrial Revenues 35.2 — 141.1 137.8 62.7 61.3 79.8 Other Retail Revenues 8.4 — 17.9 1.8 3.4 16.6 2.0 Total Retail Revenues 289.3 — 648.8 463.1 618.5 282.5 319.0 Wholesale Revenues: Generation Revenues (a) — — 54.1 78.4 — 1.9 34.1 Transmission Revenues (b) 96.9 298.2 30.4 7.4 17.1 7.8 25.4 Total Wholesale Revenues 96.9 298.2 84.5 85.8 17.1 9.7 59.5 Other Revenues from Contracts with Customers (c) 7.9 3.4 17.2 21.0 28.6 4.7 5.8 Total Revenues from Contracts with Customers 394.1 301.6 750.5 569.9 664.2 296.9 384.3 Other Revenues: Alternative Revenues (d) (0.7) (6.0) (1.1) 0.4 20.0 0.4 1.6 Other Revenues (d) 30.2 — — — 6.1 — — Total Other Revenues 29.5 (6.0) (1.1) 0.4 26.1 0.4 1.6 Total Revenues $ 423.6 $ 295.6 $ 749.4 $ 570.3 $ 690.3 $ 297.3 $ 385.9 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $33 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $235 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $16 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues.
Fixed Performance Obligations	Company 2021 2022-2023 2024-2025 After 2025 Total (in millions) AEP $ 873.4 $ 171.3 $ 160.4 $ 161.5 $ 1,366.6 AEP Texas 349.0 — — — 349.0 AEPTCo 1,001.3 — — — 1,001.3 APCo 130.4 32.3 24.3 11.7 198.7 I&M 25.8 8.8 8.8 4.4 47.8 OPCo 49.7 — — 0.1 49.8 PSO 14.8 — — — 14.8 SWEPCo 41.6 — — — 41.6
Affiliated Accounts Receivable Contracts with Customers	Company March 31, 2021 December 31, 2020 (in millions) AEPTCo $ 92.3 $ 81.0 APCo 52.6 52.7 I&M 31.4 34.8 OPCo 47.8 45.9 PSO 14.9 7.8 SWEPCo 22.8 11.2

Significant Accounting Matter_3

Significant Accounting Matters (Details) - USD ($) $ / shares in Units, $ in Millions		3 Months Ended
		Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2020	Dec. 31, 2019
Amounts Attributable to AEP Common Shareholders
Earnings Attributable to Common Shareholders		$ 575	$ 495.2
Weighted Average Number of Basic AEP Common Shares Outstanding		497,058,635	494,596,869
Total Basic Earnings Per Share Attributable to AEP Common Shareholders		$ 1.16	$ 1
Weighted Average Dilutive Effect of:
Weighted Average Number of Diluted AEP Common Shares Outstanding		498,164,219	496,608,918
Total Diluted Earnings Per Share Attributable to AEP Common Shareholders		$ 1.15	$ 1
Organization and Summary of Significant Accounting Policies (Textuals)
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount		0	697,000
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		$ 273.2		$ 392.7
Restricted Cash		50.8		45.6
Total Cash, Cash Equivalents and Restricted Cash		324	$ 1,670.8	438.3	$ 432.6
Proceeds from Issuance of Debt	[1]	1,964.6
AEP Texas Inc. [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		0.1		0.1
Restricted Cash		39.3		28.7
Total Cash, Cash Equivalents and Restricted Cash		39.4	100.2	28.8	157.8
AEP Transmission Co [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		0	0	0	0
Appalachian Power Co [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		4.8		5.8
Restricted Cash		11.6		16.9
Total Cash, Cash Equivalents and Restricted Cash		16.4	18.5	22.7	26.8
Indiana Michigan Power Co [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		2.8	1.8	3.3	2
Ohio Power Co [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		6.1		7.4
Total Cash, Cash Equivalents and Restricted Cash		6.1	3.1	7.4	3.7
Public Service Co Of Oklahoma [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		2.4	1.1	2.6	1.5
Southwestern Electric Power Co [Member]
Amounts Attributable to AEP Common Shareholders
Earnings Attributable to Common Shareholders		62.4	15.1
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		$ 18.2	$ 1.4	$ 13.2	$ 1.6
Restricted Stock Units and Performance Share Units [Member]
Weighted Average Dilutive Effect of:
Weighted Average Dilutive Effect of Shares		1,100,000	2,000,000
Dilutive Securities, Effect on Basic Earnings Per Share		$ (0.01)	$ 0
[1]	Amounts indicated on the statements of cash flows are net of issuance costs and premium or discount and will not tie to the issuance amounts.

Comprehensive Income (Details)

Comprehensive Income (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2021		Mar. 31, 2020
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		$ (85.1)		$ (147.7)
Change in Fair Value Recognized in AOCI		190.4		(108)
Commodity
Generation & Marketing Revenues		4,281.1		3,747.5
Interest Rate
Interest Expense		290.2		292.1
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(172.2)		49.6
Income Tax (Expense) Benefit		54.5		46.5
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(136.1)		39.2
Net Current Period Other Comprehensive Income (Loss)		54.3		(68.8)
Ending Balance in AOCI		(30.8)		(216.5)
Pension and OPEB [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		23		(32.7)
Change in Fair Value Recognized in AOCI		0		0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(2.5)		(2.3)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(2)		(1.8)
Net Current Period Other Comprehensive Income (Loss)		(2)		(1.8)
Ending Balance in AOCI		21		(34.5)
Accumulated Other Comprehensive Income [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Net Current Period Other Comprehensive Income (Loss)		54.3		(68.8)
Commodity [Member] | Cash Flow Hedges [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(60.6)		(103.5)
Change in Fair Value Recognized in AOCI		177.3		(65.3)
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(171.2)		51
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(135.2)		40.3
Net Current Period Other Comprehensive Income (Loss)		42.1		(25)
Ending Balance in AOCI		(18.5)		(128.5)
Interest Rate [Member] | Cash Flow Hedges [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(47.5)		(11.5)
Change in Fair Value Recognized in AOCI		13.1	[1]	(42.7)
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		1.5		0.9
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		1.1		0.7
Net Current Period Other Comprehensive Income (Loss)		14.2		(42)
Ending Balance in AOCI		(33.3)		(53.5)
Generation and Marketing [Member]
Commodity
Generation & Marketing Revenues		601.7		408.4
Reclassifications from Accumulated Other Comprehensive Income [Member]
Interest Rate
Interest Expense	[2]	1.5		0.9
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(4.8)		(4.9)
Amortization of Actuarial (Gains) Losses		2.3		2.6
Income Tax (Expense) Benefit		(36.1)		10.4
Reclassifications from Accumulated Other Comprehensive Income [Member] | Pension and OPEB [Member]
Interest Rate
Interest Expense	[2]	0		0
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(4.8)		(4.9)
Amortization of Actuarial (Gains) Losses		2.3		2.6
Income Tax (Expense) Benefit		(0.5)		(0.5)
Reclassifications from Accumulated Other Comprehensive Income [Member] | Commodity [Member] | Cash Flow Hedges [Member]
Interest Rate
Interest Expense	[2]	0		0
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		0		0
Amortization of Actuarial (Gains) Losses		0		0
Income Tax (Expense) Benefit		(36)		10.7
Reclassifications from Accumulated Other Comprehensive Income [Member] | Interest Rate [Member] | Cash Flow Hedges [Member]
Interest Rate
Interest Expense	[2]	1.5		0.9
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		0		0
Amortization of Actuarial (Gains) Losses		0		0
Income Tax (Expense) Benefit		0.4		0.2
Reclassifications from Accumulated Other Comprehensive Income [Member] | Generation and Marketing [Member]
Commodity
Generation & Marketing Revenues	[2]	0.8		(0.1)
Reclassifications from Accumulated Other Comprehensive Income [Member] | Generation and Marketing [Member] | Pension and OPEB [Member]
Commodity
Generation & Marketing Revenues	[2]	0		0
Reclassifications from Accumulated Other Comprehensive Income [Member] | Generation and Marketing [Member] | Commodity [Member] | Cash Flow Hedges [Member]
Commodity
Generation & Marketing Revenues	[2]	0.8		(0.1)
Reclassifications from Accumulated Other Comprehensive Income [Member] | Generation and Marketing [Member] | Interest Rate [Member] | Cash Flow Hedges [Member]
Commodity
Generation & Marketing Revenues	[2]	0		0
Reclassifications from Accumulated Other Comprehensive Income [Member] | Purchased Electricity for Resale [Member]
Commodity
Purchased Electricity for Resale	[2]	(172)		51.1
Reclassifications from Accumulated Other Comprehensive Income [Member] | Purchased Electricity for Resale [Member] | Pension and OPEB [Member]
Commodity
Purchased Electricity for Resale	[2]	0		0
Reclassifications from Accumulated Other Comprehensive Income [Member] | Purchased Electricity for Resale [Member] | Commodity [Member] | Cash Flow Hedges [Member]
Commodity
Purchased Electricity for Resale	[2]	(172)		51.1
Reclassifications from Accumulated Other Comprehensive Income [Member] | Purchased Electricity for Resale [Member] | Interest Rate [Member] | Cash Flow Hedges [Member]
Commodity
Purchased Electricity for Resale	[2]	0		0
Apple Blossom and Black Oak [Member] | Interest Rate [Member] | Cash Flow Hedges [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Change in Fair Value Recognized in AOCI		4		5
AEP Texas Inc. [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(8.9)		(12.8)
Change in Fair Value Recognized in AOCI		0.1		0
Interest Rate
Interest Expense		43		42.5
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0.3		0.4
Income Tax (Expense) Benefit		7.1		7.4
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0.2		0.3
Net Current Period Other Comprehensive Income (Loss)		0.3		0.3
Ending Balance in AOCI		(8.6)		(12.5)
AEP Texas Inc. [Member] | Pension and OPEB [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(6.6)		(9.4)
Change in Fair Value Recognized in AOCI		0		0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0		0
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0		0
Net Current Period Other Comprehensive Income (Loss)		0		0
Ending Balance in AOCI		(6.6)		(9.4)
AEP Texas Inc. [Member] | Accumulated Other Comprehensive Income [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Net Current Period Other Comprehensive Income (Loss)		0.3		0.3
AEP Texas Inc. [Member] | Interest Rate [Member] | Cash Flow Hedges [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(2.3)		(3.4)
Change in Fair Value Recognized in AOCI		0.1		0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0.3		0.4
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0.2		0.3
Net Current Period Other Comprehensive Income (Loss)		0.3		0.3
Ending Balance in AOCI		(2)		(3.1)
AEP Texas Inc. [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member]
Interest Rate
Interest Expense	[2]	0.3		0.4
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit		0.1		0.1
AEP Texas Inc. [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member] | Pension and OPEB [Member]
Interest Rate
Interest Expense	[2]	0		0
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit		0		0
AEP Texas Inc. [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member] | Interest Rate [Member] | Cash Flow Hedges [Member]
Interest Rate
Interest Expense	[2]	0.3		0.4
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit		0.1		0.1
Appalachian Power Co [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		7.2		5
Change in Fair Value Recognized in AOCI		9.3		(3.9)
Interest Rate
Interest Expense		54.9		53.1
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(1.8)		(1.6)
Income Tax (Expense) Benefit		5		10.4
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(1.4)		(1.2)
Net Current Period Other Comprehensive Income (Loss)		7.9		(5.1)
Ending Balance in AOCI		15.1		(0.1)
Appalachian Power Co [Member] | Pension and OPEB [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		8		4.1
Change in Fair Value Recognized in AOCI		0		0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(1.4)		(1.2)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(1.1)		(0.9)
Net Current Period Other Comprehensive Income (Loss)		(1.1)		(0.9)
Ending Balance in AOCI		6.9		3.2
Appalachian Power Co [Member] | Accumulated Other Comprehensive Income [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Net Current Period Other Comprehensive Income (Loss)		7.9		(5.1)
Appalachian Power Co [Member] | Interest Rate [Member] | Cash Flow Hedges [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(0.8)		0.9
Change in Fair Value Recognized in AOCI		9.3		(3.9)
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(0.4)		(0.4)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(0.3)		(0.3)
Net Current Period Other Comprehensive Income (Loss)		9		(4.2)
Ending Balance in AOCI		8.2		(3.3)
Appalachian Power Co [Member] | Purchased Electricity for Resale [Member]
Commodity
Purchased Electricity for Resale		90.1		122.6
Appalachian Power Co [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member]
Interest Rate
Interest Expense	[2]	(0.4)		(0.4)
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(1.4)		(1.3)
Amortization of Actuarial (Gains) Losses				0.1
Income Tax (Expense) Benefit		(0.4)		(0.4)
Appalachian Power Co [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member] | Pension and OPEB [Member]
Interest Rate
Interest Expense	[2]	0		0
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(1.4)		(1.3)
Amortization of Actuarial (Gains) Losses				0.1
Income Tax (Expense) Benefit		(0.3)		(0.3)
Appalachian Power Co [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member] | Interest Rate [Member] | Cash Flow Hedges [Member]
Interest Rate
Interest Expense	[2]	(0.4)		(0.4)
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		0		0
Amortization of Actuarial (Gains) Losses				0
Income Tax (Expense) Benefit		(0.1)		(0.1)
Indiana Michigan Power Co [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(7)		(11.6)
Change in Fair Value Recognized in AOCI		0		0
Interest Rate
Interest Expense		27.3		30.7
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0.6		0.5
Income Tax (Expense) Benefit		(0.7)		0.4
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0.5		0.4
Net Current Period Other Comprehensive Income (Loss)		0.5		0.4
Ending Balance in AOCI		(6.5)		(11.2)
Indiana Michigan Power Co [Member] | Pension and OPEB [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		1.3		(1.7)
Change in Fair Value Recognized in AOCI		0		0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0		0
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0		0
Net Current Period Other Comprehensive Income (Loss)		0		0
Ending Balance in AOCI		1.3		(1.7)
Indiana Michigan Power Co [Member] | Accumulated Other Comprehensive Income [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Net Current Period Other Comprehensive Income (Loss)		0.5		0.4
Indiana Michigan Power Co [Member] | Interest Rate [Member] | Cash Flow Hedges [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(8.3)		(9.9)
Change in Fair Value Recognized in AOCI		0		0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0.6		0.5
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0.5		0.4
Net Current Period Other Comprehensive Income (Loss)		0.5		0.4
Ending Balance in AOCI		(7.8)		(9.5)
Indiana Michigan Power Co [Member] | Purchased Electricity for Resale [Member]
Commodity
Purchased Electricity for Resale		47.3		50.1
Indiana Michigan Power Co [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member]
Interest Rate
Interest Expense	[2]	0.6		0.5
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(0.2)		(0.2)
Amortization of Actuarial (Gains) Losses		0.2		0.2
Income Tax (Expense) Benefit		0.1		0.1
Indiana Michigan Power Co [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member] | Pension and OPEB [Member]
Interest Rate
Interest Expense	[2]	0		0
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(0.2)		(0.2)
Amortization of Actuarial (Gains) Losses		0.2		0.2
Income Tax (Expense) Benefit		0		0
Indiana Michigan Power Co [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member] | Interest Rate [Member] | Cash Flow Hedges [Member]
Interest Rate
Interest Expense	[2]	0.6		0.5
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		0		0
Amortization of Actuarial (Gains) Losses		0		0
Income Tax (Expense) Benefit		0.1		0.1
Ohio Power Co [Member]
Interest Rate
Interest Expense		31.6		28.9
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit		6.1		9.7
Ohio Power Co [Member] | Interest Rate [Member] | Cash Flow Hedges [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		0		0
Change in Fair Value Recognized in AOCI		0		0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0		0
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0		0
Net Current Period Other Comprehensive Income (Loss)		0		0
Ending Balance in AOCI		0		0
Ohio Power Co [Member] | Purchased Electricity for Resale [Member]
Commodity
Purchased Electricity for Resale		175.3		149.1
Ohio Power Co [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member] | Interest Rate [Member] | Cash Flow Hedges [Member]
Interest Rate
Interest Expense	[2]	0		0
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit		0		0
Public Service Co Of Oklahoma [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		0.1
Interest Rate
Interest Expense		14.4		15.8
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit		0.2		0.1
Net Current Period Other Comprehensive Income (Loss)		(0.1)		(0.2)
Ending Balance in AOCI		0
Public Service Co Of Oklahoma [Member] | Accumulated Other Comprehensive Income [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Net Current Period Other Comprehensive Income (Loss)		(0.1)		(0.2)
Public Service Co Of Oklahoma [Member] | Interest Rate [Member] | Cash Flow Hedges [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		0.1		1.1
Change in Fair Value Recognized in AOCI		0		0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(0.1)		(0.3)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(0.1)		(0.2)
Net Current Period Other Comprehensive Income (Loss)		(0.1)		(0.2)
Ending Balance in AOCI		0		0.9
Public Service Co Of Oklahoma [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member] | Interest Rate [Member] | Cash Flow Hedges [Member]
Interest Rate
Interest Expense	[2]	(0.1)		(0.3)
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit		0		(0.1)
Southwestern Electric Power Co [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		1.9		(1.3)
Change in Fair Value Recognized in AOCI		0		0
Interest Rate
Interest Expense		29.3		30.1
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0		0
Income Tax (Expense) Benefit		5.6		(6.2)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0		0
Net Current Period Other Comprehensive Income (Loss)		0		0
Ending Balance in AOCI		1.9		(1.3)
Southwestern Electric Power Co [Member] | Pension and OPEB [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		2.2		0.5
Change in Fair Value Recognized in AOCI		0		0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(0.5)		(0.5)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(0.4)		(0.4)
Net Current Period Other Comprehensive Income (Loss)		(0.4)		(0.4)
Ending Balance in AOCI		1.8		0.1
Southwestern Electric Power Co [Member] | Interest Rate [Member] | Cash Flow Hedges [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(0.3)		(1.8)
Change in Fair Value Recognized in AOCI		0		0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0.5		0.5
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0.4		0.4
Net Current Period Other Comprehensive Income (Loss)		0.4		0.4
Ending Balance in AOCI		0.1		(1.4)
Southwestern Electric Power Co [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member]
Interest Rate
Interest Expense	[2]	0.5		0.5
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(0.5)		(0.5)
Income Tax (Expense) Benefit		0		0
Southwestern Electric Power Co [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member] | Pension and OPEB [Member]
Interest Rate
Interest Expense	[2]	0		0
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(0.5)		(0.5)
Income Tax (Expense) Benefit		(0.1)		(0.1)
Southwestern Electric Power Co [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member] | Interest Rate [Member] | Cash Flow Hedges [Member]
Interest Rate
Interest Expense	[2]	0.5		0.5
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		0		0
Income Tax (Expense) Benefit		$ 0.1		$ 0.1
[1]	The change in fair value includes $4 million and $5 million related to AEP's investment in joint venture wind farms acquired as part of the purchase of Sempra Renewables LLC for the three months ended March 31, 2021 and 2020, respectively.
[2]	Amounts reclassified to the referenced line item on the statements of income.

