American Electric Power (AEP) 10-Q 28 Oct 21 2021 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2021	Oct. 28, 2021
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 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		503,651,677
Entity Central Index Key	0000004904
Amendment Flag	false
Document Fiscal Year Focus	2021
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				9 Months Ended
	Sep. 30, 2021		Sep. 30, 2020		Sep. 30, 2021		Sep. 30, 2020
Revenues
Revenue from Contracts with Customers	$ 4,623		$ 4,066.4		$ 12,730.6		$ 11,307.9
Sales to AEP Affiliates	0		0		0		0
TOTAL REVENUES	4,623		4,066.4		12,730.6		11,307.9
Expenses
Other Operation	735.3		702.9		1,894.6		1,871
Maintenance	277.8		237.6		817		730.5
Depreciation and Amortization	700.3		644.6		2,103.9		1,996.3
Taxes Other Than Income Taxes	360.8		337.7		1,061.4		976.3
TOTAL EXPENSES	3,515.6		3,123.2		10,003		8,890.4
OPERATING INCOME (LOSS)	1,107.4		943.2		2,727.6		2,417.5
Other Income (Expense):
Other Income	(20.6)		5.5		34.2		15.4
Allowance for Equity Funds Used During Construction	37		45.2		103.9		111.7
Non-Service Cost Components of Net Periodic Benefit Cost	29.6		29.7		88.9		89.2
Interest Expense	(303.7)		(291.3)		(895.5)		(877.4)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS	849.7		732.3		2,059.1		1,756.4
Income Tax Expense (Benefit)	69.8		(1.2)		185.5		57.9
Equity Earnings (Loss) of Unconsolidated Subsidiaries	17		14.7		75.9		63.5
Net Income (Loss)	796.9		748.2		1,949.5		1,762
Net Income (Loss) Attributable to Noncontrolling Interests	0.9		(0.4)		0.3		(2.6)
Earnings Attributable to Common Shareholders	$ 796		$ 748.6		$ 1,949.2		$ 1,764.6
Earnings Per Share
Weighted Average Number of Basic AEP Common Shares Outstanding	501,233,680		496,177,968		499,418,278		495,479,190
Total Basic Earnings Per Share Attributable to AEP Common Shareholders	$ 1.59		$ 1.51		$ 3.90		$ 3.56
Weighted Average Number of Diluted AEP Common Shares Outstanding	502,606,836		497,458,523		500,600,237		496,916,187
Total Diluted Earnings Per Share Attributable to AEP Common Shareholders	$ 1.58		$ 1.50		$ 3.89		$ 3.55
Common Stock, Dividends Per Share, Declared	$ 0.74		$ 0.70
Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers	$ 2,716.8		$ 2,400.1		$ 7,445.9		$ 6,655.4
Transmission and Distribution Utilities [Member]
Revenues
Revenue from Contracts with Customers	1,195		1,124.1		3,366.9		3,208.7
Generation and Marketing [Member]
Revenues
Revenue from Contracts with Customers	617.4		464.8		1,641.6		1,223.4
Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	93.8		77.4		276.2		220.4
TOTAL REVENUES	154.8	[1]	(5.5)	[2]	188.7	[3]	13.3	[4]
Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold	1,441.4		1,200.4		4,126.1		3,316.3
AEP Texas Inc. [Member]
Revenues
Sales to AEP Affiliates	0.9		41.4		2.9		89.4
TOTAL REVENUES	432.6		432		1,195.3		1,257.1
Expenses
Other Operation	135.3		134.3		367.1		344.7
Maintenance	22		20.4		59.8		64.1
Depreciation and Amortization	87.6		107.7		287.1		435.8
Taxes Other Than Income Taxes	41.6		38.7		117.4		106.7
TOTAL EXPENSES	286.5		311.5		831.4		964.9
OPERATING INCOME (LOSS)	146.1		120.5		363.9		292.2
Other Income (Expense):
Interest Income	0.2		0.5		0.6		1.2
Allowance for Equity Funds Used During Construction	9.2		4.4		16.7		14.4
Non-Service Cost Components of Net Periodic Benefit Cost	2.8		2.8		8.3		8.4
Interest Expense	(44.2)		(44.5)		(132.5)		(129.2)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS	114.1		83.7		257		187
Income Tax Expense (Benefit)	14.6		1.1		31.6		(10.1)
Net Income (Loss)	99.5		82.6		225.4		197.1
AEP Texas Inc. [Member] | Transmission and Distribution Utilities [Member]