Rate Matters Regulated Operatio

Rate Matters Regulated Operations (Details) - USD ($) $ in Millions		1 Months Ended	3 Months Ended
		Apr. 22, 2021	Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2020
Public Utilities, General Disclosures [Line Items]
Gross Investment Including CWIP			$ 23,186.5		$ 23,133.9
Accumulated Depreciation			20,916.8		20,411.4
Net Investment			64,696.1		63,901.6
Materials and Supplies			683.3		680.6
Regulatory Assets, Noncurrent			4,885.6		3,527
Customers			763		613.6
Proceeds from Issuance of Debt	[1]		1,964.6
February 2021 Storm Event
Public Utilities, General Disclosures [Line Items]
Capitalized Storm Costs			56.6
Incremental Other Operation and Maintenance Expenses			6
Deferred Storm Costs as a Regulated Asset			130.9
Total Estimated February 2021 Storm Restoration Expenditures			193.5
February 2021 Severe Storm Fuel Costs
Public Utilities, General Disclosures [Line Items]
Customers			88.4
Total Estimated 2021 February Winter Storm Fuel Costs			1,273.4
February 2021 Severe Storm Fuel Costs | 364 Day Term Loan
Public Utilities, General Disclosures [Line Items]
Proceeds from Issuance of Debt			500
AEP Texas Inc. [Member]
Public Utilities, General Disclosures [Line Items]
Accumulated Depreciation			1,565.9		1,529.3
Net Investment			9,975.8		9,813.6
Materials and Supplies			69.8		70
Regulatory Assets, Noncurrent			274.5		266.8
Customers			129.3		112.8
AEP Transmission Co [Member]
Public Utilities, General Disclosures [Line Items]
Accumulated Depreciation			623.6		572.8
Net Investment			11,070.4		10,772.8
Materials and Supplies			8.8		8.5
Regulatory Assets, Noncurrent			14		15.1
Customers			25.6		22.9
Capital Contribution from Member			124	$ 185
AEP Transmission Co [Member] | Additional Paid-in Capital [Member]
Public Utilities, General Disclosures [Line Items]
Capital Contribution from Member			124	$ 185
Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Gross Investment Including CWIP			6,643.9		6,633.7
Accumulated Depreciation			4,802		4,716.2
Net Investment			11,455.2		11,394.1
Materials and Supplies			101.2		99.6
Regulatory Assets, Noncurrent			727.1		686.3
Customers			146.4		142.8
Appalachian Power Co [Member] | Senior Unsecured Notes [Member]
Public Utilities, General Disclosures [Line Items]
Proceeds from Issuance of Debt	[1]		500
Appalachian Power Co [Member] | February 2021 Storm Event | Virginia
Public Utilities, General Disclosures [Line Items]
Capitalized Storm Costs			5.4
Incremental Other Operation and Maintenance Expenses			2.2
Deferred Storm Costs as a Regulated Asset			5.6
Total Estimated February 2021 Storm Restoration Expenditures			13.2
Appalachian Power Co [Member] | February 2021 Storm Event | West Virginia
Public Utilities, General Disclosures [Line Items]
Capitalized Storm Costs			19.6
Incremental Other Operation and Maintenance Expenses			0
Deferred Storm Costs as a Regulated Asset			39.1
Total Estimated February 2021 Storm Restoration Expenditures			58.7
Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Gross Investment Including CWIP			5,302.4		5,264.7
Accumulated Depreciation			3,647.3		3,552.5
Net Investment			7,063.2		7,052.3
Materials and Supplies			172.8		175.8
Regulatory Assets, Noncurrent			403.4		404.8
Customers			32.7		44
Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Accumulated Depreciation			2,385.4		2,350
Net Investment			7,565.7		7,452.1
Materials and Supplies			67.3		66.9
Regulatory Assets, Noncurrent			392.3		385.8
Customers			66.1		50
Ohio Power Co [Member] | Senior Unsecured Notes [Member]
Public Utilities, General Disclosures [Line Items]
Proceeds from Issuance of Debt	[1]		450
Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Gross Investment Including CWIP			1,481.7		1,480.7
Accumulated Depreciation			1,626		1,605.6
Net Investment			4,343.3		4,320
Materials and Supplies			53.3		54
Regulatory Assets, Noncurrent			1,067.6		375
Customers			37.7		30.8
Capital Contribution from Member			425
Public Service Co Of Oklahoma [Member] | Additional Paid-in Capital [Member]
Public Utilities, General Disclosures [Line Items]
Capital Contribution from Member			425
Public Service Co Of Oklahoma [Member] | Other Long Term Debt [Member]
Public Utilities, General Disclosures [Line Items]
Proceeds from Issuance of Debt	[1]		500
Public Service Co Of Oklahoma [Member] | February 2021 Severe Storm Fuel Costs
Public Utilities, General Disclosures [Line Items]
Customers			0
Total Estimated 2021 February Winter Storm Fuel Costs			688.7
Public Service Co Of Oklahoma [Member] | Northeastern Plant, Unit 3 | Generating Units Probable of Abandonment [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment			190.5
Accelerated Depreciation Regulatory Asset			114.8
Cost of Removal Regulatory Liability	[2]		$ 19.8
Expected Retirement Date	[3]		2026
Depreciation	[4]		$ 14.9
Public Service Co Of Oklahoma [Member] | February 2021 Severe Storm Fuel Costs
Public Utilities, General Disclosures [Line Items]
Capital Contribution from Member			425
Public Service Co Of Oklahoma [Member] | February 2021 Severe Storm Fuel Costs | Subsequent Event [Member]
Public Utilities, General Disclosures [Line Items]
Capital Contribution from Member		$ 125
Public Service Co Of Oklahoma [Member] | February 2021 Severe Storm Fuel Costs | Other Long Term Debt [Member]
Public Utilities, General Disclosures [Line Items]
Proceeds from Issuance of Debt			100
Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Gross Investment Including CWIP			4,679.8		4,681.4
Accumulated Depreciation			3,275.2		3,158.5
Net Investment			7,047.3		7,088.2
Materials and Supplies			93		95.8
Regulatory Assets, Noncurrent			988.2		403.1
Net Over-Recovered Fuel Costs			20
Customers			119.4		27.1
Capital Contribution from Member			100
Southwestern Electric Power Co [Member] | Additional Paid-in Capital [Member]
Public Utilities, General Disclosures [Line Items]
Capital Contribution from Member			100
Southwestern Electric Power Co [Member] | Senior Unsecured Notes [Member]
Public Utilities, General Disclosures [Line Items]
Proceeds from Issuance of Debt	[1]		500
Southwestern Electric Power Co [Member] | 2020 Texas Fuel Reconciliation
Public Utilities, General Disclosures [Line Items]
Amount of Fuel Costs Under Review			1,700
Southwestern Electric Power Co [Member] | 2020 Texas Fuel Reconciliation | TEXAS
Public Utilities, General Disclosures [Line Items]
Amount of Fuel Costs Under Review			616
Recommended Disallowance from Staff or Intervenors			125
Southwestern Electric Power Co [Member] | February 2021 Storm Event
Public Utilities, General Disclosures [Line Items]
Capitalized Storm Costs			4.9
Incremental Other Operation and Maintenance Expenses			0
Deferred Storm Costs as a Regulated Asset			42.1
Total Estimated February 2021 Storm Restoration Expenditures			47
Southwestern Electric Power Co [Member] | February 2021 Severe Storm Fuel Costs
Public Utilities, General Disclosures [Line Items]
Customers			88.4
Total Estimated 2021 February Winter Storm Fuel Costs			$ 584.7
Southwestern Electric Power Co [Member] | February 2021 Severe Storm Fuel Costs | Arkansas
Public Utilities, General Disclosures [Line Items]
Requested Weighted Average Cost of Capital			6.05%
Southwestern Electric Power Co [Member] | Dolet Hills Power Station [Member] | Generating Units Probable of Abandonment [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment			$ 51.3
Accelerated Depreciation Regulatory Asset			92.6
Cost of Removal Regulatory Liability			$ 1.1
Expected Retirement Date	[5]		2021
Depreciation	[4]		$ 7.7
Southwestern Electric Power Co [Member] | Dolet Hills Power Station and Related Fuel Operations
Public Utilities, General Disclosures [Line Items]
Percent of Fuel Supply Provided by DHLC			100.00%
Asset Retirement Obligation, Revision of Estimate			$ 21
Share of Net Investment in Dolet Hills Power Station			150
Dolet Hills Lignite Company Unbilled Fixed Costs			126
Recovery of 2021 Dolet Hills Fuel Costs			20
Approved Deferral of Dolet Hills Fuel Costs			30
Southwestern Electric Power Co [Member] | Pirkey Power Plant and Related Fuel Operations
Public Utilities, General Disclosures [Line Items]
Share of Net Investment in Pirkey Power Plant			209
Pirkey Power Plant and Sabine Unbilled Fixed Costs			163
Southwestern Electric Power Co [Member] | Pirkey Generating Station (Unit No. 1) | Generating Units Probable of Abandonment [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment			178.3
Accelerated Depreciation Regulatory Asset			30.8
Cost of Removal Regulatory Liability			$ 18.4
Expected Retirement Date	[6]		2023
Depreciation	[4]		$ 13.7
Southwestern Electric Power Co [Member] | Welsh Plant Unit 1 and 3 | Generating Units Probable of Abandonment [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment			528.8
Accelerated Depreciation Regulatory Asset			14.2
Cost of Removal Regulatory Liability	[7]		$ 11.4
Expected Retirement Date	[8]		2028
Depreciation	[4]		$ 33.3
Southwestern Electric Power Co [Member] | February 2021 Severe Storm Fuel Costs
Public Utilities, General Disclosures [Line Items]
Capital Contribution from Member			100
Southwestern Electric Power Co [Member] | February 2021 Severe Storm Fuel Costs | Senior Unsecured Notes [Member]
Public Utilities, General Disclosures [Line Items]
Proceeds from Issuance of Debt			500
Kentucky Power Co [Member] | February 2021 Storm Event
Public Utilities, General Disclosures [Line Items]
Capitalized Storm Costs			26.7
Incremental Other Operation and Maintenance Expenses			3.8
Deferred Storm Costs as a Regulated Asset			44.1
Total Estimated February 2021 Storm Restoration Expenditures			74.6
Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			1,833.6		442.2
Regulatory Assets Pending Final Regulatory Approval [Member] | AEP Texas Inc. [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			46		32.9
Regulatory Assets Pending Final Regulatory Approval [Member] | Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			92.9		43.8
Regulatory Assets Pending Final Regulatory Approval [Member] | Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			3.4		4.3
Regulatory Assets Pending Final Regulatory Approval [Member] | Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			8.4		8.4
Regulatory Assets Pending Final Regulatory Approval [Member] | Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			748.3		50.5
Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			835.8		247.3
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | February 2021 Severe Storm Fuel Costs
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	[9]		1,185
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Oklaunion Power Station Accelerated Depreciation [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			34		34.4
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Kentucky Deferred Purchase Power Expenses [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			42.8		41.3
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Plant Retirement Costs - Unrecovered Plant [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			35.2		35.2
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Dolet Hills Power Station Accelerated Depreciation [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			92.6		71.2
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			37.5		26.4
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | February 2021 Severe Storm Fuel Costs
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	[10]		1,185		0
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Pirkey Power Plant Accelerated Depreciation
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			30.8		12.2
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | AEP Texas Inc. [Member] | Adavanced Metering System
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			16.4		16.3
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Appalachian Power Co [Member] | COVID-19 - Virginia
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			4		3.7
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Indiana Michigan Power Co [Member] | Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			0		0.5
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Public Service Co Of Oklahoma [Member] | February 2021 Severe Storm Fuel Costs
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	[9]		688.7
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Public Service Co Of Oklahoma [Member] | Oklaunion Power Station Accelerated Depreciation [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			34		34.4
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Public Service Co Of Oklahoma [Member] | February 2021 Severe Storm Fuel Costs
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	[11]		688.7		0
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member] | February 2021 Severe Storm Fuel Costs
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	[9]		496.3
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member] | Dolet Hills Power Station Accelerated Depreciation [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			92.6		71.2
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member] | Plant Retirement Costs - Unrecovered Plant, Louisiana [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			35.2		35.2
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member] | Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			2.8		2.2
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member] | February 2021 Severe Storm Fuel Costs
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	[12]		496.3		0
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member] | Pirkey Power Plant Accelerated Depreciation
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			30.8		12.2
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member] | Welsh Unit 1 and 3 Accelerated Depreciation
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			14.2		3.6
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | COVID-19
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			19.5		24.9
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Plant Retirement Costs - Asset Retirement Obligation Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			25.9		25.9
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Storm Related Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			285		134.2
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			33		27.2
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Environmental Expense Deferral - Virginia
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			12.3		9.3
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | AEP Texas Inc. [Member] | COVID-19
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			8.6		10.5
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | AEP Texas Inc. [Member] | Storm Related Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			10.5		0.8
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | AEP Texas Inc. [Member] | Vegetation Management Program [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			3.8		3.8
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | AEP Texas Inc. [Member] | Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			2.6		1.5
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | AEP Texas Inc. [Member] | Texas Retail Electric Provider Bad Debt Expense
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			4.1		0
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Appalachian Power Co [Member] | Plant Retirement Costs - Asset Retirement Obligation Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			25.9		25.9
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Appalachian Power Co [Member] | Storm Related Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			49.1		3.4
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Appalachian Power Co [Member] | COVID-19 - West Virginia
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			1.6		1.5
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Appalachian Power Co [Member] | Environmental Expense Deferral - Virginia
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			12.3		9.3
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Indiana Michigan Power Co [Member] | COVID-19
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			2.8		3.8
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Indiana Michigan Power Co [Member] | Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			0.6		0
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Ohio Power Co [Member] | COVID-19
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			1.5		4.4
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Ohio Power Co [Member] | Storm Related Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			6.8		4
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Ohio Power Co [Member] | Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			0.1		0
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Public Service Co Of Oklahoma [Member] | COVID-19
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			0.8		0.3
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Public Service Co Of Oklahoma [Member] | Storm Related Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			24.8		15.8
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member] | Asset Retirement Obligation - Louisiana [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			9.4		9.1
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member] | Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			15.4		14.5
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member] | Storm Related Costs - Louisiana
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent			$ 139.1		$ 99.3
[1]	Amounts indicated on the statements of cash flows are net of issuance costs and premium or discount and will not tie to the issuance amounts.
[2]	Includes Northeastern Plant, Unit 4, which was retired in 2016. Removal of Northeastern Plant, Unit 4, will be performed with Northeastern Plant, Unit 3, after retirement.
[3]	Northeastern Plant, Unit 3 is currently being recovered through 2040.
[4]	Represents the amount of annual depreciation that has been collected from customers over the prior 12-month period
[5]	Dolet Hills Power Station is currently being recovered through 2026 in the Louisiana jurisdiction and through 2046 in the Arkansas and Texas jurisdictions.
[6]	Pirkey Power Plant is currently being recovered through 2025 in the Louisiana jurisdiction and through 2045 in the Arkansas and Texas jurisdictions.
[7]	Includes Welsh Plant, Unit 2, which was retired in 2016. Removal of Welsh Plant, Unit 2, will be performed with Welsh Plant, Units 1 and 3, after retirement.
[8]	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.
[9]	(a) These costs were deferred as regulatory assets as of March 31, 2021.
[10]	PSO and SWEPCo have active fuel clauses that allow for the recovery of prudently incurred fuel and purchased power expenses. However, the recovery of these costs from customers may be extended over longer than usual time periods to mitigate the impact on customer bills. See “Impacts of Severe Winter Weather” section below for additional information.
[11]	PSO has an active fuel clause that allows for the recovery of prudently incurred fuel and purchased power expenses. However, the recovery of these costs from customers may be extended over longer than usual time periods to mitigate the impact on customer bills. See “Impacts of Severe Winter Weather” section below for additional information.
[12]	SWEPCo has an active fuel clause that allows for the recovery of prudently incurred fuel and purchased power expenses. However, the recovery of these costs from customers may be extended over longer than usual time periods to mitigate the impact on customer bills. See “Impacts of Severe Winter Weather” section below for additional information

Rate Matters East Companies (De

Rate Matters East Companies (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Dec. 31, 2020
Public Utilities, General Disclosures [Line Items]
Property, Plant and Equipment, Net	$ 64,696.1	$ 63,901.6
AEP Transmission Co [Member]
Public Utilities, General Disclosures [Line Items]
Property, Plant and Equipment, Net	11,070.4	10,772.8
Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Property, Plant and Equipment, Net	11,455.2	11,394.1
Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Property, Plant and Equipment, Net	7,063.2	7,052.3
Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Property, Plant and Equipment, Net	7,565.7	$ 7,452.1
2017-2019 Virginia Triennial Review [Member] | Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Annual Increase	$ 40
Approved Return on Common Equity	9.20%
Total Basis Point Band for Authorized Return on Equity	140.00%
2020 Ohio Base Rate Case [Member] | Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Annual Increase	$ 42
Requested Return on Equity	10.15%
Staff Recommended Annual Revenue Cap for the DIR in 2022	$ 78
Staff Recommended Annual Revenue Cap for the DIR for the First Five Months of 2024	46
Proposed Settlement Annual Rate Increase	$ 68
Proposed Settlement Agreement ROE	9.70%
Settlement Annual Revenue Cap for the DIR in 2021	$ 57
Settlement Annual Revenue Cap for the DIR in 2022	91
Settlement Annual Revenue Cap for the DIR in 2023	116
Settlement Annual Revenue Cap for the DIR in for the first five months of 2024	51
Staff Recommended Annual Revenue Cap for the DIR in 2023	96
Staff Recommended Annual Revenue Cap for the DIR in 2021	57
2020 Ohio Base Rate Case [Member] | Ohio Power Co [Member] | Demand Side Management Programs
Public Utilities, General Disclosures [Line Items]
Staff Recommended Adjustments to Companies Request	40
2020 Ohio Base Rate Case [Member] | Ohio Power Co [Member] | Employee Related Expense
Public Utilities, General Disclosures [Line Items]
Staff Recommended Adjustments to Companies Request	23
2020 Ohio Base Rate Case [Member] | Ohio Power Co [Member] | Rate Base
Public Utilities, General Disclosures [Line Items]
Staff Recommended Adjustments to Companies Request	19
2020 Ohio Base Rate Case [Member] | Ohio Power Co [Member] | Property Tax
Public Utilities, General Disclosures [Line Items]
Staff Recommended Adjustments to Companies Request	17
2020 Ohio Base Rate Case [Member] | Ohio Power Co [Member] | Other Various Expenses
Public Utilities, General Disclosures [Line Items]
Staff Recommended Adjustments to Companies Request	15
2020 Ohio Base Rate Case [Member] | Ohio Power Co [Member] | Vegetation Management Programs
Public Utilities, General Disclosures [Line Items]
Staff Recommended Adjustments to Companies Request	10
2020 Ohio Base Rate Case [Member] | Ohio Power Co [Member] | Depreciation Expense
Public Utilities, General Disclosures [Line Items]
Staff Recommended Adjustments to Companies Request	11
2019 DIR Audit [Member]
Public Utilities, General Disclosures [Line Items]
DIR Revenue Amount above 2019 Authorized Limit	17
Virginia E-RAC | Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Annual Increase	31
Investment in CCR/ELG	240
CCR Investment	8
ELG Investment	$ 14
Minimum [Member] | 2017-2019 Virginia Triennial Review [Member] | Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Approved Return on Common Equity	8.50%
Minimum [Member] | 2020 Ohio Base Rate Case [Member] | Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Staff Recommended Return on Common Equity	8.76%
Staff Recommended Annual Rate Decrease	$ 102
Minimum [Member] | 2020 Ohio Base Rate Case [Member] | Ohio Power Co [Member] | Return on Common Equity
Public Utilities, General Disclosures [Line Items]
Staff Recommended Adjustments to Companies Request	$ 9
Maximum [Member] | 2017-2019 Virginia Triennial Review [Member] | Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Approved Return on Common Equity	9.90%
Maximum [Member] | 2020 Ohio Base Rate Case [Member] | Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Staff Recommended Return on Common Equity	9.78%
Staff Recommended Annual Rate Decrease	$ 123
Maximum [Member] | 2020 Ohio Base Rate Case [Member] | Ohio Power Co [Member] | Return on Common Equity
Public Utilities, General Disclosures [Line Items]
Staff Recommended Adjustments to Companies Request	30
Maximum [Member] | 2020 Ohio Base Rate Case [Member] | Ohio Power Co [Member] | Plant in Service
Public Utilities, General Disclosures [Line Items]
Recommended Disallowance from Staff or Intervenors	$ 27

Rate Matters West Companies (De

Rate Matters West Companies (Details) $ in Millions	3 Months Ended
	Mar. 31, 2021USD ($)customer	Dec. 31, 2020USD ($)
Public Utilities, General Disclosures [Line Items]
Construction Work in Progress	$ 4,289.5	$ 4,025.7
AEP Texas Inc. [Member]
Public Utilities, General Disclosures [Line Items]
Construction Work in Progress	567.8	614.1
Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Construction Work in Progress	98.2	128.7
Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Construction Work in Progress	232.4	$ 228.3
AEP Texas Interim Transmission and Distribution Rates [Member] | AEP Texas Inc. [Member]
Public Utilities, General Disclosures [Line Items]
AEP Texas Cumulative Revenues Subject to Review	$ 118
ETT Interim Transmission Rates [Member]
Public Utilities, General Disclosures [Line Items]
Parent Ownership Interest In ETT	50.00%
AEP Share Of ETT Cumulative Revenues Subject To Review	$ 1,200
2012 Texas Base Rate Case [Member] | Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
2013 Reversal Of Previously Recorded Regulatory Disallowances	114
Resulting Approved Base Rate Increase	52
2012 Texas Base Rate Case [Member] | Turk Generating Plant [Member] | Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Property, Plant and Equipment, Net	$ 1,400
Texas Jurisdictional Share of Turk Plant	33.00%
2016 Texas Base Rate Case [Member] | Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Return on Equity	10.00%
Requested Net Increase in Texas Annual Revenues	$ 69
Approved Net Increase in Texas Annual Revenues	$ 50
Approved Return on Common Equity	9.60%
Approved Additional Vegetation Management Expenses	$ 2
Impairment Charge Total	19
Impairment Charge Welsh Plant, Unit 2	7
Impairment Charge Disallowed Plant Investments	12
Additional Revenues Recognized to be Surcharged to Customers	32
Additional Recognized Expenses Consisting Primarily of Depreciation and Vegetation Management	7
Hurricane Laura [Member] | Southwestern Electric Power Co [Member] | Louisiana Jurisdiction [Member]
Public Utilities, General Disclosures [Line Items]
Incremental Other Operation and Maintenance Expenses	$ 79
Hurricane Laura [Member] | Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Customers without Power | customer	130,000
Incremental Other Operation and Maintenance Expenses	$ 82
Capitalized Storm Costs	$ 31
Hurricane Delta [Member] | Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Customers without Power | customer	23,000
Incremental Other Operation and Maintenance Expenses	$ 17
Capitalized Storm Costs	3
2020 Texas Base Rate Case [Member] | Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Annual Increase	105
Staff Recommended Annual Rate Increase	$ 45
Requested Return on Equity	10.35%
Requested Net Annual Increase	$ 90
Amount of Increase Related to Vegetation Management	5
Amount of Increase Related to Annual Depreciation Expense	10
Amount of Increase Related to Storm Catastrophe Reserve	2
Requested Recovery of Dolet Hills Power Station	$ 45
Staff Recommended Return on Common Equity	9.22%
2020 Texas Base Rate Case [Member] | Southwestern Electric Power Co [Member] | Minimum [Member]
Public Utilities, General Disclosures [Line Items]
Intervenor Recommended Annual Increase	$ 20
Intervenor Recommended Return on Common Equity	9.00%
2020 Texas Base Rate Case [Member] | Southwestern Electric Power Co [Member] | Maximum [Member]
Public Utilities, General Disclosures [Line Items]
Intervenor Recommended Annual Increase	$ 70
Intervenor Recommended Return on Common Equity	9.15%
2020 Louisiana Base Rate Case | Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Annual Increase	$ 134
Requested Return on Equity	10.35%
Amount of Increase Related to Annual Depreciation Expense	$ 32
Amount of Increase Related to Recovering Deferred Hurricane Costs	$ 10