Revenues
Revenue from Contracts with Customers	430.8		390.1		1,189.1		1,165.2
AEP Texas Inc. [Member] | Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	0.9		0.5		3.3		2.5
TOTAL REVENUES	0	[5]	40.6	[6]	0	[7]	86.9	[8]
AEP Texas Inc. [Member] | Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold	0		10.4		0		13.6
AEP Transmission Co [Member]
Revenues
Sales to AEP Affiliates	297.6		241.2		864.6		652.6
TOTAL REVENUES	377		304.1		1,104.2		837.8
Expenses
Other Operation	32.6		25.3		78.1		72
Maintenance	5.4		3.5		12.3		6.8
Depreciation and Amortization	76		61.5		219		176.4
Taxes Other Than Income Taxes	61		52.2		178.9		152.8
TOTAL EXPENSES	175		142.5		488.3		408
OPERATING INCOME (LOSS)	202		161.6		615.9		429.8
Other Income (Expense):
Interest Income	0.2		0.2		0.4		2.3
Allowance for Equity Funds Used During Construction	16		20.2		49.3		54.9
Interest Expense	(36.1)		(32.7)		(104.5)		(95.1)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS	182.1		149.3		561.1		391.9
Income Tax Expense (Benefit)	36.7		31.7		115.4		82.8
Net Income (Loss)	145.4		117.6		445.7		309.1
AEP Transmission Co [Member] | Transmission [Member]
Revenues
Revenue from Contracts with Customers	79.2		62.9		239.3		184.6
AEP Transmission Co [Member] | Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	0.2		0		0.3		0.6
TOTAL REVENUES	0	[5]	0	[6]	0	[7]	0	[8]
Appalachian Power Co [Member]
Revenues
Sales to AEP Affiliates	52.4		44.4		140.6		124.9
TOTAL REVENUES	804		735.7		2,298		2,122.6
Expenses
Other Operation	173		136.3		442.1		379.1
Maintenance	69.1		52		184.4		148.7
Depreciation and Amortization	135.4		123.2		406.6		366
Taxes Other Than Income Taxes	39.8		38.8		116.7		114.2
TOTAL EXPENSES	670.5		583.8		1,870.1		1,679.4
OPERATING INCOME (LOSS)	133.5		151.9		427.9		443.2
Other Income (Expense):
Interest Income	0.2		0.6		0.8		1.4
Allowance for Equity Funds Used During Construction	4.3		6.7		12.1		11.5
Non-Service Cost Components of Net Periodic Benefit Cost	4.7		4.7		14.2		14.1
Interest Expense	(52.8)		(55)		(160.6)		(162.2)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS	89.9		108.9		294.4		308
Income Tax Expense (Benefit)	3.6		(7.7)		19.3		(5.2)
Net Income (Loss)	86.3		116.6		275.1		313.2
Appalachian Power Co [Member] | Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers	748.5		688.9		2,149.2		1,989.9
Appalachian Power Co [Member] | Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	3.1		2.4		8.2		7.8
TOTAL REVENUES	0	[5]	0	[6]	0	[7]	0	[8]
Appalachian Power Co [Member] | Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold	170.8		166		471.9		430.9
Appalachian Power Co [Member] | Purchased Electricity for Resale [Member]
Expenses
Cost of Goods and Services Sold	82.4		67.5		248.4		240.5
Indiana Michigan Power Co [Member]
Revenues
Sales to AEP Affiliates	1.1		1.3		2.6		9.1
Other Revenues - Affiliated	14.7		14.1		41.2		42.4
TOTAL REVENUES	635.7		586.7		1,784		1,703.6
Expenses
Purchased Electricity from AEP Affiliates	63.3		55.9		172.7		135.8
Other Operation	167.5		165.5		482.4		459.7
Maintenance	52		51		165.4		144.4
Depreciation and Amortization	110.6		104.5		328.7		303.6
Taxes Other Than Income Taxes	27.8		27.4		83.8		79.5
TOTAL EXPENSES	509.8		486.2		1,494.8		1,397.1
OPERATING INCOME (LOSS)	125.9		100.5		289.2		306.5
Other Income (Expense):
Other Income	2.5		2.2		8.9		7.8
Allowance for Equity Funds Used During Construction					9.7		8.8
Non-Service Cost Components of Net Periodic Benefit Cost	4.1		4.1		12.3		12.5
Interest Expense	(30.2)		(26.9)		(86.6)		(85.7)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS	102.3		79.9		223.8		241.1
Income Tax Expense (Benefit)	(1.8)		3.2		(8.3)		8.3