Commitments, Guarantees and C_3

Commitments, Guarantees and Contingencies (Details) - USD ($) $ in Millions		1 Months Ended
		Apr. 22, 2021	Mar. 31, 2021
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements			$ 48.6
Vertically Integrated Utilities [Member] | Subsequent Event [Member]
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Rockport Plant, Unit 2 Acquisition Price		$ 115.5
AEP Wind Holdings LLC [Member] | Generation And Marketing [Member]
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Maximum Potential Amount of Future Payments Associated with Guarantee			157
Guarantor Obligations, Current Carrying Value			30
Guarantor Obligations, Current Carrying Value, Contingent Portion			1
AEP Texas Inc. [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements			11.3
Appalachian Power Co [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements			6.3
Indiana Michigan Power Co [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements			4.2
Ohio Power Co [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements			7.7
Public Service Co Of Oklahoma [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements			4.7
Southwestern Electric Power Co [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements			5.4
Rockport Lease [Member]
Present Value of Future Minimum Lease Payments, Sale Leaseback Transactions, Fiscal Year Maturity [Abstract]
Minimum Lease Payments, Sale Leaseback Transactions, Next Twelve Months	[1]		147.8
Minimum Lease Payments, Sale Leaseback Transactions, within Two Years	[1]		147.6
Minimum Lease Payments, Sale Leaseback Transactions	[1]		295.4
Rockport Lease [Member] | Indiana Michigan Power Co [Member]
Present Value of Future Minimum Lease Payments, Sale Leaseback Transactions, Fiscal Year Maturity [Abstract]
Minimum Lease Payments, Sale Leaseback Transactions, Next Twelve Months			73.9
Minimum Lease Payments, Sale Leaseback Transactions, within Two Years			73.8
Minimum Lease Payments, Sale Leaseback Transactions			147.7
Boat and Barge Leases [Member]
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Guarantor Obligations, Current Carrying Value			3
Maximum Potential Lease Payments, AEPRO Barge and Boat Leases			47
Guarantee Obligations Current Carrying Value Other Liabilities Current			1
Guarantee Obligations Current Carrying Value Other Liabilities Noncurrent			2
Letters of Credit [Member]
Maximum Future Payments for Letters of Credit [Abstract]
Maximum Future Payments for Letters of Credit Issued Under the Uncommitted Facility			183.2
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Letters of Credit Limit			1,200
Uncommitted Facility			425
Letters of Credit [Member] | AEP Texas Inc. [Member]
Maximum Future Payments for Letters of Credit [Abstract]
Maximum Future Payments for Letters of Credit Issued Under the Uncommitted Facility			2.2
March 2026 | Letters of Credit [Member]
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Revolving Credit Facilities			4,000
March 2023 | Letters of Credit [Member]
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Revolving Credit Facilities			$ 1,000
[1]	AEP’s future minimum lease payments include equal shares from AEGCo and I&M.

Acquisitions and Dispositions (

Acquisitions and Dispositions (Details) $ in Millions	3 Months Ended
	Mar. 31, 2022MW	Dec. 31, 2021MW	Jun. 30, 2021USD ($)MW	Mar. 31, 2021USD ($)MW
Dry Lake Solar Project
Noncash or Part Noncash Acquisition, Other Assets Acquired				$ 18.9
Dry Lake Solar Project | Noncontrolling Interest [Member]
Noncash or Part Noncash Acquisition, Other Assets Acquired				$ 18.9
Generation And Marketing [Member] | Dry Lake Solar Project
Percentage of an Asset Acquired				75.00%
Wind Generation MWs | MW				100
Noncash or Part Noncash Acquisition, Value of Assets Acquired				$ 114
Payments to Acquire Businesses, Gross				103
Generation And Marketing [Member] | Dry Lake Solar Project | Noncontrolling Interest [Member]
Noncash or Part Noncash Acquisition, Other Assets Acquired				$ 19
Vertically Integrated Utilities [Member] | North Central Wind Energy Facilities
Wind Generation MWs | MW				1,485
Vertically Integrated Utilities [Member] | North Central Wind Energy Facilities | Subsequent Event [Member]
Wind Generation MWs | MW	999	287	199
Noncash or Part Noncash Acquisition, Value of Assets Acquired			$ 2,000
Payments to Acquire Businesses, Gross			$ 307
Property, Plant and Equipment | Generation And Marketing [Member] | Dry Lake Solar Project
Noncash or Part Noncash Acquisition, Other Assets Acquired				$ 133
Accounts Payable [Member] | Generation And Marketing [Member] | Dry Lake Solar Project
Noncash or Part Noncash Acquisition, Other Assets Acquired				$ 11
Public Service Co Of Oklahoma [Member] | Vertically Integrated Utilities [Member] | North Central Wind Energy Facilities | Subsequent Event [Member]
Percentage of an Asset Acquired			45.50%
Southwestern Electric Power Co [Member] | Vertically Integrated Utilities [Member] | North Central Wind Energy Facilities | Subsequent Event [Member]
Percentage of an Asset Acquired			54.50%

Benefit Plans (Details)

Benefit Plans (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Pension Plans [Member]
Components of Net Periodic Benefit Cost
Service Cost	$ 32.3	$ 28
Interest Cost	34.3	42
Expected Return on Plan Assets	(57.5)	(66.2)
Amortization of Prior Service Cost (Credit)	0	0
Amortization of Net Actuarial Loss	25.4	23.4
Net Periodic Benefit Cost (Credit)	34.5	27.2
Pension Plans [Member] | AEP Texas Inc. [Member]
Components of Net Periodic Benefit Cost
Service Cost	3	2.6
Interest Cost	2.8	3.5
Expected Return on Plan Assets	(4.9)	(5.7)
Amortization of Prior Service Cost (Credit)	0	0
Amortization of Net Actuarial Loss	2.1	1.9
Net Periodic Benefit Cost (Credit)	3	2.3
Pension Plans [Member] | Appalachian Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	3	2.6
Interest Cost	4.1	5.1
Expected Return on Plan Assets	(7.3)	(8.4)
Amortization of Prior Service Cost (Credit)	0	0
Amortization of Net Actuarial Loss	3	2.8
Net Periodic Benefit Cost (Credit)	2.8	2.1
Pension Plans [Member] | Indiana Michigan Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	4.4	3.9
Interest Cost	4	4.9
Expected Return on Plan Assets	(7.2)	(8.3)
Amortization of Prior Service Cost (Credit)	0	0
Amortization of Net Actuarial Loss	2.9	2.7
Net Periodic Benefit Cost (Credit)	4.1	3.2
Pension Plans [Member] | Ohio Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	2.9	2.4
Interest Cost	3.1	3.9
Expected Return on Plan Assets	(5.6)	(6.6)
Amortization of Prior Service Cost (Credit)	0	0
Amortization of Net Actuarial Loss	2.2	2.1
Net Periodic Benefit Cost (Credit)	2.6	1.8
Pension Plans [Member] | Public Service Co Of Oklahoma [Member]
Components of Net Periodic Benefit Cost
Service Cost	1.9	1.8
Interest Cost	1.7	2.1
Expected Return on Plan Assets	(3.1)	(3.6)
Amortization of Prior Service Cost (Credit)	0	0
Amortization of Net Actuarial Loss	1.3	1.2
Net Periodic Benefit Cost (Credit)	1.8	1.5
Pension Plans [Member] | Southwestern Electric Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	2.9	2.5
Interest Cost	2.1	2.5
Expected Return on Plan Assets	(3.4)	(3.9)
Amortization of Prior Service Cost (Credit)	0	0
Amortization of Net Actuarial Loss	1.5	1.4
Net Periodic Benefit Cost (Credit)	3.1	2.5
Other Postretirement Benefit Plans [Member]
Components of Net Periodic Benefit Cost
Service Cost	2.4	2.5
Interest Cost	7.6	9.9
Expected Return on Plan Assets	(22.8)	(23.9)
Amortization of Prior Service Cost (Credit)	(17.7)	(17.4)
Amortization of Net Actuarial Loss	0	1.5
Net Periodic Benefit Cost (Credit)	(30.5)	(27.4)
Other Postretirement Benefit Plans [Member] | AEP Texas Inc. [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.2	0.2
Interest Cost	0.6	0.8
Expected Return on Plan Assets	(1.9)	(2)
Amortization of Prior Service Cost (Credit)	(1.5)	(1.4)
Amortization of Net Actuarial Loss	0	0.1
Net Periodic Benefit Cost (Credit)	(2.6)	(2.3)
Other Postretirement Benefit Plans [Member] | Appalachian Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.3	0.3
Interest Cost	1.2	1.6
Expected Return on Plan Assets	(3.4)	(3.6)
Amortization of Prior Service Cost (Credit)	(2.6)	(2.5)
Amortization of Net Actuarial Loss	0	0.2
Net Periodic Benefit Cost (Credit)	(4.5)	(4)
Other Postretirement Benefit Plans [Member] | Indiana Michigan Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.3	0.3
Interest Cost	0.9	1.2
Expected Return on Plan Assets	(2.8)	(2.9)
Amortization of Prior Service Cost (Credit)	(2.4)	(2.4)
Amortization of Net Actuarial Loss	0	0.2
Net Periodic Benefit Cost (Credit)	(4)	(3.6)
Other Postretirement Benefit Plans [Member] | Ohio Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.2	0.2
Interest Cost	0.8	1
Expected Return on Plan Assets	(2.4)	(2.6)
Amortization of Prior Service Cost (Credit)	(1.8)	(1.8)
Amortization of Net Actuarial Loss	0	0.2
Net Periodic Benefit Cost (Credit)	(3.2)	(3)
Other Postretirement Benefit Plans [Member] | Public Service Co Of Oklahoma [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.2	0.2
Interest Cost	0.4	0.5
Expected Return on Plan Assets	(1.3)	(1.3)
Amortization of Prior Service Cost (Credit)	(1.1)	(1.1)
Amortization of Net Actuarial Loss	0	0.1
Net Periodic Benefit Cost (Credit)	(1.8)	(1.6)
Other Postretirement Benefit Plans [Member] | Southwestern Electric Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.1	0.2
Interest Cost	0.5	0.6
Expected Return on Plan Assets	(1.5)	(1.5)
Amortization of Prior Service Cost (Credit)	(1.3)	(1.3)
Amortization of Net Actuarial Loss	0	0.1
Net Periodic Benefit Cost (Credit)	$ (2.2)	$ (1.9)

Business Segments (Details)

Business Segments (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2021		Mar. 31, 2020		Dec. 31, 2020
Reportable Segment Information
Revenue from Contracts with Customers		$ 4,281.1		$ 3,747.5
Revenue from Related Parties		0		0
Revenues		4,281.1		3,747.5
Net Income (Loss)		578.8		499.3
Balance Sheet Information
Total Property, Plant and Equipment		85,612.9				$ 84,313
Accumulated Depreciation and Amortization		20,916.8				20,411.4
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		64,696.1				63,901.6
Total Assets		82,985.1				80,757.2
Long-term Debt Due Within One Year		2,130.2				2,086.1
Long-term Debt - Affiliated		0				0
Long-term Debt		30,214.8				28,986.4
Total Long-term Debt Outstanding		32,345				31,072.5
Income Tax (Expense) Benefit		54.5		46.5
Interest Expense		290.2		292.1
Reclassification out of Accumulated Other Comprehensive Income [Member]
Balance Sheet Information
Income Tax (Expense) Benefit		(36.1)		10.4
Interest Expense	[1]	1.5		0.9
Interest Rate [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Balance Sheet Information
Income Tax (Expense) Benefit		0.4		0.2
Interest Expense	[1]	1.5		0.9
Vertically Integrated Utilities [Member]
Reportable Segment Information
Revenue from Contracts with Customers		2,504.5		2,193
Transmission and Distribution Utilities Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		1,082.3		1,075.2
Generation and Marketing Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		601.7		408.4
Generation and Marketing Revenues [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reportable Segment Information
Revenue from Contracts with Customers	[1]	0.8		(0.1)
Generation and Marketing Revenues [Member] | Interest Rate [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Reportable Segment Information
Revenue from Contracts with Customers	[1]	0		0
Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		92.6		70.9
Revenues		4.8	[2]	19.9	[3]
AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Related Parties		285.6		233.7
Revenues		361.7		295.6
Net Income (Loss)		151.7		117.8
Balance Sheet Information
Total Property, Plant and Equipment		11,694				11,345.6
Accumulated Depreciation and Amortization		623.6				572.8
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		11,070.4				10,772.8
Notes Receivable, Related Parties		0				0
Total Assets		11,515.1				11,246
Long-term Debt Due Within One Year		50				50
Long-term Debt		3,899				3,898.5
Total Long-term Debt Outstanding		3,949				3,948.5
Income Tax (Expense) Benefit		39.6		31.8
Interest Income		0.1		0.8
Interest Expense		34.1		29.6
AEP Transmission Co [Member] | Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0.1		0.6
Revenues		0	[4]	0	[5]
AEP Transmission Co [Member] | Transmission [Member]
Reportable Segment Information
Revenue from Contracts with Customers		76		61.3
Reconciling Adjustments [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0		0
Revenue from Related Parties		(368.4)		(354.8)
Revenues		(368.4)		(354.8)
Net Income (Loss)		0		0
Balance Sheet Information
Total Property, Plant and Equipment		0				0
Accumulated Depreciation and Amortization		0				0
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		0				0
Total Assets	[6]	(4,562.7)				(3,961.7)
Long-term Debt Due Within One Year		0				0
Long-term Debt - Affiliated		(65)				(65)
Long-term Debt		0				0
Total Long-term Debt Outstanding		(65)				(65)
Reconciling Adjustments [Member] | Other Revenues [Member]
Reportable Segment Information
Revenues		(3.6)	[2]	(25.5)	[3]
Reconciling Adjustments [Member] | AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0		0
Revenue from Related Parties		0		0
Revenues		0		0
Net Income (Loss)		0		0
Balance Sheet Information
Total Property, Plant and Equipment		0				0
Accumulated Depreciation and Amortization		0				0
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		0				0
Notes Receivable, Related Parties	[7]	(3,899)				(3,948.5)
Total Assets	[8]	(4,050.4)				(4,023.1)
Total Long-term Debt Outstanding	[7]	(3,990)				(3,990)
Income Tax (Expense) Benefit		0		0
Interest Income	[9]	(38.2)		(33.4)
Interest Expense	[9]	(38.2)		(33.4)
Reconciling Adjustments [Member] | AEP Transmission Co [Member] | Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0		0
Vertically Integrated Utilities [Member]
Reportable Segment Information
Revenue from Related Parties		32.8		33.7
Revenues		2,537.3		2,226.7
Net Income (Loss)		271.4		246.3
Balance Sheet Information
Total Property, Plant and Equipment		49,448.9				49,023.3
Accumulated Depreciation and Amortization		15,950.1				15,586.2
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		33,498.8				33,437.1
Total Assets		44,591.3				42,752.7
Long-term Debt Due Within One Year		1,078.3				1,034.6
Long-term Debt - Affiliated		65				65
Long-term Debt		13,185.8				12,375.6
Total Long-term Debt Outstanding		14,329.1				13,475.2
Vertically Integrated Utilities [Member] | Vertically Integrated Utilities [Member]
Reportable Segment Information
Revenue from Contracts with Customers		2,504.5		2,193
Vertically Integrated Utilities [Member] | Other Revenues [Member]
Reportable Segment Information
Revenues		0	[2]	0	[3]
Transmission And Distribution Utilities [Member]
Reportable Segment Information
Revenue from Related Parties		5.8		31.7
Revenues		1,088.1		1,106.9
Net Income (Loss)		114.4		116.2
Balance Sheet Information
Total Property, Plant and Equipment		21,492.9				21,145
Accumulated Depreciation and Amortization		3,951.3				3,879.3
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		17,541.6				17,265.7
Total Assets		20,076.9				19,765.9
Long-term Debt Due Within One Year		589				588.8
Long-term Debt - Affiliated		0				0
Long-term Debt		7,097.4				6,661.9
Total Long-term Debt Outstanding		7,686.4				7,250.7
Transmission And Distribution Utilities [Member] | Transmission and Distribution Utilities Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		1,082.3		1,075.2
Transmission And Distribution Utilities [Member] | Other Revenues [Member]
Reportable Segment Information
Revenues		5.3	[2]	29.3	[3]
AEP Transmission Holdco [Member]
Reportable Segment Information
Revenue from Related Parties		289.1		237.1
Revenues		377		310.2
Net Income (Loss)		173.2		141.6
Balance Sheet Information
Total Property, Plant and Equipment		12,185.2				11,827.2
Accumulated Depreciation and Amortization		648.1				595.7
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		11,537.1				11,231.5
Total Assets		12,925.8				12,627.3
Long-term Debt Due Within One Year		52.4				52.3
Long-term Debt - Affiliated		0				0
Long-term Debt		4,089.7				4,075.7
Total Long-term Debt Outstanding		4,142.1				4,128
AEP Transmission Holdco [Member] | Transmission [Member]
Reportable Segment Information
Revenue from Contracts with Customers		87.9		73.1
Generation And Marketing [Member]
Reportable Segment Information
Revenue from Related Parties		32.5		30.2
Revenues		634.2		438.6
Net Income (Loss)		38.2		30.5
Balance Sheet Information
Total Property, Plant and Equipment		2,080.6				1,910.2
Accumulated Depreciation and Amortization		183.8				166.1
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		1,896.8				1,744.1
Total Assets		3,881.8				3,585.9
Long-term Debt Due Within One Year		0				0
Long-term Debt - Affiliated		0				0
Long-term Debt		0				0
Total Long-term Debt Outstanding		0				0
Generation And Marketing [Member] | Generation and Marketing Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		601.7		408.4
Generation And Marketing [Member] | Other Revenues [Member]
Reportable Segment Information
Revenues		0	[2]	18.3	[3]
All Other [Member]
Reportable Segment Information
Revenue from Related Parties	[10]	8.2		22.1
Revenues	[10]	12.9		19.9
Net Income (Loss)	[10]	(18.4)		(35.3)
Balance Sheet Information
Total Property, Plant and Equipment	[10]	405.3				407.3
Accumulated Depreciation and Amortization	[10]	183.5				184.1
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET	[10]	221.8				223.2
Total Assets	[10],[11]	6,072				5,987.1
Long-term Debt Due Within One Year	[10],[12]	410.5				410.4
Long-term Debt - Affiliated	[10]	0				0
Long-term Debt	[10],[12]	5,841.9				5,873.2
Total Long-term Debt Outstanding	[10],[12]	6,252.4				6,283.6
All Other [Member] | Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers	[10]	4.7		(2.2)
Revenues		3.1	[2]	(2.2)	[3]
State Transcos [Member] | AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Related Parties		285.6		233.7
Revenues		361.7		295.6
Net Income (Loss)		151.7		117.3
Balance Sheet Information
Total Property, Plant and Equipment		11,694				11,345.6
Accumulated Depreciation and Amortization		623.6				572.8
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		11,070.4				10,772.8
Notes Receivable, Related Parties		0				0
Total Assets		11,458.3				11,185.1
Total Long-term Debt Outstanding		3,990				3,990
Income Tax (Expense) Benefit		39.6		31.8
Interest Income		0		0.2
Interest Expense		34.1		29.6
State Transcos [Member] | AEP Transmission Co [Member] | Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0.1		0.6
State Transcos [Member] | AEP Transmission Co [Member] | Transmission [Member]
Reportable Segment Information
Revenue from Contracts with Customers		76		61.3
AEPTCo Parent [Member] | AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0		0
Revenue from Related Parties		0		0
Revenues		0		0
Net Income (Loss)	[13]	0		0.5
Balance Sheet Information
Total Property, Plant and Equipment		0				0
Accumulated Depreciation and Amortization		0				0
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		0				0
Notes Receivable, Related Parties		3,899				3,948.5
Total Assets	[14]	4,107.2				4,084
Total Long-term Debt Outstanding		3,949				$ 3,948.5
Income Tax (Expense) Benefit		0		0
Interest Income		38.3		34
Interest Expense		$ 38.2		$ 33.4
[1]	Amounts reclassified to the referenced line item on the statements of income.
[2]	Amounts include affiliated and nonaffiliated revenues.
[3]	Amounts include affiliated and nonaffiliated revenues
[4]	Amounts include affiliated and nonaffiliated revenues.
[5]	Amounts include affiliated and nonaffiliated revenues.
[6]	Reconciling Adjustments for Total Assets primarily include elimination of intercompany advances to affiliates and intercompany accounts receivable.
[7]	Elimination of intercompany debt.
[8]	Primarily relates to the elimination of Notes Receivable from the State Transcos.
[9]	Elimination of intercompany interest income/interest expense on affiliated debt arrangement.
[10]	Corporate and Other primarily includes the purchasing of receivables from certain AEP utility subsidiaries. This segment also includes Parent’s guarantee revenue received from affiliates, investment income, interest income, interest expense and other nonallocated costs.
[11]	Includes elimination of AEP Parent’s investments in wholly-owned subsidiary companies.
[12]	Amounts are inclusive of the impact of fair value hedge accounting. See “Accounting for Fair Value Hedging Strategies” section of Note 10 for additional information.
[13]	Includes the elimination of AEPTCo Parent’s equity earnings in the State Transcos.
[14]	Includes the elimination of AEPTCo Parent’s investments in State Transcos.

Derivatives and Hedging (Detail

Derivatives and Hedging (Details) gal in Millions, MWh in Millions, MMBTU in Millions		3 Months Ended			12 Months Ended
		Mar. 31, 2021USD ($)MWhMMBTUgal		Mar. 31, 2020USD ($)	Dec. 31, 2020USD ($)MWhMMBTUgal
Cash Collateral Netting
Cash Collateral Received Netted Against Risk Management Assets		$ 3,000,000			$ 3,000,000
Cash Collateral Paid Netted Against Risk Management Liabilities		8,000,000			7,000,000
Fair Value of Derivative Instruments
Current Risk Management Assets		72,100,000			94,700,000
Long-term Risk Management Assets		264,800,000			242,200,000
Total Assets		336,900,000			336,900,000
Current Risk Management Liabilities		39,100,000			78,800,000
Long-term Risk Management Liabilities		273,000,000			232,800,000
Total Liabilities		312,100,000			311,600,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		29,400,000		$ (32,900,000)
Carrying Amount of Hedged Asset (Liability)	[1],[2]	(959,400,000)			(995,900,000)
Cumulative Fair Value Hedging Adjustment in the Carrying Amount of the Hedged Asset (Liability)	[1],[2]	(16,600,000)			(51,700,000)
Gain (Loss) on Hedging Instruments
Gain (Loss) on Fair Value Hedging Instruments	[3]	(33,200,000)		42,500,000
Gain (Loss) on Fair Value Portion of Long Term Debt	[3]	33,200,000		(42,500,000)
Collateral Triggering Events [Abstract]
Fair Value Of Derivative Liabilities Subject To Cross Default Provisions		156,800,000			188,400,000
Amount of Cash Collateral Posted		0			0
Additional Settlement Liability if Cross Default Provision is Triggered		127,700,000			169,200,000
Derivatives and Hedging (Textuals) [Abstract]
Hedged Liability, Discontinued Fair Value Hedge, Cumulative Increase (Decrease)		(51,000,000)			(53,000,000)
Investment in Private Investee
Derivatives and Hedging (Textuals) [Abstract]
Cost Method Investments					8,000,000
Equity Method Investments, Fair Value Disclosure		35,000,000
Unrealized Gain (Loss) on Investments		27,000,000
AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		600,000		(1,400,000)
Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		6,900,000			22,400,000
Total Assets					22,500,000
Total Liabilities					4,700,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		4,100,000		(16,000,000)
Collateral Triggering Events [Abstract]
Fair Value Of Derivative Liabilities Subject To Cross Default Provisions		600,000			4,300,000
Amount of Cash Collateral Posted		0			0
Additional Settlement Liability if Cross Default Provision is Triggered		100,000			3,500,000
Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		900,000			3,600,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(4,000,000)		2,600,000
Collateral Triggering Events [Abstract]
Fair Value Of Derivative Liabilities Subject To Cross Default Provisions		400,000			500,000
Amount of Cash Collateral Posted		0			0
Additional Settlement Liability if Cross Default Provision is Triggered		100,000			100,000
Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Liabilities		8,100,000			8,700,000
Long-term Risk Management Liabilities		95,900,000			101,600,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		9,700,000		(15,000,000)
Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		5,500,000			10,300,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		11,300,000		7,600,000
Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		1,300,000			3,200,000
Current Risk Management Liabilities		0			700,000
Long-term Risk Management Liabilities		900,000			1,000,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		7,100,000		3,100,000
Collateral Triggering Events [Abstract]
Fair Value Of Derivative Liabilities Subject To Cross Default Provisions		900,000			1,800,000
Amount of Cash Collateral Posted		0			0
Additional Settlement Liability if Cross Default Provision is Triggered		900,000			1,800,000
Risk Management Contracts [Member]
Fair Value of Derivative Instruments
Total Assets	[4]	319,100,000	[5]		322,100,000	[6]
Total Liabilities	[4]	236,800,000	[5]		218,900,000	[6]
Risk Management Contracts [Member] | AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Total Assets	[4]	0			0
Risk Management Contracts [Member] | Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[4],[7]	6,900,000			20,100,000
Total Liabilities	[4],[7]	200,000			1,300,000
Risk Management Contracts [Member] | Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[4],[7]	900,000			3,700,000
Total Liabilities	[4],[7]	200,000			200,000
Risk Management Contracts [Member] | Ohio Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[4],[7]	0			0
Total Liabilities	[4],[7]	104,000,000			110,300,000
Risk Management Contracts [Member] | Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Total Assets	[4],[7]	5,500,000			10,300,000
Risk Management Contracts [Member] | Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[4],[7]	1,300,000			3,200,000
Total Liabilities	[4],[7]	900,000			1,700,000
Commodity [Member]
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		(18,500,000)			(60,600,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		$ (300,000)			(27,100,000)
Derivatives and Hedging (Textuals) [Abstract]
Maximum Term for Exposure to Variability of Future Cash Flows		120 months
Cross Default Provisions Maximum Third Party Obligation Amount		$ 50,000,000			50,000,000
Commodity [Member] | Risk Management Contracts [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]	164,100,000			239,100,000
Long-term Risk Management Assets	[8]	266,900,000			275,900,000
Total Assets	[8]	431,000,000			515,000,000
Current Risk Management Liabilities	[8]	133,600,000			193,000,000
Long-term Risk Management Liabilities	[8]	219,800,000			222,200,000
Total Liabilities	[8]	353,400,000			415,200,000
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	77,600,000			99,800,000
Commodity [Member] | Risk Management Contracts [Member] | AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]	800,000			400,000
Long-term Risk Management Assets	[8]	0			0
Total Assets	[8]	800,000			400,000
Current Risk Management Liabilities	[8]	0			0
Long-term Risk Management Liabilities	[8]	0			0
Total Liabilities	[8]	0			0
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	800,000			400,000
Commodity [Member] | Risk Management Contracts [Member] | Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]	16,500,000			38,800,000
Long-term Risk Management Assets	[8]	500,000			700,000
Total Assets	[8]	17,000,000			39,500,000
Current Risk Management Liabilities	[8]	9,300,000			19,700,000
Long-term Risk Management Liabilities	[8]	500,000			600,000
Total Liabilities	[8]	9,800,000			20,300,000
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	7,200,000			19,200,000
Commodity [Member] | Risk Management Contracts [Member] | Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]	6,800,000			17,200,000
Long-term Risk Management Assets	[8]	300,000			500,000
Total Assets	[8]	7,100,000			17,700,000
Current Risk Management Liabilities	[8]	6,200,000			12,100,000
Long-term Risk Management Liabilities	[8]	300,000			400,000
Total Liabilities	[8]	6,500,000			12,500,000
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	600,000			5,200,000
Commodity [Member] | Risk Management Contracts [Member] | Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]	600,000			300,000
Long-term Risk Management Assets	[8]	0			0
Total Assets	[8]	600,000			300,000
Current Risk Management Liabilities	[8]	8,100,000			8,700,000
Long-term Risk Management Liabilities	[8]	95,900,000			101,600,000
Total Liabilities	[8]	104,000,000			110,300,000
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	(103,400,000)			(110,000,000)
Commodity [Member] | Risk Management Contracts [Member] | Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]	5,800,000			10,500,000
Long-term Risk Management Assets	[8]	0			0
Total Assets	[8]	5,800,000			10,500,000
Current Risk Management Liabilities	[8]	0			0
Long-term Risk Management Liabilities	[8]	0			0
Total Liabilities	[8]	0			0
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	5,800,000			10,500,000
Commodity [Member] | Risk Management Contracts [Member] | Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]	1,700,000			3,400,000
Long-term Risk Management Assets	[8]	0			0
Total Assets	[8]	1,700,000			3,400,000
Current Risk Management Liabilities	[8]	0			700,000
Long-term Risk Management Liabilities	[8]	900,000			1,000,000
Total Liabilities	[8]	900,000			1,700,000
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	800,000			1,700,000
Commodity [Member] | Hedging Contracts [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]	34,800,000			21,100,000
Long-term Risk Management Assets	[8]	18,800,000			18,000,000
Total Assets	[8]	53,600,000			39,100,000
Current Risk Management Liabilities	[8]	34,800,000			54,400,000
Long-term Risk Management Liabilities	[8]	41,600,000			60,100,000
Total Liabilities	[8]	76,400,000			114,500,000
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	(22,800,000)			(75,400,000)
Interest Rate [Member]
Commodity:
Derivative, Notional Amount		950,000,000			1,150,000,000
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		(33,300,000)			(47,500,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		$ (5,100,000)			(5,700,000)
Derivatives and Hedging (Textuals) [Abstract]
Maximum Term for Exposure to Variability of Future Cash Flows		117 months
Deferred (Gain) Loss on Discontinuation of Fair Value Hedge		$ 57,000,000
Notional Amount of a Discontinued Hedge		500,000,000
Interest Rate [Member] | AEP Texas Inc. [Member]
Commodity:
Derivative, Notional Amount		0			0
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		(2,000,000)			(2,300,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		(1,100,000)			(1,100,000)
Interest Rate [Member] | Appalachian Power Co [Member]
Commodity:
Derivative, Notional Amount		0			200,000,000
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		8,200,000			(800,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		800,000			400,000
Interest Rate [Member] | Indiana Michigan Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		(7,800,000)			(8,300,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		(1,600,000)			(1,600,000)
Interest Rate [Member] | Ohio Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0
Interest Rate [Member] | Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Notional Amount		0			0
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		0			100,000
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		0			100,000
Interest Rate [Member] | Southwestern Electric Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		100,000			(300,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months		(1,200,000)			(1,500,000)
Interest Rate [Member] | Hedging Contracts [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]	2,700,000			5,000,000
Long-term Risk Management Assets	[8]	0			0
Total Assets	[8]	2,700,000			5,000,000
Current Risk Management Liabilities	[8]	0			3,400,000
Long-term Risk Management Liabilities	[8]	37,400,000			4,100,000
Total Liabilities	[8]	37,400,000			7,500,000
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	(34,700,000)			(2,500,000)
Interest Rate [Member] | Hedging Contracts [Member] | Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]				2,400,000
Long-term Risk Management Assets	[8]				0
Total Assets	[8]				2,400,000
Current Risk Management Liabilities	[8]				3,400,000
Long-term Risk Management Liabilities	[8]				0
Total Liabilities	[8]				3,400,000
Total MTM Derivative Contract Net Assets (Liabilities)	[8]				(1,000,000)
Gross Amounts of Risk Management Assets/Liabilities Recognized [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		201,600,000			265,200,000
Long-term Risk Management Assets		285,700,000			293,900,000
Total Assets		487,300,000			559,100,000
Current Risk Management Liabilities		168,400,000			250,800,000
Long-term Risk Management Liabilities		298,800,000			286,400,000
Total Liabilities		467,200,000			537,200,000
Total MTM Derivative Contract Net Assets (Liabilities)		20,100,000			21,900,000
Gross Amounts of Risk Management Assets/Liabilities Recognized [Member] | Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets					41,200,000
Long-term Risk Management Assets					700,000
Total Assets					41,900,000
Current Risk Management Liabilities					23,100,000
Long-term Risk Management Liabilities					600,000
Total Liabilities					23,700,000
Total MTM Derivative Contract Net Assets (Liabilities)					18,200,000
Gross Amounts Offset in the Statement of Financial Position [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	(129,500,000)			(170,500,000)
Long-term Risk Management Assets	[9]	(20,900,000)			(51,700,000)
Total Assets	[9]	(150,400,000)			(222,200,000)
Current Risk Management Liabilities	[9]	(129,300,000)			(172,000,000)
Long-term Risk Management Liabilities	[9]	(25,800,000)			(53,600,000)
Total Liabilities	[9]	(155,100,000)			(225,600,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	4,700,000			3,400,000
Gross Amounts Offset in the Statement of Financial Position [Member] | AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	(800,000)			(400,000)
Long-term Risk Management Assets	[9]	0			0
Total Assets	[9]	(800,000)			(400,000)
Current Risk Management Liabilities	[9]	0			0
Long-term Risk Management Liabilities	[9]	0			0
Total Liabilities	[9]	0			0
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	(800,000)			(400,000)
Gross Amounts Offset in the Statement of Financial Position [Member] | Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	(9,600,000)			(18,800,000)
Long-term Risk Management Assets	[9]	(500,000)			(600,000)
Total Assets	[9]	(10,100,000)			(19,400,000)
Current Risk Management Liabilities	[9]	(9,100,000)			(18,500,000)
Long-term Risk Management Liabilities	[9]	(500,000)			(500,000)
Total Liabilities	[9]	(9,600,000)			(19,000,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	(500,000)			(400,000)
Gross Amounts Offset in the Statement of Financial Position [Member] | Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	(5,900,000)			(13,600,000)
Long-term Risk Management Assets	[9]	(300,000)			(400,000)
Total Assets	[9]	(6,200,000)			(14,000,000)
Current Risk Management Liabilities	[9]	(6,000,000)			(12,000,000)
Long-term Risk Management Liabilities	[9]	(300,000)			(300,000)
Total Liabilities	[9]	(6,300,000)			(12,300,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	100,000			(1,700,000)
Gross Amounts Offset in the Statement of Financial Position [Member] | Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	(600,000)			(300,000)
Long-term Risk Management Assets	[9]	0			0
Total Assets	[9]	(600,000)			(300,000)
Current Risk Management Liabilities	[9]	0			0
Long-term Risk Management Liabilities	[9]	0			0
Total Liabilities	[9]	0			0
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	(600,000)			(300,000)
Gross Amounts Offset in the Statement of Financial Position [Member] | Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	(300,000)			(200,000)
Long-term Risk Management Assets	[9]	0			0
Total Assets	[9]	(300,000)			(200,000)
Current Risk Management Liabilities	[9]	0			0
Long-term Risk Management Liabilities	[9]	0			0
Total Liabilities	[9]	0			0
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	(300,000)			(200,000)
Gross Amounts Offset in the Statement of Financial Position [Member] | Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[9]	(400,000)			(200,000)
Long-term Risk Management Assets	[9]	0			0
Total Assets	[9]	(400,000)			(200,000)
Current Risk Management Liabilities	[9]	0			0
Long-term Risk Management Liabilities	[9]	0			0
Total Liabilities	[9]	0			0
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	(400,000)			(200,000)
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[10]	72,100,000			94,700,000
Long-term Risk Management Assets	[10]	264,800,000			242,200,000
Total Assets	[10]	336,900,000			336,900,000
Current Risk Management Liabilities	[10]	39,100,000			78,800,000
Long-term Risk Management Liabilities	[10]	273,000,000			232,800,000
Total Liabilities	[10]	312,100,000			311,600,000
Total MTM Derivative Contract Net Assets (Liabilities)	[10]	24,800,000			25,300,000
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member] | AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[10]	0			0
Long-term Risk Management Assets	[10]	0			0
Total Assets	[10]	0			0
Current Risk Management Liabilities	[10]	0			0
Long-term Risk Management Liabilities	[10]	0			0
Total Liabilities	[10]	0			0
Total MTM Derivative Contract Net Assets (Liabilities)	[10]	0			0
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member] | Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[10]	6,900,000			22,400,000
Long-term Risk Management Assets	[10]	0			100,000
Total Assets	[10]	6,900,000			22,500,000
Current Risk Management Liabilities	[10]	200,000			4,600,000
Long-term Risk Management Liabilities	[10]	0			100,000
Total Liabilities	[10]	200,000			4,700,000
Total MTM Derivative Contract Net Assets (Liabilities)	[10]	6,700,000			17,800,000
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member] | Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[10]	900,000			3,600,000
Long-term Risk Management Assets	[10]	0			100,000
Total Assets	[10]	900,000			3,700,000
Current Risk Management Liabilities	[10]	200,000			100,000
Long-term Risk Management Liabilities	[10]	0			100,000
Total Liabilities	[10]	200,000			200,000
Total MTM Derivative Contract Net Assets (Liabilities)	[10]	700,000			3,500,000
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member] | Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[10]	0			0
Long-term Risk Management Assets	[10]	0			0
Total Assets	[10]	0			0
Current Risk Management Liabilities	[10]	8,100,000			8,700,000
Long-term Risk Management Liabilities	[10]	95,900,000			101,600,000
Total Liabilities	[10]	104,000,000			110,300,000
Total MTM Derivative Contract Net Assets (Liabilities)	[10]	(104,000,000)			(110,300,000)
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member] | Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[10]	5,500,000			10,300,000
Long-term Risk Management Assets	[10]	0			0
Total Assets	[10]	5,500,000			10,300,000
Current Risk Management Liabilities	[10]	0			0
Long-term Risk Management Liabilities	[10]	0			0
Total Liabilities	[10]	0			0
Total MTM Derivative Contract Net Assets (Liabilities)	[10]	5,500,000			10,300,000
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member] | Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[10]	1,300,000			3,200,000
Long-term Risk Management Assets	[10]	0			0
Total Assets	[10]	1,300,000			3,200,000
Current Risk Management Liabilities	[10]	0			700,000
Long-term Risk Management Liabilities	[10]	900,000			1,000,000
Total Liabilities	[10]	900,000			1,700,000
Total MTM Derivative Contract Net Assets (Liabilities)	[10]	$ 400,000			$ 1,500,000
Power [Member]
Commodity:
Derivative, Energy Notional Amount | MWh		271.2			331.3
Power [Member] | AEP Texas Inc. [Member]
Commodity:
Derivative, Energy Notional Amount | MWh		0			0
Power [Member] | Appalachian Power Co [Member]
Commodity:
Derivative, Energy Notional Amount | MWh		23.3			46.9
Power [Member] | Indiana Michigan Power Co [Member]
Commodity:
Derivative, Energy Notional Amount | MWh		10.8			19.7
Power [Member] | Ohio Power Co [Member]
Commodity:
Derivative, Energy Notional Amount | MWh		2.9			3
Power [Member] | Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Energy Notional Amount | MWh		3.8			11.9
Power [Member] | Southwestern Electric Power Co [Member]
Commodity:
Derivative, Energy Notional Amount | MWh		1.6			4
Natural Gas [Member]
Commodity:
Derivative, Energy Notional Amount | MMBTU		22.7			26.9
Natural Gas [Member] | AEP Texas Inc. [Member]
Commodity:
Derivative, Energy Notional Amount | MMBTU		0			0
Natural Gas [Member] | Appalachian Power Co [Member]
Commodity:
Derivative, Energy Notional Amount | MMBTU		0			0
Natural Gas [Member] | Indiana Michigan Power Co [Member]
Commodity:
Derivative, Energy Notional Amount | MMBTU		0			0
Natural Gas [Member] | Ohio Power Co [Member]
Commodity:
Derivative, Energy Notional Amount | MMBTU		0			0
Natural Gas [Member] | Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Energy Notional Amount | MMBTU		0			0
Natural Gas [Member] | Southwestern Electric Power Co [Member]
Commodity:
Derivative, Energy Notional Amount | MMBTU		7			7.9
Heating Oil and Gasoline [Member]
Commodity:
Derivative, Volume Notional Amount | gal		5			6.9
Heating Oil and Gasoline [Member] | AEP Texas Inc. [Member]
Commodity:
Derivative, Volume Notional Amount | gal		1.3			1.8
Heating Oil and Gasoline [Member] | Appalachian Power Co [Member]
Commodity:
Derivative, Volume Notional Amount | gal		0.8			1.1
Heating Oil and Gasoline [Member] | Indiana Michigan Power Co [Member]
Commodity:
Derivative, Volume Notional Amount | gal		0.5			0.6
Heating Oil and Gasoline [Member] | Ohio Power Co [Member]
Commodity:
Derivative, Volume Notional Amount | gal		1			1.4
Heating Oil and Gasoline [Member] | Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Volume Notional Amount | gal		0.5			0.7
Heating Oil and Gasoline [Member] | Southwestern Electric Power Co [Member]
Commodity:
Derivative, Volume Notional Amount | gal		0.7			0.9
Interest Rate Contract [Member]
Commodity:
Derivative, Notional Amount		$ 123,600,000			$ 129,800,000
Interest Rate Contract [Member] | AEP Texas Inc. [Member]
Commodity:
Derivative, Notional Amount		0			0
Interest Rate Contract [Member] | Appalachian Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0
Interest Rate Contract [Member] | Indiana Michigan Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0
Interest Rate Contract [Member] | Ohio Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0
Interest Rate Contract [Member] | Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Notional Amount		0			0
Interest Rate Contract [Member] | Southwestern Electric Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0
Warrants Held in Investee
Fair Value of Derivative Instruments
Total Assets		22,000,000			$ 32,000,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		10,000,000
Vertically Integrated Utilities Revenues [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		200,000		400,000
Vertically Integrated Utilities Revenues [Member] | AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Vertically Integrated Utilities Revenues [Member] | Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Vertically Integrated Utilities Revenues [Member] | Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Vertically Integrated Utilities Revenues [Member] | Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Vertically Integrated Utilities Revenues [Member] | Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Vertically Integrated Utilities Revenues [Member] | Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Generation and Marketing Revenues [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(400,000)		(10,300,000)
Generation and Marketing Revenues [Member] | AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Generation and Marketing Revenues [Member] | Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Generation and Marketing Revenues [Member] | Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Generation and Marketing Revenues [Member] | Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Generation and Marketing Revenues [Member] | Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Generation and Marketing Revenues [Member] | Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Electric Generation, Transmission and Distribution Revenues [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Electric Generation, Transmission and Distribution Revenues [Member] | AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Electric Generation, Transmission and Distribution Revenues [Member] | Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		200,000		200,000
Electric Generation, Transmission and Distribution Revenues [Member] | Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		100,000
Electric Generation, Transmission and Distribution Revenues [Member] | Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Electric Generation, Transmission and Distribution Revenues [Member] | Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Electric Generation, Transmission and Distribution Revenues [Member] | Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Purchased Electricity for Resale [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		400,000		100,000
Purchased Electricity for Resale [Member] | AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Purchased Electricity for Resale [Member] | Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		400,000		100,000
Purchased Electricity for Resale [Member] | Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Purchased Electricity for Resale [Member] | Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Purchased Electricity for Resale [Member] | Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Purchased Electricity for Resale [Member] | Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Other Operation Expense [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		300,000		(200,000)
Other Operation Expense [Member] | AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		100,000		(100,000)
Other Operation Expense [Member] | Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Other Operation Expense [Member] | Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Other Operation Expense [Member] | Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		100,000		(100,000)
Other Operation Expense [Member] | Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Other Operation Expense [Member] | Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0
Maintenance Expense [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		500,000		(200,000)
Maintenance Expense [Member] | AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		100,000		(100,000)
Maintenance Expense [Member] | Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		100,000		(100,000)
Maintenance Expense [Member] | Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		100,000		0
Maintenance Expense [Member] | Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		100,000		0
Maintenance Expense [Member] | Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		100,000		0
Maintenance Expense [Member] | Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		100,000		0
Regulatory Assets [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	6,400,000		(33,900,000)
Regulatory Assets [Member] | AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	0		(1,200,000)
Regulatory Assets [Member] | Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	0		(8,900,000)
Regulatory Assets [Member] | Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	(900,000)		(700,000)
Regulatory Assets [Member] | Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	6,600,000		(18,400,000)
Regulatory Assets [Member] | Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	0		(500,000)
Regulatory Assets [Member] | Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	800,000		(200,000)
Regulatory Liabilities [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	22,000,000		11,200,000
Regulatory Liabilities [Member] | AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	400,000		0
Regulatory Liabilities [Member] | Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	3,400,000		(7,300,000)
Regulatory Liabilities [Member] | Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	(3,200,000)		3,200,000
Regulatory Liabilities [Member] | Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	2,900,000		3,500,000
Regulatory Liabilities [Member] | Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	11,200,000		8,100,000
Regulatory Liabilities [Member] | Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	$ 6,200,000		$ 3,300,000
[1]	Amounts include $(51) million and $(53) million as of March 31, 2021 and December 31, 2020, respectively, for the fair value hedge adjustment of hedged debt obligations for which hedge accounting has been discontinued.
[2]	Amounts included on the balance sheets within Long-term Debt Due within One Year and Long-term Debt, respectively.
[3]	Gain (Loss) is included in Interest Expense on the statements of income.
[4]	Amounts in “Other’’ column primarily represent counterparty netting of risk management and hedging contracts and associated cash collateral under the accounting guidance for “Derivatives and Hedging.’’
[5]	The March 31, 2021 maturity of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 2 matures $(3) million in 2021, $11 million in periods 2022-2024, $17 million in periods 2025-2026 and $10 million in periods 2027-2033; Level 3 matures $23 million in 2021, $32 million in periods 2022-2024, $8 million in periods 2025-2026 and $(21) million in periods 2027-2033.  Risk management commodity contracts are substantially comprised of power contracts.
[6]	The December 31, 2020 maturity of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 2 matures $3 million in periods 2022-2024, $11 million in periods 2025-2026 and $1 million in periods 2027-2033; Level 3 matures $47 million in 2021, $37 million in periods 2022-2024, $14 million in periods 2025-2026 and $(13) million in periods 2027-2033.  Risk management commodity contracts are substantially comprised of power contracts.
[7]	Substantially comprised of power contracts for the Registrant Subsidiaries.
[8]	Derivative instruments within these categories are reported gross.  These instruments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with the accounting guidance for “Derivatives and Hedging.”
[9]	Amounts include counterparty netting of risk management and hedging contracts and associated cash collateral in accordance with the accounting guidance for “Derivatives and Hedging.”
[10]	All derivative contracts subject to a master netting arrangement or similar agreement are offset in the statement of financial position.
[11]	Represents realized and unrealized gains and losses subject to regulatory accounting treatment recorded as either current or noncurrent on the balance sheets.

Fair Value Long-term Debt, Othe

Fair Value Long-term Debt, Other Temporary Investments, Nuclear Trusts (Details) - USD ($)		3 Months Ended			12 Months Ended
		Mar. 31, 2021		Mar. 31, 2020	Dec. 31, 2020
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		$ 32,345,000,000			$ 31,072,500,000
Long Term Debt, Fair Value	[1]	35,802,400,000			37,457,000,000
Other Temporary Investments
Cost		216,200,000			214,900,000
Gross Unrealized Gains		33,700,000			31,500,000
Gross Unrealized Losses		0			0
Other Short-term Investments		249,900,000			246,400,000
Debt and Equity Securities Within Other Temporary Investments
Proceeds from Investment Sales		5,500,000		$ 23,200,000
Purchases of Investments		700,000		6,700,000
Gross Realized Gains on Investment Sales		100,000		2,000,000
Gross Realized Losses on Investment Sales		0		100,000
Nuclear Trust Fund Investments
Fair Value		3,414,300,000			3,306,700,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		3,414,300,000			3,306,700,000
Spent Nuclear Fuel and Decommissioning Trusts [Member]
Unrealized Gain on Securities		1,500,000,000			1,400,000,000
Nuclear Trust Fund Investments
Gross Unrealized Gains		1,603,500,000			1,509,800,000
Other-Than-Temporary Impairments		(16,300,000)			(9,200,000)
Securities Activity Within Decommissioning and SNF Trusts
Proceeds from Investment Sales		320,000,000		612,400,000
Purchases of Investments		336,900,000		626,000,000
Gross Realized Gains on Investment Sales		5,400,000		10,900,000
Gross Realized Losses on Investment Sales		4,200,000		17,000,000
Contractual Maturities, Fair Value of Debt Securities
Within 1 year		320,500,000
After 1 year through 5 years		334,700,000
After 5 years through 10 years		233,600,000
After 10 years		270,300,000
Fair Value Measurements (Textuals)
Adjusted Cost of Debt Securities		1,100,000,000			1,100,000,000
Adjusted Cost of Domestic Equity Securities		664,000,000			654,000,000
Unrealized Loss on Securities		5,000,000			9,000,000
Cash [Member]
Other Temporary Investments
Cost	[2]	74,600,000			68,300,000
Gross Unrealized Gains	[2]	0			0
Gross Unrealized Losses	[2]	0			0
Other Short-term Investments	[2],[3]	74,600,000			68,300,000
Fixed Income Funds [Member]
Nuclear Trust Fund Investments
Fair Value		1,159,100,000			1,226,200,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,159,100,000			1,226,200,000
Fixed Income Funds [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		60,000,000			109,000,000
Other-Than-Temporary Impairments		(16,300,000)			(9,200,000)
Mutual Funds Fixed Income [Member]
Other Temporary Investments
Cost	[4]	116,700,000			120,700,000
Gross Unrealized Gains	[4]	2,000,000			2,800,000
Gross Unrealized Losses	[4]	0			0
Other Short-term Investments	[4]	118,700,000			123,500,000
Domestic [Member]
Nuclear Trust Fund Investments
Fair Value	[5]	2,207,500,000			2,054,700,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[5]	2,207,500,000			2,054,700,000
Domestic [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains	[6]	1,543,500,000			1,400,800,000
Other-Than-Temporary Impairments		0			0
Mutual Funds Equity [Member]
Other Temporary Investments
Cost		24,900,000			25,900,000
Gross Unrealized Gains		31,700,000			28,700,000
Gross Unrealized Losses		0			0
Other Short-term Investments	[5]	56,600,000			54,600,000
Cash and Cash Equivalents [Member]
Nuclear Trust Fund Investments
Fair Value	[7]	47,700,000			25,800,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[7]	47,700,000			25,800,000
Cash and Cash Equivalents [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		0			0
Other-Than-Temporary Impairments		0			0
US Government Agencies Debt Securities [Member]
Nuclear Trust Fund Investments
Fair Value		998,900,000			1,025,600,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		998,900,000			1,025,600,000
US Government Agencies Debt Securities [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		54,800,000			98,500,000
Other-Than-Temporary Impairments		(13,000,000)			(7,100,000)
Corporate Debt [Member]
Nuclear Trust Fund Investments
Fair Value		76,400,000			86,300,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		76,400,000			86,300,000
Corporate Debt [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		4,800,000			9,600,000
Other-Than-Temporary Impairments		(2,600,000)			(1,700,000)
State and Local Jurisdiction [Member]
Nuclear Trust Fund Investments
Fair Value		83,800,000			114,300,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		83,800,000			114,300,000
State and Local Jurisdiction [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		400,000			900,000
Other-Than-Temporary Impairments		(700,000)			(400,000)
AEP Texas Inc. [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		4,810,200,000			4,820,400,000
Long Term Debt, Fair Value		5,235,600,000			5,682,600,000
AEP Transmission Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		3,949,000,000			3,948,500,000
Long Term Debt, Fair Value		4,460,100,000			4,984,300,000
Appalachian Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		4,966,200,000			4,834,100,000
Long Term Debt, Fair Value		5,871,100,000			6,391,800,000
Indiana Michigan Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		3,006,300,000			3,029,900,000
Long Term Debt, Fair Value		3,422,900,000			3,775,300,000
Nuclear Trust Fund Investments
Fair Value		3,414,300,000			3,306,700,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		3,414,300,000			3,306,700,000
Indiana Michigan Power Co [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Unrealized Gain on Securities		1,500,000,000			1,400,000,000
Nuclear Trust Fund Investments
Gross Unrealized Gains		1,603,500,000			1,509,800,000
Other-Than-Temporary Impairments		(16,300,000)			(9,200,000)
Securities Activity Within Decommissioning and SNF Trusts
Proceeds from Investment Sales		320,000,000		612,400,000
Purchases of Investments		336,900,000		626,000,000
Gross Realized Gains on Investment Sales		5,400,000		10,900,000
Gross Realized Losses on Investment Sales		4,200,000		$ 17,000,000
Contractual Maturities, Fair Value of Debt Securities
Within 1 year		320,500,000
After 1 year through 5 years		334,700,000
After 5 years through 10 years		233,600,000
After 10 years		270,300,000
Fair Value Measurements (Textuals)
Adjusted Cost of Debt Securities		1,100,000,000			1,100,000,000
Adjusted Cost of Domestic Equity Securities		664,000,000			654,000,000
Unrealized Loss on Securities		5,000,000			9,000,000
Indiana Michigan Power Co [Member] | Fixed Income Funds [Member]
Nuclear Trust Fund Investments
Fair Value		1,159,100,000			1,226,200,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,159,100,000			1,226,200,000
Indiana Michigan Power Co [Member] | Fixed Income Funds [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		60,000,000			109,000,000
Other-Than-Temporary Impairments		(16,300,000)			(9,200,000)
Indiana Michigan Power Co [Member] | Domestic [Member]
Nuclear Trust Fund Investments
Fair Value	[5]	2,207,500,000			2,054,700,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[5]	2,207,500,000			2,054,700,000
Indiana Michigan Power Co [Member] | Domestic [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		1,543,500,000	[6]		1,400,800,000
Other-Than-Temporary Impairments		0			0
Indiana Michigan Power Co [Member] | Cash and Cash Equivalents [Member]
Nuclear Trust Fund Investments
Fair Value	[7]	47,700,000			25,800,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[7]	47,700,000			25,800,000
Indiana Michigan Power Co [Member] | Cash and Cash Equivalents [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		0			0
Other-Than-Temporary Impairments		0			0
Indiana Michigan Power Co [Member] | US Government Agencies Debt Securities [Member]
Nuclear Trust Fund Investments
Fair Value		998,900,000			1,025,600,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		998,900,000			1,025,600,000
Indiana Michigan Power Co [Member] | US Government Agencies Debt Securities [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		54,800,000			98,500,000
Other-Than-Temporary Impairments		(13,000,000)			(7,100,000)
Indiana Michigan Power Co [Member] | Corporate Debt [Member]
Nuclear Trust Fund Investments
Fair Value		76,400,000			86,300,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		76,400,000			86,300,000
Indiana Michigan Power Co [Member] | Corporate Debt [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		4,800,000			9,600,000
Other-Than-Temporary Impairments		(2,600,000)			(1,700,000)
Indiana Michigan Power Co [Member] | State and Local Jurisdiction [Member]
Nuclear Trust Fund Investments
Fair Value		83,800,000			114,300,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		83,800,000			114,300,000
Indiana Michigan Power Co [Member] | State and Local Jurisdiction [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains		400,000			900,000
Other-Than-Temporary Impairments		(700,000)			(400,000)
Ohio Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		2,876,300,000			2,430,200,000
Long Term Debt, Fair Value		3,316,100,000			3,154,900,000
Public Service Co Of Oklahoma [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		1,623,800,000			1,373,800,000
Long Term Debt, Fair Value		1,842,400,000			1,732,100,000
Southwestern Electric Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		3,131,400,000			2,636,400,000
Long Term Debt, Fair Value		3,444,800,000			3,210,100,000
Equity Units [Member]
Book Values and Fair Values of Long - term Debt
Long Term Debt, Fair Value		$ 1,600,000,000			$ 1,700,000,000
[1]	The fair value amounts include debt related to AEP’s Equity Units and had a fair value of $1.6 billion and $1.7 billion as of March 31, 2021 and December 31, 2020, respectively. See “Equity Units” section of Note 12 for additional information.
[2]	Primarily represents amounts held for the repayment of debt.
[3]	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.
[4]	Primarily short and intermediate maturities which may be sold and do not contain maturity dates.
[5]	Amounts represent publicly traded equity securities and equity-based mutual funds.
[6]	Amount reported as Gross Unrealized Gains includes unrealized gains of $1.5 billion and $1.4 billion and unrealized losses of $5 million and $9 million as of March 31, 2021 and December 31, 2020, respectively.
[7]	Amounts in “Other’’ column primarily represent accrued interest receivables from financial institutions.  Level 1 amounts primarily represent investments in money market funds.

Fair Value Assets and Liabiliti

Fair Value Assets and Liabilities (Details) - USD ($)		3 Months Ended
		Mar. 31, 2021		Mar. 31, 2020	Dec. 31, 2020
Other [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		$ 11,700,000			$ 10,500,000
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		8,200,000			9,000,000
Total Assets		(106,900,000)			(199,000,000)
Risk Management Assets
Risk Management Assets		(126,800,000)			(218,500,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities		(131,500,000)			(221,900,000)
Other Short-term Investments		249,900,000			246,400,000
Spent Nuclear Fuel and Decommissioning Trusts		3,414,300,000			3,306,700,000
Total Assets		4,057,800,000			3,921,800,000
Risk Management Assets		336,900,000			336,900,000
Risk Management Liabilities		312,100,000			311,600,000
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		113,300,000		$ 109,900,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	19,800,000		900,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	(21,300,000)		10,900,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Other Comprehensive Income (Loss)	[3]	3,100,000		(4,100,000)
Settlements		(47,900,000)		(59,200,000)
Transfers into Level 3	[4],[5]	500,000		(500,000)
Transfers out of Level 3	[5]	(33,000,000)		5,300,000
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	7,300,000		(20,700,000)
Ending Balance		41,800,000		42,500,000
Level 1 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		238,200,000			235,900,000
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		2,247,000,000			2,071,500,000
Total Assets		2,486,400,000			2,308,300,000
Risk Management Assets
Risk Management Assets		1,200,000			900,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		800,000			900,000
Level 2 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,159,100,000			1,226,200,000
Total Assets		1,480,800,000			1,524,400,000
Risk Management Assets
Risk Management Assets		265,000,000			298,200,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		287,100,000			357,800,000
Level 3 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Total Assets		197,500,000			288,100,000
Risk Management Assets
Risk Management Assets		197,500,000			256,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		155,700,000			174,800,000
2021 [Member] | Level 2 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		(3,000,000)
2021 [Member] | Level 3 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		23,000,000			47,000,000
2022 - 2024 [Member] | Level 2 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		11,000,000			3,000,000
2022 - 2024 [Member] | Level 3 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		32,000,000			37,000,000
2025 - 2026 [Member] | Level 2 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		17,000,000			11,000,000
2025 - 2026 [Member] | Level 3 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		8,000,000			14,000,000
2027 - 2033 [Member] | Level 2 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		10,000,000			1,000,000
2027 - 2033 [Member] | Level 3 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		(21,000,000)			(13,000,000)
Risk Management Commodity Contracts [Member] | Other [Member]
Risk Management Assets
Risk Management Assets	[7]	(94,800,000)	[8]		(190,000,000)	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	(99,500,000)	[8]		(193,400,000)	[9]
Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[7]	319,100,000	[8]		322,100,000	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	236,800,000	[8]		218,900,000	[9]
Risk Management Commodity Contracts [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets	[7]	1,200,000	[8]		900,000	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	800,000	[8]		900,000	[9]
Risk Management Commodity Contracts [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[7]	217,900,000	[8]		258,800,000	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	182,700,000	[8]		244,200,000	[9]
Risk Management Commodity Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[7]	194,800,000	[8]		252,400,000	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	152,800,000	[8]		167,200,000	[9]
Energy Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		178,500,000			213,500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		151,700,000			169,700,000
Energy Contracts [Member] | Level 3 [Member] | Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	0.10			5.33
Energy Contracts [Member] | Level 3 [Member] | High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	98.66			100.47
Energy Contracts [Member] | Level 3 [Member] | Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	28.85			32.73
Natural Gas Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		900,000			1,700,000
Natural Gas Contracts [Member] | Level 3 [Member] | Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[12]	2.24			2.18
Natural Gas Contracts [Member] | Level 3 [Member] | High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[12]	2.92			2.77
Natural Gas Contracts [Member] | Level 3 [Member] | Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[11],[12]	2.50			2.40
FTRs [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		19,000,000			42,800,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		3,100,000			3,400,000
FTRs [Member] | Level 3 [Member] | Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	(13.61)			(15.08)
FTRs [Member] | Level 3 [Member] | High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	9.08			9.66
FTRs [Member] | Level 3 [Member] | Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	0.02			0.19
Commodity Hedges [Member] | Other [Member]
Risk Management Assets
Risk Management Assets	[7]	(32,000,000)			(28,500,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	(32,000,000)			(28,500,000)
Commodity Hedges [Member]
Risk Management Assets
Risk Management Assets	[7]	15,100,000			9,800,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	37,900,000			85,200,000
Commodity Hedges [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets	[7]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	0			0
Commodity Hedges [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[7]	44,400,000			34,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	67,000,000			106,100,000
Commodity Hedges [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[7]	2,700,000			3,900,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	2,900,000			7,600,000
Interest Rate [Member] | Other [Member]
Risk Management Assets
Risk Management Assets					0
Interest Rate [Member]
Risk Management Assets
Risk Management Assets					2,400,000
Interest Rate [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets					0
Interest Rate [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets					2,400,000
Interest Rate [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets					0
Fair Value Hedges [Member] | Other [Member]
Risk Management Assets
Risk Management Assets		0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0
Fair Value Hedges [Member]
Risk Management Assets
Risk Management Assets		2,700,000			2,600,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		37,400,000			4,100,000
Fair Value Hedges [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets		0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0
Fair Value Hedges [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets		2,700,000			2,600,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		37,400,000			4,100,000
Fair Value Hedges [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0
Other Investments | Other [Member]
Risk Management Assets
Risk Management Assets	[13]	0			0
Other Investments
Risk Management Assets
Risk Management Assets	[13]	56,700,000			31,800,000
Other Investments | Level 1 [Member]
Risk Management Assets
Risk Management Assets	[13]	0			0
Other Investments | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[13]	56,700,000			0
Other Investments | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[13]	0			31,800,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities					0
Other Investments | Level 3 [Member] | Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[14]				0.10
Other Investments | Level 3 [Member] | High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[14]				0.20
Other Investments | Level 3 [Member] | Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[14]				0.15
Interest Rate Foreign Currency Hedges | Other [Member]
Liabilities, Fair Value Disclosure
Risk Management Liabilities					0
Interest Rate Foreign Currency Hedges
Liabilities, Fair Value Disclosure
Risk Management Liabilities					3,400,000
Interest Rate Foreign Currency Hedges | Level 1 [Member]
Liabilities, Fair Value Disclosure
Risk Management Liabilities					0
Interest Rate Foreign Currency Hedges | Level 2 [Member]
Liabilities, Fair Value Disclosure
Risk Management Liabilities					3,400,000
Interest Rate Foreign Currency Hedges | Level 3 [Member]
Liabilities, Fair Value Disclosure
Risk Management Liabilities					0
AEP Texas Inc. [Member] | Other [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		(800,000)			(400,000)
AEP Texas Inc. [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		39,300,000			28,700,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		39,300,000			28,700,000
AEP Texas Inc. [Member] | Level 1 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		39,300,000			28,700,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		39,300,000			28,700,000
AEP Texas Inc. [Member] | Level 2 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		800,000			400,000
AEP Texas Inc. [Member] | Level 3 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		0			0
AEP Texas Inc. [Member] | Risk Management Commodity Contracts [Member] | Other [Member]
Risk Management Assets
Risk Management Assets	[7]	(800,000)			(400,000)
AEP Texas Inc. [Member] | Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[7]	0			0
AEP Texas Inc. [Member] | Risk Management Commodity Contracts [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets	[7]	0			0
AEP Texas Inc. [Member] | Risk Management Commodity Contracts [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[7]	800,000			400,000
AEP Texas Inc. [Member] | Risk Management Commodity Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[7]	0			0
Appalachian Power Co [Member] | Other [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		(10,000,000)			(19,200,000)
Risk Management Assets
Risk Management Assets					(19,200,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities					(18,800,000)
Appalachian Power Co [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		11,600,000			16,900,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		18,500,000			39,400,000
Risk Management Assets
Risk Management Assets					22,500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities					4,700,000
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		19,300,000		37,700,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	2,100,000		(9,200,000)
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	0		0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Other Comprehensive Income (Loss)	[3]	0		0
Settlements		(15,600,000)		(21,900,000)
Transfers into Level 3	[4],[5]	0		0
Transfers out of Level 3	[5]	0		700,000
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	800,000		(700,000)
Ending Balance		6,600,000		6,600,000
Appalachian Power Co [Member] | Level 1 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		11,600,000			16,900,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		11,600,000			16,900,000
Risk Management Assets
Risk Management Assets					0
Liabilities, Fair Value Disclosure
Risk Management Liabilities					0
Appalachian Power Co [Member] | Level 2 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		9,800,000			21,800,000
Risk Management Assets
Risk Management Assets					21,800,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities					22,900,000
Appalachian Power Co [Member] | Level 3 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		7,100,000			19,900,000
Risk Management Assets
Risk Management Assets		7,100,000			19,900,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		500,000			600,000
Appalachian Power Co [Member] | Risk Management Commodity Contracts [Member] | Other [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	(10,000,000)			(19,200,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	(9,500,000)			(18,800,000)
Appalachian Power Co [Member] | Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	6,900,000			20,100,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	200,000			1,300,000
Appalachian Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	0			0
Appalachian Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	9,800,000			19,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	9,200,000			19,500,000
Appalachian Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	7,100,000			19,900,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	500,000			600,000
Appalachian Power Co [Member] | Energy Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		400,000			1,000,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		500,000			600,000
Appalachian Power Co [Member] | Energy Contracts [Member] | Level 3 [Member] | Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	10.92			10.84
Appalachian Power Co [Member] | Energy Contracts [Member] | Level 3 [Member] | High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	44.29			41.09
Appalachian Power Co [Member] | Energy Contracts [Member] | Level 3 [Member] | Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	25.13			25.08
Appalachian Power Co [Member] | FTRs [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		6,700,000			18,900,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0
Appalachian Power Co [Member] | FTRs [Member] | Level 3 [Member] | Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	0.08			0.04
Appalachian Power Co [Member] | FTRs [Member] | Level 3 [Member] | High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	4.99			5.61
Appalachian Power Co [Member] | FTRs [Member] | Level 3 [Member] | Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	0.99			1.13
Appalachian Power Co [Member] | Interest Rate Foreign Currency Hedges | Other [Member]
Risk Management Assets
Risk Management Assets					0
Liabilities, Fair Value Disclosure
Risk Management Liabilities					0
Appalachian Power Co [Member] | Interest Rate Foreign Currency Hedges
Risk Management Assets
Risk Management Assets					2,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities					3,400,000
Appalachian Power Co [Member] | Interest Rate Foreign Currency Hedges | Level 1 [Member]
Risk Management Assets
Risk Management Assets					0
Liabilities, Fair Value Disclosure
Risk Management Liabilities					0
Appalachian Power Co [Member] | Interest Rate Foreign Currency Hedges | Level 2 [Member]
Risk Management Assets
Risk Management Assets					2,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities					3,400,000
Appalachian Power Co [Member] | Interest Rate Foreign Currency Hedges | Level 3 [Member]
Risk Management Assets
Risk Management Assets					0
Liabilities, Fair Value Disclosure
Risk Management Liabilities					0
Indiana Michigan Power Co [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		8,200,000			9,000,000
Total Assets		2,000,000			(4,900,000)
Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		3,414,300,000			3,306,700,000
Total Assets		3,415,200,000			3,310,400,000
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		2,100,000		5,800,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	300,000		200,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	0		0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Other Comprehensive Income (Loss)	[3]	0		0
Settlements		(1,400,000)		(4,000,000)
Transfers into Level 3	[4],[5]	0		0
Transfers out of Level 3	[5]	0		400,000
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	(300,000)		(300,000)
Ending Balance		700,000		2,100,000
Indiana Michigan Power Co [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		2,247,000,000			2,071,500,000
Total Assets		2,247,000,000			2,071,500,000
Indiana Michigan Power Co [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,159,100,000			1,226,200,000
Total Assets		1,165,100,000			1,241,300,000
Indiana Michigan Power Co [Member] | Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Total Assets		1,100,000			2,500,000
Risk Management Assets
Risk Management Assets		1,100,000			2,500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		400,000			400,000
Indiana Michigan Power Co [Member] | Risk Management Commodity Contracts [Member] | Other [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	(6,200,000)			(13,900,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	(6,300,000)			(12,200,000)
Indiana Michigan Power Co [Member] | Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	900,000			3,700,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	200,000			200,000
Indiana Michigan Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	0			0
Indiana Michigan Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	6,000,000			15,100,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	6,100,000			12,000,000
Indiana Michigan Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	1,100,000			2,500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	400,000			400,000
Indiana Michigan Power Co [Member] | Energy Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		300,000			600,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		300,000			300,000
Indiana Michigan Power Co [Member] | Energy Contracts [Member] | Level 3 [Member] | Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	10.92			10.84
Indiana Michigan Power Co [Member] | Energy Contracts [Member] | Level 3 [Member] | High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	44.29			41.09
Indiana Michigan Power Co [Member] | Energy Contracts [Member] | Level 3 [Member] | Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	25.13			25.08
Indiana Michigan Power Co [Member] | FTRs [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		800,000			1,900,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		100,000			100,000
Indiana Michigan Power Co [Member] | FTRs [Member] | Level 3 [Member] | Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	(2.29)			(1.96)
Indiana Michigan Power Co [Member] | FTRs [Member] | Level 3 [Member] | High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	3.66			3.69
Indiana Michigan Power Co [Member] | FTRs [Member] | Level 3 [Member] | Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	0.33			0.33
Ohio Power Co [Member]
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		(110,300,000)		(103,600,000)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	0		(300,000)
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	0		0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Other Comprehensive Income (Loss)	[3]	0		0
Settlements		2,700,000		2,500,000
Transfers into Level 3	[4],[5]	0		0
Transfers out of Level 3	[5]	0		0
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	3,600,000		(19,500,000)
Ending Balance		(104,000,000)		(120,900,000)
Ohio Power Co [Member] | Risk Management Commodity Contracts [Member] | Other [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	(600,000)			(300,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	0			0
Ohio Power Co [Member] | Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	104,000,000			110,300,000
Ohio Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	0			0
Ohio Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	600,000			300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	0			0
Ohio Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	104,000,000			110,300,000
Ohio Power Co [Member] | Energy Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		104,000,000			110,300,000
Ohio Power Co [Member] | Energy Contracts [Member] | Level 3 [Member] | Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	15.08			16.19
Ohio Power Co [Member] | Energy Contracts [Member] | Level 3 [Member] | High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	49.09			46.98
Ohio Power Co [Member] | Energy Contracts [Member] | Level 3 [Member] | Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	27.79			28.30
Public Service Co Of Oklahoma [Member]
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		10,300,000		15,800,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	9,300,000		8,000,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	0		0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Other Comprehensive Income (Loss)	[3]	0		0
Settlements		(16,300,000)		(17,700,000)
Transfers into Level 3	[4],[5]	0		0
Transfers out of Level 3	[5]	0		0
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	2,200,000		200,000
Ending Balance		5,500,000		6,300,000
Public Service Co Of Oklahoma [Member] | Risk Management Commodity Contracts [Member] | Other [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	(300,000)			(200,000)
Public Service Co Of Oklahoma [Member] | Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	5,500,000			10,300,000
Public Service Co Of Oklahoma [Member] | Risk Management Commodity Contracts [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	0			0
Public Service Co Of Oklahoma [Member] | Risk Management Commodity Contracts [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	300,000			200,000
Public Service Co Of Oklahoma [Member] | Risk Management Commodity Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	5,500,000			10,300,000
Public Service Co Of Oklahoma [Member] | FTRs [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		5,500,000			10,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0
Public Service Co Of Oklahoma [Member] | FTRs [Member] | Level 3 [Member] | Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	(13.61)			(6.93)
Public Service Co Of Oklahoma [Member] | FTRs [Member] | Level 3 [Member] | High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	2.04			0.48
Public Service Co Of Oklahoma [Member] | FTRs [Member] | Level 3 [Member] | Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	(3.01)			(1.93)
Southwestern Electric Power Co [Member]
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		1,600,000		1,400,000
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	[1],[2]	6,100,000		1,900,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	0		0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Other Comprehensive Income (Loss)	[3]	0		0
Settlements		(8,200,000)		(5,300,000)
Transfers into Level 3	[4],[5]	0		0
Transfers out of Level 3	[5]	0		0
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	1,000,000		(500,000)
Ending Balance		500,000		$ (2,500,000)
Southwestern Electric Power Co [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		1,400,000			3,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		900,000			1,700,000
Southwestern Electric Power Co [Member] | Risk Management Commodity Contracts [Member] | Other [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	(400,000)			(200,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	0			0
Southwestern Electric Power Co [Member] | Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	1,300,000			3,200,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	900,000			1,700,000
Southwestern Electric Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	0			0
Southwestern Electric Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	300,000			100,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	0			0
Southwestern Electric Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	1,400,000			3,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	900,000			1,700,000
Southwestern Electric Power Co [Member] | Natural Gas Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		900,000			1,700,000
Southwestern Electric Power Co [Member] | Natural Gas Contracts [Member] | Level 3 [Member] | Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[12]	2.24			2.18
Southwestern Electric Power Co [Member] | Natural Gas Contracts [Member] | Level 3 [Member] | High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[12]	2.92			2.77
Southwestern Electric Power Co [Member] | Natural Gas Contracts [Member] | Level 3 [Member] | Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[11],[12]	2.50			2.41
Southwestern Electric Power Co [Member] | FTRs [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		1,400,000			3,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0
Southwestern Electric Power Co [Member] | FTRs [Member] | Level 3 [Member] | Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	(13.61)			(6.93)
Southwestern Electric Power Co [Member] | FTRs [Member] | Level 3 [Member] | High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	2.04			0.48
Southwestern Electric Power Co [Member] | FTRs [Member] | Level 3 [Member] | Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	(3.01)			(1.93)
Cash [Member] | Other [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[16]	11,700,000			10,500,000
Cash [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[16],[17]	74,600,000			68,300,000
Cash [Member] | Level 1 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[16]	62,900,000			57,800,000
Cash [Member] | Level 2 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[16]	0			0
Cash [Member] | Level 3 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[16]	0			0
Fixed Income Funds [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Fixed Income Funds [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,159,100,000			1,226,200,000
Fixed Income Funds [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Fixed Income Funds [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,159,100,000			1,226,200,000
Fixed Income Funds [Member] | Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Fixed Income Funds [Member] | Indiana Michigan Power Co [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Fixed Income Funds [Member] | Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,159,100,000			1,226,200,000
Fixed Income Funds [Member] | Indiana Michigan Power Co [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Fixed Income Funds [Member] | Indiana Michigan Power Co [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,159,100,000			1,226,200,000
Fixed Income Funds [Member] | Indiana Michigan Power Co [Member] | Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Mutual Funds Fixed Income [Member] | Other [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0
Mutual Funds Fixed Income [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[18]	118,700,000			123,500,000
Mutual Funds Fixed Income [Member] | Level 1 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		118,700,000			123,500,000
Mutual Funds Fixed Income [Member] | Level 2 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0
Mutual Funds Fixed Income [Member] | Level 3 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0
Mutual Funds Equity [Member] | Other [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[19]	0			0
Mutual Funds Equity [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[19]	56,600,000			54,600,000
Mutual Funds Equity [Member] | Level 1 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[19]	56,600,000			54,600,000
Mutual Funds Equity [Member] | Level 2 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[19]	0			0
Mutual Funds Equity [Member] | Level 3 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[19]	0			0
Cash and Cash Equivalents [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[20]	8,200,000			9,000,000
Cash and Cash Equivalents [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[20]	47,700,000			25,800,000
Cash and Cash Equivalents [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[20]	39,500,000			16,800,000
Cash and Cash Equivalents [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[20]	0			0
Cash and Cash Equivalents [Member] | Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[20]	0			0
Cash and Cash Equivalents [Member] | Indiana Michigan Power Co [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[20]	8,200,000			9,000,000
Cash and Cash Equivalents [Member] | Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[20]	47,700,000			25,800,000
Cash and Cash Equivalents [Member] | Indiana Michigan Power Co [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[20]	39,500,000			16,800,000
Cash and Cash Equivalents [Member] | Indiana Michigan Power Co [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[20]	0			0
Cash and Cash Equivalents [Member] | Indiana Michigan Power Co [Member] | Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[20]	0			0
US Government Agencies Debt Securities [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
US Government Agencies Debt Securities [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		998,900,000			1,025,600,000
US Government Agencies Debt Securities [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
US Government Agencies Debt Securities [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		998,900,000			1,025,600,000
US Government Agencies Debt Securities [Member] | Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
US Government Agencies Debt Securities [Member] | Indiana Michigan Power Co [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
US Government Agencies Debt Securities [Member] | Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		998,900,000			1,025,600,000
US Government Agencies Debt Securities [Member] | Indiana Michigan Power Co [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
US Government Agencies Debt Securities [Member] | Indiana Michigan Power Co [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		998,900,000			1,025,600,000
US Government Agencies Debt Securities [Member] | Indiana Michigan Power Co [Member] | Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Corporate Debt [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Corporate Debt [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		76,400,000			86,300,000
Corporate Debt [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Corporate Debt [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		76,400,000			86,300,000
Corporate Debt [Member] | Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Corporate Debt [Member] | Indiana Michigan Power Co [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Corporate Debt [Member] | Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		76,400,000			86,300,000
Corporate Debt [Member] | Indiana Michigan Power Co [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Corporate Debt [Member] | Indiana Michigan Power Co [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		76,400,000			86,300,000
Corporate Debt [Member] | Indiana Michigan Power Co [Member] | Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
State and Local Jurisdiction [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
State and Local Jurisdiction [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		83,800,000			114,300,000
State and Local Jurisdiction [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
State and Local Jurisdiction [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		83,800,000			114,300,000
State and Local Jurisdiction [Member] | Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
State and Local Jurisdiction [Member] | Indiana Michigan Power Co [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
State and Local Jurisdiction [Member] | Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		83,800,000			114,300,000
State and Local Jurisdiction [Member] | Indiana Michigan Power Co [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
State and Local Jurisdiction [Member] | Indiana Michigan Power Co [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		83,800,000			114,300,000
State and Local Jurisdiction [Member] | Indiana Michigan Power Co [Member] | Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0
Domestic [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[19]	0			0
Domestic [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[19]	2,207,500,000			2,054,700,000
Domestic [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[19]	2,207,500,000			2,054,700,000
Domestic [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[19]	0			0
Domestic [Member] | Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[19]	0			0
Domestic [Member] | Indiana Michigan Power Co [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[19]	0			0
Domestic [Member] | Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[19]	2,207,500,000			2,054,700,000
Domestic [Member] | Indiana Michigan Power Co [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[19]	2,207,500,000			2,054,700,000
Domestic [Member] | Indiana Michigan Power Co [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[19]	0			0
Domestic [Member] | Indiana Michigan Power Co [Member] | Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[19]	$ 0			$ 0
[1]	Included in revenues on the statements of income.
[2]	Represents the change in fair value between the beginning of the reporting period and the settlement of the risk management commodity contract.
[3]	Included in cash flow hedges on the statements of comprehensive income.
[4]	Represents existing assets or liabilities that were previously categorized as Level 2.
[5]	Transfers are recognized based on their value at the beginning of the reporting period that the transfer occurred.
[6]	Relates to the net gains (losses) of those contracts that are not reflected on the statements of income.  These net gains (losses) are recorded as regulatory assets/liabilities or accounts payable.
[7]	Amounts in “Other’’ column primarily represent counterparty netting of risk management and hedging contracts and associated cash collateral under the accounting guidance for “Derivatives and Hedging.’’
[8]	The March 31, 2021 maturity of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 2 matures $(3) million in 2021, $11 million in periods 2022-2024, $17 million in periods 2025-2026 and $10 million in periods 2027-2033; Level 3 matures $23 million in 2021, $32 million in periods 2022-2024, $8 million in periods 2025-2026 and $(21) million in periods 2027-2033.  Risk management commodity contracts are substantially comprised of power contracts.
[9]	The December 31, 2020 maturity of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 2 matures $3 million in periods 2022-2024, $11 million in periods 2025-2026 and $1 million in periods 2027-2033; Level 3 matures $47 million in 2021, $37 million in periods 2022-2024, $14 million in periods 2025-2026 and $(13) million in periods 2027-2033.  Risk management commodity contracts are substantially comprised of power contracts.
[10]	Represents market prices in dollars per MWh.
[11]	The weighted average is the product of the forward market price of the underlying commodity and volume weighted by term.
[12]	Represents market prices in dollars per MMBtu.
[13]	See “Warrants Held in Investee” section of Note 9 for additional information.
[14]	Represents percentage discount applied to the publically available share price.
[15]	Substantially comprised of power contracts for the Registrant Subsidiaries.
[16]	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.
[17]	Primarily represents amounts held for the repayment of debt.
[18]	Primarily short and intermediate maturities which may be sold and do not contain maturity dates.
[19]	Amounts represent publicly traded equity securities and equity-based mutual funds.
[20]	Amounts in “Other’’ column primarily represent accrued interest receivables from financial institutions.  Level 1 amounts primarily represent investments in money market funds.

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Dec. 31, 2020	Mar. 31, 2020	Sep. 30, 2019
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21.00%		21.00%
State Income Tax, net of Federal Benefit	2.30%		2.50%
Tax Reform Excess ADIT Reversal	(9.20%)		(9.40%)
Production and Investment Tax Credits	(5.50%)		(4.30%)
Flow Through	0.30%		0.50%
AFUDC Equity	(0.90%)		(1.40%)
Parent Company Loss Benefit	0.00%		0.00%
Discrete Tax Adjustments	0.50%		0.00%
Other	0.10%		(0.40%)
Effective Income Tax Rate	8.60%		8.50%
Income Taxes (Textuals) [Abstract]
Income Taxes Receivable				$ 95
Tax Cuts and Jobs Act, Change in Tax Rate, Deferred Tax Asset, Income Tax Expense		$ 48
AEP Texas Inc. [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21.00%		21.00%
State Income Tax, net of Federal Benefit	1.40%		1.50%
Tax Reform Excess ADIT Reversal	(7.80%)		(6.20%)
Production and Investment Tax Credits	(0.30%)		(0.40%)
Flow Through	0.30%		0.10%
AFUDC Equity	(1.40%)		(2.60%)
Parent Company Loss Benefit	0.00%		(0.20%)
Discrete Tax Adjustments	0.00%		0.00%
Other	0.10%		0.30%
Effective Income Tax Rate	13.30%		13.50%
AEP Transmission Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21.00%		21.00%
State Income Tax, net of Federal Benefit	2.70%		2.90%
Tax Reform Excess ADIT Reversal	0.30%		0.40%
Production and Investment Tax Credits	0.00%		0.00%
Flow Through	0.20%		0.50%
AFUDC Equity	(1.70%)		(2.60%)
Parent Company Loss Benefit	(1.90%)		(0.90%)
Discrete Tax Adjustments	0.00%		0.00%
Other	0.10%		0.00%
Effective Income Tax Rate	20.70%		21.30%
Appalachian Power Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21.00%		21.00%
State Income Tax, net of Federal Benefit	3.20%		3.00%
Tax Reform Excess ADIT Reversal	(18.00%)		(13.00%)
Production and Investment Tax Credits	0.00%		0.00%
Flow Through	1.60%		1.50%
AFUDC Equity	(1.10%)		(1.00%)
Parent Company Loss Benefit	(2.90%)		(3.30%)
Discrete Tax Adjustments	0.00%		0.00%
Other	0.10%		0.10%
Effective Income Tax Rate	3.90%		8.30%
Indiana Michigan Power Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21.00%		21.00%
State Income Tax, net of Federal Benefit	1.30%		3.20%
Tax Reform Excess ADIT Reversal	(17.90%)		(19.60%)
Production and Investment Tax Credits	(1.70%)		(1.90%)
Flow Through	(1.00%)		0.20%
AFUDC Equity	(0.20%)		(1.10%)
Parent Company Loss Benefit	(2.50%)		(3.90%)
Discrete Tax Adjustments	0.00%		2.70%
Other	0.00%		(0.20%)
Effective Income Tax Rate	(1.00%)		0.40%
Ohio Power Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21.00%		21.00%
State Income Tax, net of Federal Benefit	0.70%		0.70%
Tax Reform Excess ADIT Reversal	(9.70%)		(10.20%)
Production and Investment Tax Credits	0.00%		0.00%
Flow Through	1.10%		1.00%
AFUDC Equity	(1.10%)		(1.00%)
Parent Company Loss Benefit	0.00%		(0.10%)
Discrete Tax Adjustments	(4.00%)		0.00%
Other	0.20%		0.00%
Effective Income Tax Rate	8.20%		11.40%
Public Service Co Of Oklahoma [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21.00%		21.00%
State Income Tax, net of Federal Benefit	4.70%		4.60%
Tax Reform Excess ADIT Reversal	(24.70%)		(23.10%)
Production and Investment Tax Credits	(8.20%)		(1.30%)
Flow Through	0.60%		0.60%
AFUDC Equity	(0.50%)		(0.70%)
Parent Company Loss Benefit	0.00%		(2.20%)
Discrete Tax Adjustments	0.00%		0.00%
Other	(0.90%)		0.10%
Effective Income Tax Rate	(8.00%)		(1.00%)
Southwestern Electric Power Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21.00%		21.00%
State Income Tax, net of Federal Benefit	(0.80%)		2.70%
Tax Reform Excess ADIT Reversal	(5.90%)		(94.70%)
Production and Investment Tax Credits	(5.10%)		(0.50%)
Flow Through	(0.70%)		(1.00%)
AFUDC Equity	(0.40%)		(0.40%)
Parent Company Loss Benefit	0.00%		(2.40%)
Discrete Tax Adjustments	0.00%		0.00%
Other	0.10%		7.20%
Effective Income Tax Rate	8.20%		(68.10%)

Financing Activities (Details)

Financing Activities (Details) - USD ($)		1 Months Ended	3 Months Ended
		Apr. 22, 2021	Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2020
Long-term Debt
Senior Unsecured Notes			$ 25,919,800,000		$ 25,116,100,000
Pollution Control Bonds			1,937,000,000		1,936,700,000
Notes Payable			213,900,000		239,100,000
Securitization Bonds			693,000,000		716,400,000
Spent Nuclear Fuel Obligation	[1]		281,200,000		281,200,000
Junior Subordinated Notes	[2]		1,626,000,000		1,624,100,000
Other Long-term Debt			1,674,100,000		1,158,900,000
Total Long-term Debt Outstanding			32,345,000,000		31,072,500,000
Long-term Debt Due Within One Year			2,130,200,000		2,086,100,000
Long-term Debt			30,214,800,000		28,986,400,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]		1,964,600,000
Repayments of Long-term Debt			650,700,000	$ 300,500,000
Short-term Debt:
Securitized Debt for Receivables	[4]		669,000,000		592,000,000
Commercial Paper			1,874,400,000		1,852,300,000
364-Day Term Loan			500,000,000		0
Notes Payable			5,000,000		35,000,000
Total Short-term Debt			$ 3,048,400,000		$ 2,479,300,000
Securitized Debt for Receivables	[4],[5]		0.20%		0.85%
Comparative Accounts Receivable Information
Effective Interest Rates on Securitization of Accounts Receivable			0.20%	1.75%
Net Uncollectible Accounts Receivable Written Off			$ 9,300,000	$ 4,200,000
Customer Accounts Receivable Managed Portfolio
Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts			871,400,000		$ 958,400,000
Total Principal Outstanding			669,000,000		592,000,000
Delinquent Securitized Accounts Receivable			67,700,000		62,300,000
Bad Debt Reserves Related to Securitization, Sale of Accounts Receivable			47,600,000		60,000,000
Unbilled Receivables Related to Securitization, Sale of Accounts Receivable			211,200,000		296,800,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			4,281,100,000	3,747,500,000
Financing Activities (Textuals)
Maximum Value of Shares to be Issued Under ATM Program			$ 1,000,000,000
Maximum Percentage Paid to Selling Agents			2.00%
Issuance of Common Stock			$ 184,600,000	56,100,000
Trust Fund Assets One Time Fee Obligation for Nuclear Fuel Disposition			$ 326,000,000		$ 324,000,000
Maximum Percentage Debt to Capitalization			67.50%
Total Commitment from Bank Conduits to Finance Receivables			$ 750,000,000
Forward Equity Purchase Contract Included in Current and Noncurrent Liabilities as of March 31,			$ 19,100,000	30,200,000
Equity Distribution Agreement
Financing Activities (Textuals)
Stock Issued During Period, Shares, New Issues			1,917,140
Issuance of Common Stock			$ 158,000,000
2020 Equity Units [Member]
Financing Activities (Textuals)
Equity Units Issued			17,000,000
Per Unit Conversion for Equity Units			$ 50
Net Equity Units Issuance Proceeds			$ 833,000,000
Corporate unit ownership share of an equity unit			5.00%
Principal Amounts of Junior Subordinated Debt			$ 1,000
Forward Equity Purchase Contract Date			2023
Equity Units Annual Distribution Rate			6.125%
Forward Equity Contract Payment Rate			4.825%
Maximum Shares Issued Under Equity Units Conversion			10,205,100
2019 Equity Units [Member]
Financing Activities (Textuals)
Equity Units Issued			16,100,000
Per Unit Conversion for Equity Units			$ 50
Net Equity Units Issuance Proceeds			$ 785,000,000
Corporate unit ownership share of an equity unit			5.00%
Principal Amounts of Junior Subordinated Debt			$ 1,000
Forward Equity Purchase Contract Date			2022
Equity Units Annual Distribution Rate			6.125%
Forward Equity Contract Payment Rate			2.725%
Maximum Shares Issued Under Equity Units Conversion			9,701,860
Subsequent Event [Member] | Equity Distribution Agreement
Financing Activities (Textuals)
Stock Issued During Period, Shares, New Issues		438,165
Issuance of Common Stock		$ 37,000,000
Junior Subordinated Debt [Member] | 2020 Equity Units [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt			$ 850,000,000
Interest Rate (Percentage)			1.30%
Junior Subordinated Debt [Member] | 2019 Equity Units [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt			$ 805,000,000
Interest Rate (Percentage)			3.40%
Commercial Paper [Member]
Short-term Debt:
Weighted Average Interest Rate	[5]		0.27%		0.29%
364 Day Term Loan
Short-term Debt:
Weighted Average Interest Rate	[5]		0.71%		0.00%
Loans Payable [Member]
Short-term Debt:
Weighted Average Interest Rate	[5]		2.75%		2.55%
AEP Texas Inc. [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 4,810,200,000		$ 4,820,400,000
Long-term Debt Due Within One Year			88,900,000		88,700,000
Long-term Debt			4,721,300,000		4,731,700,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 11,200,000	$ 114,300,000
Financing Activities (Textuals)
Maximum Percentage Debt to Capitalization			67.50%
AEP Texas Inc. [Member] | Utility [Member]
Maximum Interest Rate			0.40%	2.24%
Minimum Interest Rate			0.25%	1.76%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool			$ 295,500,000
Maximum Loans to Money Pool			0
Average Borrowings from Money Pool			197,800,000
Average Loans to Money Pool			0
Net Loans (Borrowings) to/from Money Pool			(284,000,000)
Authorized Short Term Borrowing Limit			$ 500,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed			0.31%	2.05%
Average Interest Rate For Funds Loaned			0.00%	1.97%
AEP Texas Inc. [Member] | Nonutility [Member]
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Loans to Money Pool			$ 7,100,000
Average Loans to Money Pool			6,900,000
Net Loans (Borrowings) to/from Money Pool			$ 6,800,000
Maximum and Minimum Interest Rates
Maximum Interest Rate For Funds Loaned			0.40%	2.24%
Minimum Interest Rate for Funds Loaned			0.25%	1.76%
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Loaned			0.30%	1.94%
AEP Texas Inc. [Member] | Securitization Bonds [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 11,200,000
Due Date			2025
Interest Rate (Percentage)			2.06%
AEP Transmission Co [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 3,949,000,000		3,948,500,000
Long-term Debt Due Within One Year			50,000,000		50,000,000
Long-term Debt			3,899,000,000		3,898,500,000
Financing Activities (Textuals)
Sub-Limit of Secured Debt			$ 50,000,000
Maximum Percentage of Consolidated Tangible Net Assets			10.00%
Tangible Capital to Tangible Assets			2.50%
Maximum Percentage Debt to Capitalization			67.50%
AEP Transmission Co [Member] | Utility [Member]
Maximum Interest Rate			0.40%	2.24%
Minimum Interest Rate			0.25%	1.76%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool			$ 330,600,000
Maximum Loans to Money Pool			3,500,000
Average Borrowings from Money Pool			230,100,000
Average Loans to Money Pool			1,600,000
Net Loans (Borrowings) to/from Money Pool			(227,800,000)
Authorized Short Term Borrowing Limit	[6]		$ 820,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed			0.31%	1.95%
Average Interest Rate For Funds Loaned			0.28%	1.91%
AEP Transmission Co [Member] | Direct Borrowing [Member]
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool			$ 1,200,000
Maximum Loans to Money Pool			220,600,000
Average Borrowings from Money Pool			1,200,000
Average Loans to Money Pool			148,700,000
Borrowings from Parent			1,200,000
Loans to Parent			105,800,000
Authorized Short Term Borrowing Limit	[7]		$ 50,000,000
Maximum and Minimum Interest Rates
Maximum Interest Rate for Funds Borrowed			0.86%	2.24%
Minimum Interest Rate For Funds Borrowed			0.25%	1.76%
Maximum Interest Rate For Funds Loaned			0.86%	2.24%
Minimum Interest Rate for Funds Loaned			0.25%	1.76%
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed			0.31%	1.94%
Average Interest Rate For Funds Loaned			0.31%	1.94%
Appalachian Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 4,966,200,000		4,834,100,000
Long-term Debt Due Within One Year			168,500,000		518,300,000
Long-term Debt			4,797,700,000		4,315,800,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			362,500,000	$ 12,200,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues			132,600,000		136,000,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit			$ 362,400,000	352,600,000
Financing Activities (Textuals)
Maximum Percentage Debt to Capitalization			67.50%
Appalachian Power Co [Member] | Servicing Contracts [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			$ 1,200,000	$ 1,700,000
Appalachian Power Co [Member] | Utility [Member]
Maximum Interest Rate			0.40%	2.24%
Minimum Interest Rate			0.25%	1.76%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool			$ 27,800,000
Maximum Loans to Money Pool			616,900,000
Average Borrowings from Money Pool			13,200,000
Average Loans to Money Pool			152,400,000
Net Loans (Borrowings) to/from Money Pool			261,100,000
Authorized Short Term Borrowing Limit			$ 500,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed			0.28%	1.95%
Average Interest Rate For Funds Loaned			0.36%	1.94%
Appalachian Power Co [Member] | Pollution Control Bond [Member] | Subsequent Event [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt		18,000,000
Appalachian Power Co [Member] | Securitization Bonds [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 12,500,000
Due Date			2023
Interest Rate (Percentage)			2.01%
Appalachian Power Co [Member] | Senior Unsecured Notes [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]		$ 500,000,000
Due Date			2031
Interest Rate (Percentage)			2.70%
Appalachian Power Co [Member] | Senior Unsecured Notes Two [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 350,000,000
Due Date			2021
Interest Rate (Percentage)			4.60%
Indiana Michigan Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 3,006,300,000		3,029,900,000
Long-term Debt Due Within One Year			363,100,000		369,600,000
Long-term Debt			2,643,200,000		2,660,300,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			24,100,000	$ 23,700,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues			154,000,000		170,500,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit			478,800,000	471,400,000
Financing Activities (Textuals)
Trust Fund Assets One Time Fee Obligation for Nuclear Fuel Disposition			$ 326,000,000		324,000,000
Maximum Percentage Debt to Capitalization			67.50%
Indiana Michigan Power Co [Member] | Servicing Contracts [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			$ 1,600,000	$ 2,800,000
Indiana Michigan Power Co [Member] | Utility [Member]
Maximum Interest Rate			0.40%	2.24%
Minimum Interest Rate			0.25%	1.76%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool			$ 166,500,000
Maximum Loans to Money Pool			13,300,000
Average Borrowings from Money Pool			118,200,000
Average Loans to Money Pool			13,300,000
Net Loans (Borrowings) to/from Money Pool			(111,300,000)
Authorized Short Term Borrowing Limit			$ 500,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed			0.31%	1.95%
Average Interest Rate For Funds Loaned			0.30%	1.94%
Indiana Michigan Power Co [Member] | Notes Payable, Other Payables [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 1,500,000
Due Date			2021
Interest Rate (Variable)			Variable
Indiana Michigan Power Co [Member] | Notes Payable, Other Payables [Member] | Subsequent Event [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt		$ 6,000,000
Indiana Michigan Power Co [Member] | Notes Payable, Other Payable Two [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 1,500,000
Due Date			2022
Interest Rate (Variable)			Variable
Indiana Michigan Power Co [Member] | Notes Payable, Other Payable Three [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 3,400,000
Due Date			2022
Interest Rate (Variable)			Variable
Indiana Michigan Power Co [Member] | Notes Payable, Other Payable Four [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 4,800,000
Due Date			2023
Interest Rate (Variable)			Variable
Indiana Michigan Power Co [Member] | Notes Payable, Other Payable Five [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 5,900,000
Due Date			2024
Interest Rate (Variable)			Variable
Indiana Michigan Power Co [Member] | Notes Payable, Other Payables Six [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 6,500,000
Due Date			2025
Interest Rate (Variable)			Variable
Indiana Michigan Power Co [Member] | Other Long Term Debt [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 500,000
Due Date			2025
Interest Rate (Percentage)			6.00%
Ohio Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 2,876,300,000		2,430,200,000
Long-term Debt Due Within One Year			500,100,000		500,100,000
Long-term Debt			2,376,200,000		1,930,100,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues			360,200,000		398,800,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit			601,300,000	$ 570,300,000
Ohio Power Co [Member] | Servicing Contracts [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			$ 1,300,000	$ 4,800,000
Ohio Power Co [Member] | Utility [Member]
Maximum Interest Rate			0.40%	2.24%
Minimum Interest Rate			0.25%	1.76%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool			$ 259,200,000
Maximum Loans to Money Pool			222,400,000
Average Borrowings from Money Pool			175,100,000
Average Loans to Money Pool			107,400,000
Net Loans (Borrowings) to/from Money Pool			500,000
Authorized Short Term Borrowing Limit			$ 500,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed			0.29%	1.90%
Average Interest Rate For Funds Loaned			0.29%	2.06%
Ohio Power Co [Member] | Senior Unsecured Notes [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]		$ 450,000,000
Due Date			2031
Interest Rate (Percentage)			1.63%
Public Service Co Of Oklahoma [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 1,623,800,000		1,373,800,000
Long-term Debt Due Within One Year			500,000		500,000
Long-term Debt			1,623,300,000		1,373,300,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			250,100,000	$ 100,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues			76,200,000		85,000,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit			$ 284,900,000	294,900,000
Financing Activities (Textuals)
Maximum Percentage Debt to Capitalization			67.50%
Public Service Co Of Oklahoma [Member] | Servicing Contracts [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			$ 700,000	$ 1,300,000
Public Service Co Of Oklahoma [Member] | Utility [Member]
Maximum Interest Rate			0.40%	2.24%
Minimum Interest Rate			0.25%	1.76%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool			$ 262,000,000
Maximum Loans to Money Pool			210,100,000
Average Borrowings from Money Pool			130,300,000
Average Loans to Money Pool			122,000,000
Net Loans (Borrowings) to/from Money Pool			(245,700,000)
Authorized Short Term Borrowing Limit			$ 300,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed			0.33%	2.00%
Average Interest Rate For Funds Loaned			0.28%	1.95%
Public Service Co Of Oklahoma [Member] | Other Long Term Debt [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]		$ 500,000,000
Due Date			2022
Interest Rate (Variable)			Variable
Public Service Co Of Oklahoma [Member] | Other Long Term Debt Two [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 100,000
Due Date			2027
Interest Rate (Percentage)			3.00%
Public Service Co Of Oklahoma [Member] | Senior Unsecured Notes [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 250,000,000
Due Date			2021
Interest Rate (Percentage)			4.40%
Southwestern Electric Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 3,131,400,000		2,636,400,000
Long-term Debt Due Within One Year			381,200,000		106,200,000
Long-term Debt			2,750,200,000		2,530,200,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			1,600,000	$ 1,600,000
Short-term Debt:
Notes Payable			5,000,000		35,000,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues			132,900,000		$ 158,600,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit			$ 384,400,000	365,600,000
Financing Activities (Textuals)
Maximum Percentage Debt to Capitalization			67.50%
Southwestern Electric Power Co [Member] | Servicing Contracts [Member]
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			$ 1,500,000	$ 2,100,000
Southwestern Electric Power Co [Member] | Utility [Member]
Maximum Interest Rate			0.40%	2.24%
Minimum Interest Rate			0.25%	1.76%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool			$ 280,300,000
Maximum Loans to Money Pool			156,400,000
Average Borrowings from Money Pool			169,300,000
Average Loans to Money Pool			142,000,000
Net Loans (Borrowings) to/from Money Pool			(86,900,000)
Authorized Short Term Borrowing Limit			$ 350,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed			0.28%	1.95%
Average Interest Rate For Funds Loaned			0.38%	0.00%
Southwestern Electric Power Co [Member] | Nonutility [Member]
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Loans to Money Pool			$ 2,100,000
Average Loans to Money Pool			2,100,000
Net Loans (Borrowings) to/from Money Pool			$ 2,100,000
Maximum and Minimum Interest Rates
Maximum Interest Rate For Funds Loaned			0.40%	2.24%
Minimum Interest Rate for Funds Loaned			0.25%	1.76%
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Loaned			0.30%	1.94%
Southwestern Electric Power Co [Member] | Notes Payable, Other Payables [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 1,600,000
Due Date			2032
Interest Rate (Percentage)			4.58%
Southwestern Electric Power Co [Member] | Senior Unsecured Notes [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]		$ 500,000,000
Due Date			2026
Interest Rate (Percentage)			1.65%
Southwestern Electric Power Co [Member] | Loans Payable [Member]
Short-term Debt:
Weighted Average Interest Rate	[5]		2.75%		2.55%
Transource Energy [Member] | Other Long Term Debt [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]		$ 14,600,000
Due Date			2023
Interest Rate (Variable)			Variable
Transource Energy [Member] | Senior Unsecured Notes [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt			$ 1,200,000
Due Date			2050
Interest Rate (Percentage)			2.75%
Maximum [Member] | 2020 Equity Units [Member]
Financing Activities (Textuals)
AEP Share Price for Equity Unit Conversion			$ 99.95
Shares Per Equity Unit			0.6003
Maximum [Member] | 2019 Equity Units [Member]
Financing Activities (Textuals)
AEP Share Price for Equity Unit Conversion			$ 99.58
Shares Per Equity Unit			0.6026
Minimum [Member] | 2020 Equity Units [Member]
Financing Activities (Textuals)
AEP Share Price for Equity Unit Conversion			$ 83.29
Shares Per Equity Unit			0.5003
Minimum [Member] | 2019 Equity Units [Member]
Financing Activities (Textuals)
AEP Share Price for Equity Unit Conversion			$ 82.98
Shares Per Equity Unit			0.5021
Retained Earnings [Member]
Financing Activities (Textuals)
Forward Equity Purchase Contract Included in Current and Noncurrent Liabilities as of March 31,			$ 600,000
Additional Paid-in Capital [Member]
Financing Activities (Textuals)
Forward Equity Purchase Contract Included in Current and Noncurrent Liabilities as of March 31,			21,900,000	$ 29,000,000
Additional Paid-in Capital [Member] | 2020 Equity Units [Member]
Financing Activities (Textuals)
Forward Equity Purchase Contract Included in Current and Noncurrent Liabilities as of March 31,			121,000,000
Additional Paid-in Capital [Member] | 2019 Equity Units [Member]
Financing Activities (Textuals)
Forward Equity Purchase Contract Included in Current and Noncurrent Liabilities as of March 31,			$ 62,000,000
[1]	Pursuant to the Nuclear Waste Policy Act of 1982, I&M, a nuclear licensee, has an obligation to the United States Department of Energy for SNF disposal. The obligation includes a one-time fee for nuclear fuel consumed prior to April 7, 1983. Trust fund assets related to this obligation were $326 million and $324 million as of March 31, 2021 and December 31, 2020, respectively, and are included in Spent Nuclear Fuel and Decommissioning Trusts on the balance sheets.
[2]	See “Equity Units” section below for additional information.
[3]	Amounts indicated on the statements of cash flows are net of issuance costs and premium or discount and will not tie to the issuance amounts.
[4]	Amount of securitized debt for receivables as accounted for under the “Transfers and Servicing” accounting guidance.
[5]	Weighted-average rate.
[6]	Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions.
[7]	Amount represents the combined authorized short-term borrowing limit the State Transcos have from FERC or state regulatory commissions.

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2021		Mar. 31, 2020		Dec. 31, 2020
Disaggregation of Revenue
Revenue from Contracts with Customers		$ 4,281.1		$ 3,747.5
Revenue, Performance Obligation
Fixed Performance Obligations		1,366.6
Revenues		4,281.1		3,747.5
Revenue Textuals
Revenue from Related Parties		0		0
Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,936.9		2,870.2
Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,594.2		1,436.4
Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		725.4		766.3
Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		569.5		615.8
Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		47.8		51.7
Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,234.6		765.2
Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		393.1		184.5
Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		280.6	[1]	240.8	[2]
Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		21.7	[3]	16.6	[4]
Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		539.2	[5]	323.3	[6]
Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		87.9	[3]	71.5	[4]
Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		4,259.4		3,706.9
Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		21.7		40.6
Alternative [Member]
Revenue, Performance Obligation
Revenues		16.9	[3]	20.7	[4]
Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		92.6		70.9
Revenue, Performance Obligation
Revenues		4.8	[3]	19.9	[4]
2021 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		873.4
2022-2023 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		171.3
2024-2025 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		160.4
2025 and Forward [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		161.5
AEP Texas Inc. [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		349
Revenues		364.2		423.6
Affiliated Companies - Contracts with Customers		7.2				$ 5.1
Revenue Textuals
Revenue from Related Parties		1		31.1
AEP Texas Inc. [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		236.7		289.3
AEP Texas Inc. [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		122.7		132.9
AEP Texas Inc. [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		80.7		112.8
AEP Texas Inc. [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		26.5		35.2
AEP Texas Inc. [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		6.8		8.4
AEP Texas Inc. [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		112		96.9
AEP Texas Inc. [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[7]	0	[8]
AEP Texas Inc. [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		112	[9]	96.9	[10]
AEP Texas Inc. [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		16.2	[11]	7.9	[12]
AEP Texas Inc. [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		364.9		394.1
AEP Texas Inc. [Member] | Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		(0.7)		29.5
AEP Texas Inc. [Member] | Alternative [Member]
Revenue, Performance Obligation
Revenues		(0.7)	[13]	(0.7)	[14]
AEP Texas Inc. [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1.5		0.9
Revenue, Performance Obligation
Revenues		0	[13]	30.2	[14]
AEP Texas Inc. [Member] | 2021 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		349
AEP Texas Inc. [Member] | 2022-2023 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
AEP Texas Inc. [Member] | 2024-2025 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
AEP Texas Inc. [Member] | 2025 and Forward [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
AEP Transmission Co [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		1,001.3
Revenues		361.7		295.6
Affiliated Companies - Contracts with Customers		95				81.2
Revenue Textuals
Revenue from Related Parties		285.6		233.7
AEP Transmission Co [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
AEP Transmission Co [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
AEP Transmission Co [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
AEP Transmission Co [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
AEP Transmission Co [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
AEP Transmission Co [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		345.2		298.2
AEP Transmission Co [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[7]	0	[8]
AEP Transmission Co [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		345.2	[9]	298.2	[10]
Revenue Textuals
Revenue from Related Parties		270		235
AEP Transmission Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		4.6	[11]	3.4	[12]
AEP Transmission Co [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		349.8		301.6
AEP Transmission Co [Member] | Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		11.9		(6)
AEP Transmission Co [Member] | Alternative [Member]
Revenue, Performance Obligation
Revenues		11.9	[13]	(6)	[14]
AEP Transmission Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0.1		0.6
Revenue, Performance Obligation
Revenues		0	[13]	0	[14]
AEP Transmission Co [Member] | Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		92.3				81
AEP Transmission Co [Member] | 2021 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		1,001.3
AEP Transmission Co [Member] | 2022-2023 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
AEP Transmission Co [Member] | 2024-2025 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
AEP Transmission Co [Member] | 2025 and Forward [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
Appalachian Power Co [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		198.7
Revenues		817		749.4
Affiliated Companies - Contracts with Customers		64.9				64.3
Revenue Textuals
Revenue from Related Parties		50.1		49.7
Appalachian Power Co [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		694.9		648.8
Appalachian Power Co [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		416.9		357.5
Appalachian Power Co [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		130.2		132.3
Appalachian Power Co [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		130.9		141.1
Appalachian Power Co [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		16.9		17.9
Appalachian Power Co [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		106.6		84.5
Appalachian Power Co [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		72.4	[7]	54.1	[8]
Revenue Textuals
Revenue from Related Parties		32		33
Appalachian Power Co [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		34.2	[9]	30.4	[10]
Appalachian Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		13.1	[11]	17.2	[12]
Appalachian Power Co [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		814.6		750.5
Appalachian Power Co [Member] | Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		2.4		(1.1)
Appalachian Power Co [Member] | Alternative [Member]
Revenue, Performance Obligation
Revenues		2.2	[13]	(1.1)	[14]
Appalachian Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2.7		2.7
Revenue, Performance Obligation
Revenues		0.2	[13]	0	[14]
Appalachian Power Co [Member] | Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		52.6				52.7
Appalachian Power Co [Member] | 2021 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		130.4
Appalachian Power Co [Member] | 2022-2023 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		32.3
Appalachian Power Co [Member] | 2024-2025 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		24.3
Appalachian Power Co [Member] | 2025 and Forward [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		11.7
Indiana Michigan Power Co [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		47.8
Revenues		564.5		570.3
Affiliated Companies - Contracts with Customers		48.8				51.3
Revenue Textuals
Revenue from Related Parties		0.8		2.9
Indiana Michigan Power Co [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		457		463.1
Indiana Michigan Power Co [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		213.6		201.3
Indiana Michigan Power Co [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		113.6		122.2
Indiana Michigan Power Co [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		128.4		137.8
Indiana Michigan Power Co [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1.4		1.8
Indiana Michigan Power Co [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		87.9		85.8
Indiana Michigan Power Co [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		79.6	[7]	78.4	[8]
Indiana Michigan Power Co [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		8.3	[9]	7.4	[10]
Indiana Michigan Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		20.7	[11]	21	[12]
Indiana Michigan Power Co [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		565.6		569.9
Indiana Michigan Power Co [Member] | Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		(1.1)		0.4
Indiana Michigan Power Co [Member] | Alternative [Member]
Revenue, Performance Obligation
Revenues		(1.1)	[13]	0.4	[14]
Indiana Michigan Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1.7		1.5
Revenue, Performance Obligation
Revenues		0	[13]	0	[14]
Revenue Textuals
Revenue from Related Parties		16		16
Indiana Michigan Power Co [Member] | Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		31.4				34.8
Indiana Michigan Power Co [Member] | 2021 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		25.8
Indiana Michigan Power Co [Member] | 2022-2023 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		8.8
Indiana Michigan Power Co [Member] | 2024-2025 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		8.8
Indiana Michigan Power Co [Member] | 2025 and Forward [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		4.4
Ohio Power Co [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		49.8
Revenues		723.9		690.3
Affiliated Companies - Contracts with Customers		78.3				65.1
Revenue Textuals
Revenue from Related Parties		4.8		8.4
Ohio Power Co [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		646.2		618.5
Ohio Power Co [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		425.3		388.4
Ohio Power Co [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		158.5		164
Ohio Power Co [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		59.2		62.7
Ohio Power Co [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		3.2		3.4
Ohio Power Co [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		18.5		17.1
Ohio Power Co [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[7]	0	[8]
Ohio Power Co [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		18.5	[9]	17.1	[10]
Ohio Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		36	[11]	28.6	[12]
Ohio Power Co [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		700.7		664.2
Ohio Power Co [Member] | Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		23.2		26.1
Ohio Power Co [Member] | Alternative [Member]
Revenue, Performance Obligation
Revenues		17.9	[13]	20	[14]
Ohio Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2.4		2.7
Revenue, Performance Obligation
Revenues		5.3	[13]	6.1	[14]
Ohio Power Co [Member] | Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		47.8				45.9
Ohio Power Co [Member] | 2021 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		49.7
Ohio Power Co [Member] | 2022-2023 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
Ohio Power Co [Member] | 2024-2025 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
Ohio Power Co [Member] | 2025 and Forward [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0.1
Public Service Co Of Oklahoma [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		14.8
Revenues		296.1		297.3
Affiliated Companies - Contracts with Customers		21.8				15.6
Revenue Textuals
Revenue from Related Parties		1		1.1
Public Service Co Of Oklahoma [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		281.6		282.5
Public Service Co Of Oklahoma [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		136.8		128.5
Public Service Co Of Oklahoma [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		72.7		76.1
Public Service Co Of Oklahoma [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		56.4		61.3
Public Service Co Of Oklahoma [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		15.7		16.6
Public Service Co Of Oklahoma [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2.3		9.7
Public Service Co Of Oklahoma [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(7.1)	[7]	1.9	[8]
Public Service Co Of Oklahoma [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		9.4	[9]	7.8	[10]
Public Service Co Of Oklahoma [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		12.6	[11]	4.7	[12]
Public Service Co Of Oklahoma [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		296.5		296.9
Public Service Co Of Oklahoma [Member] | Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		(0.4)		0.4
Public Service Co Of Oklahoma [Member] | Alternative [Member]
Revenue, Performance Obligation
Revenues		(0.4)	[13]	0.4	[14]
Public Service Co Of Oklahoma [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1.5		0.8
Revenue, Performance Obligation
Revenues		0	[13]	0	[14]
Public Service Co Of Oklahoma [Member] | Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		14.9				7.8
Public Service Co Of Oklahoma [Member] | 2021 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		14.8
Public Service Co Of Oklahoma [Member] | 2022-2023 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
Public Service Co Of Oklahoma [Member] | 2024-2025 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
Public Service Co Of Oklahoma [Member] | 2025 and Forward [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
Southwestern Electric Power Co [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		41.6
Revenues		616.1		385.9
Affiliated Companies - Contracts with Customers		34.6				25.1
Revenue Textuals
Revenue from Related Parties		7.8		7.5
Southwestern Electric Power Co [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		352.1		319
Southwestern Electric Power Co [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		166.3		131.6
Southwestern Electric Power Co [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		112.9		105.6
Southwestern Electric Power Co [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		70.6		79.8
Southwestern Electric Power Co [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2.3		2
Southwestern Electric Power Co [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		257.5		59.5
Southwestern Electric Power Co [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		228.6	[7]	34.1	[8]
Southwestern Electric Power Co [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		28.9	[9]	25.4	[10]
Southwestern Electric Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		6.4	[11]	5.8	[12]
Southwestern Electric Power Co [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		616		384.3
Southwestern Electric Power Co [Member] | Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		0.1		1.6
Southwestern Electric Power Co [Member] | Alternative [Member]
Revenue, Performance Obligation
Revenues		0.1	[13]	1.6	[14]
Southwestern Electric Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0.6		0.8
Revenue, Performance Obligation
Revenues		0	[13]	0	[14]
Southwestern Electric Power Co [Member] | Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		22.8				$ 11.2
Southwestern Electric Power Co [Member] | 2021 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		41.6
Southwestern Electric Power Co [Member] | 2022-2023 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
Southwestern Electric Power Co [Member] | 2024-2025 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
Southwestern Electric Power Co [Member] | 2025 and Forward [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0
Consolidation Eliminations [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Revenue, Performance Obligation
Revenues		(368.4)		(354.8)
Revenue Textuals
Revenue from Related Parties		(368.4)		(354.8)
Consolidation Eliminations [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(0.2)		(0.2)
Consolidation Eliminations [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Consolidation Eliminations [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Consolidation Eliminations [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(0.2)		(0.2)
Consolidation Eliminations [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Consolidation Eliminations [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(331.8)		(293)
Consolidation Eliminations [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Consolidation Eliminations [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(299.3)	[1]	(263)	[2]
Consolidation Eliminations [Member] | Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(0.7)	[3]	(0.6)	[4]
Consolidation Eliminations [Member] | Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(31.8)	[5]	(29.4)	[6]
Consolidation Eliminations [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(21.2)	[3]	(40.6)	[4]
Consolidation Eliminations [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(353.2)		(333.8)
Consolidation Eliminations [Member] | Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		(15.2)		(21)
Consolidation Eliminations [Member] | Alternative [Member]
Revenue, Performance Obligation
Revenues		(11.6)	[3]	4.5	[4]
Consolidation Eliminations [Member] | Other Revenues [Member]
Revenue, Performance Obligation
Revenues		(3.6)	[3]	(25.5)	[4]
Consolidation Eliminations [Member] | AEP Transmission Co [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Revenue, Performance Obligation
Revenues		0		0
Revenue Textuals
Revenue from Related Parties		0		0
Consolidation Eliminations [Member] | AEP Transmission Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Vertically Integrated Utilities [Member]
Revenue, Performance Obligation
Revenues		2,537.3		2,226.7
Revenue Textuals
Revenue from Related Parties		32.8		33.7
Vertically Integrated Utilities [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,054.1		1,962.6
Vertically Integrated Utilities [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,046.1		915.1
Vertically Integrated Utilities [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		486.2		489.4
Vertically Integrated Utilities [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		484		518.2
Vertically Integrated Utilities [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		37.8		39.9
Vertically Integrated Utilities [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		441.6		220.3
Vertically Integrated Utilities [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		352.6		140.4
Vertically Integrated Utilities [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		89	[1]	79.9	[2]
Vertically Integrated Utilities [Member] | Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[3]	0	[4]
Vertically Integrated Utilities [Member] | Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[5]	0	[6]
Vertically Integrated Utilities [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		42.3	[3]	43.6	[4]
Vertically Integrated Utilities [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,538		2,226.5
Vertically Integrated Utilities [Member] | Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		(0.7)		0.2
Vertically Integrated Utilities [Member] | Alternative [Member]
Revenue, Performance Obligation
Revenues		(0.7)	[3]	0.2	[4]
Vertically Integrated Utilities [Member] | Other Revenues [Member]
Revenue, Performance Obligation
Revenues		0	[3]	0	[4]
Transmission And Distribution Utilities [Member]
Revenue, Performance Obligation
Revenues		1,088.1		1,106.9
Revenue Textuals
Revenue from Related Parties		5.8		31.7
Transmission And Distribution Utilities [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		883		907.8
Transmission And Distribution Utilities [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		548.1		521.3
Transmission And Distribution Utilities [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		239.2		276.9
Transmission And Distribution Utilities [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		85.7		97.8
Transmission And Distribution Utilities [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		10		11.8
Transmission And Distribution Utilities [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		130.5		114.1
Transmission And Distribution Utilities [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Transmission And Distribution Utilities [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		130.5	[1]	114.1	[2]
Transmission And Distribution Utilities [Member] | Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[3]	0	[4]
Transmission And Distribution Utilities [Member] | Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[5]	0	[6]
Transmission And Distribution Utilities [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		52.1	[3]	36.4	[4]
Transmission And Distribution Utilities [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,065.6		1,058.3
Transmission And Distribution Utilities [Member] | Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		22.5		48.6
Transmission And Distribution Utilities [Member] | Alternative [Member]
Revenue, Performance Obligation
Revenues		17.2	[3]	19.3	[4]
Transmission And Distribution Utilities [Member] | Other Revenues [Member]
Revenue, Performance Obligation
Revenues		5.3	[3]	29.3	[4]
AEP Transmission Holdco [Member]
Revenue, Performance Obligation
Revenues		377		310.2
AEP Transmission Holdco [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
AEP Transmission Holdco [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
AEP Transmission Holdco [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
AEP Transmission Holdco [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
AEP Transmission Holdco [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
AEP Transmission Holdco [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		360.4		309.8
AEP Transmission Holdco [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
AEP Transmission Holdco [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		360.4	[1]	309.8	[2]
Revenue Textuals
Revenue from Related Parties		273		239
AEP Transmission Holdco [Member] | Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[3]	0	[4]
AEP Transmission Holdco [Member] | Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[5]	0	[6]
AEP Transmission Holdco [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		4.6	[3]	3.7	[4]
AEP Transmission Holdco [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		365		313.5
AEP Transmission Holdco [Member] | Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		12		(3.3)
AEP Transmission Holdco [Member] | Alternative [Member]
Revenue, Performance Obligation
Revenues		12	[3]	(3.3)	[4]
AEP Transmission Holdco [Member] | Other Revenues [Member]
Revenue, Performance Obligation
Revenues		0	[3]	0	[4]
Generation And Marketing [Member]
Revenue, Performance Obligation
Revenues		634.2		438.6
Revenue Textuals
Revenue from Related Parties		32.5		30.2
Generation And Marketing [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Generation And Marketing [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Generation And Marketing [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Generation And Marketing [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Generation And Marketing [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Generation And Marketing [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		632.7		420
Generation And Marketing [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		40.5		44.1
Revenue Textuals
Revenue from Related Parties		32		35
Generation And Marketing [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[1]	0	[2]
Generation And Marketing [Member] | Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		22.4	[3]	17.2	[4]
Generation And Marketing [Member] | Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		569.8	[5]	358.7	[6]
Generation And Marketing [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1.5	[3]	0.3	[4]
Generation And Marketing [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		634.2		420.3
Generation And Marketing [Member] | Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		0		18.3
Generation And Marketing [Member] | Alternative [Member]
Revenue, Performance Obligation
Revenues		0	[3]	0	[4]
Generation And Marketing [Member] | Other Revenues [Member]
Revenue, Performance Obligation
Revenues		0	[3]	18.3	[4]
Other Segments [Member]
Revenue, Performance Obligation
Revenues	[15]	12.9		19.9
Revenue Textuals
Revenue from Related Parties	[15]	8.2		22.1
Other Segments [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Other Segments [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Other Segments [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Other Segments [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Other Segments [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Other Segments [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1.2		(6)
Other Segments [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0
Other Segments [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[1]	0	[2]
Other Segments [Member] | Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[3]	0	[4]
Other Segments [Member] | Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1.2	[5]	(6)	[6]
Other Segments [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		8.6	[3]	28.1	[4]
Other Segments [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		9.8		22.1
Other Segments [Member] | Alternative and Other [Member]
Revenue, Performance Obligation
Revenues		3.1		(2.2)
Other Segments [Member] | Alternative [Member]
Revenue, Performance Obligation
Revenues		0	[3]	0	[4]
Other Segments [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers	[15]	4.7		(2.2)
Revenue, Performance Obligation
Revenues		$ 3.1	[3]	$ (2.2)	[4]
[1]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $273 million. The remaining affiliated amounts were immaterial.
[2]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $239 million. The remaining affiliated amounts were immaterial
[3]	Amounts include affiliated and nonaffiliated revenues.
[4]	Amounts include affiliated and nonaffiliated revenues
[5]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $32 million. The remaining affiliated amounts were immaterial.
[6]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $35 million. The remaining affiliated amounts were immaterial.
[7]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $32 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial
[8]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $33 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial.
[9]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $270 million. The remaining affiliated amounts were immaterial.
[10]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $235 million. The remaining affiliated amounts were immaterial.
[11]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $16 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial.
[12]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $16 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial.
[13]	Amounts include affiliated and nonaffiliated revenues.
[14]	Amounts include affiliated and nonaffiliated revenues.
[15]	Corporate and Other primarily includes the purchasing of receivables from certain AEP utility subsidiaries. This segment also includes Parent’s guarantee revenue received from affiliates, investment income, interest income, interest expense and other nonallocated costs.