Net Income (Loss)	104.1		76.7		232.1		232.8
Indiana Michigan Power Co [Member] | Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers	618.2		570.1		1,735.1		1,648.4
Indiana Michigan Power Co [Member] | Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	1.7		1.2		5.1		3.7
Sales to AEP Affiliates	17		15		46		49
TOTAL REVENUES	0	[5]	0	[6]	0	[7]	0	[8]
Indiana Michigan Power Co [Member] | Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold	43.7		44.4		129.9		146
Indiana Michigan Power Co [Member] | Purchased Electricity for Resale [Member]
Expenses
Cost of Goods and Services Sold	44.9		37.5		131.9		128.1
Ohio Power Co [Member]
Revenues
Sales to AEP Affiliates	4.3		8.3		21.9		33
TOTAL REVENUES	767.7		741		2,196.5		2,071.7
Expenses
Purchased Electricity from AEP Affiliates	3.5		24.1		48		96.8
Other Operation	245.1		244.6		622.9		608.5
Maintenance	39.3		33.7		116.4		92.2
Depreciation and Amortization	76.9		74.1		228.6		204.4
Taxes Other Than Income Taxes	126		117.8		366.2		337.8
TOTAL EXPENSES	675.5		643.6		1,895.7		1,752
OPERATING INCOME (LOSS)	92.2		97.4		300.8		319.7
Other Income (Expense):
Interest Income	0.2		0.4		0.5		0.8
Carrying Costs Income	0.1		0.3		1.1		1.3
Allowance for Equity Funds Used During Construction	2		4.6		7.6		9.3
Non-Service Cost Components of Net Periodic Benefit Cost	3.7		3.8		11		11.3
Interest Expense	(32.9)		(29.4)		(96.2)		(88.4)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS	65.3		77.1		224.8		254
Income Tax Expense (Benefit)	8.9		18.1		26.2		39
Net Income (Loss)	56.4		59		198.6		215
Ohio Power Co [Member] | Transmission and Distribution Utilities [Member]
Revenues
Revenue from Contracts with Customers	761		730.4		2,167.8		2,031.4
Ohio Power Co [Member] | Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	2.4		2.3		6.8		7.3
TOTAL REVENUES	4.9	[5]	3.4	[6]	14.2	[7]	13.3	[8]
Ohio Power Co [Member] | Purchased Electricity for Resale [Member]
Expenses
Cost of Goods and Services Sold	184.7		149.3		513.6		412.3
Public Service Co Of Oklahoma [Member]
Revenues
Sales to AEP Affiliates	1		1.4		3.1		3.8
TOTAL REVENUES	483.8		382.2		1,124.4		988.1
Expenses
Other Operation	102.3		91.7		262.7		248.5
Maintenance	21.2		19.9		68.1		68.9
Depreciation and Amortization	48.9		40.1		149		129.8
Taxes Other Than Income Taxes	12.1		12.1		37.1		35.8
TOTAL EXPENSES	380.4		289.4		957.7		833.3
OPERATING INCOME (LOSS)	103.4		92.8		166.7		154.8
Other Income (Expense):
Interest Income	1.3		0		3		0.1
Allowance for Equity Funds Used During Construction	0.5		1.3		1.5		3.2
Non-Service Cost Components of Net Periodic Benefit Cost	2.1		2.1		6.4		6.3
Interest Expense	(16.2)		(14.6)		(44.7)		(45.9)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS	91.1		81.6		132.9		118.5
Income Tax Expense (Benefit)	(2.1)		1.3		(3.7)		2.1
Net Income (Loss)	93.2		80.3		136.6		116.4
Public Service Co Of Oklahoma [Member] | Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers	481.3		379.8		1,117.4		976.3
Public Service Co Of Oklahoma [Member] | Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	1.5		1		3.9		8
TOTAL REVENUES	0	[5]	0	[6]	0	[7]	0	[8]
Public Service Co Of Oklahoma [Member] | Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold	195.9		125.6		440.8		350.3
Southwestern Electric Power Co [Member]
Revenues
Sales to AEP Affiliates	13.5		10.9		32.2		31.5
TOTAL REVENUES	584.1		517.3		1,630.3		1,318.2
Expenses
Other Operation	91.7		96.8		270.6		259
Maintenance	33.7		30.7		99.5		97.2
Depreciation and Amortization	74.8		68.5		217.4		203.9
Taxes Other Than Income Taxes	28.9		26.7		89		77
TOTAL EXPENSES	443.5		395.4		1,329.2		1,068.6
OPERATING INCOME (LOSS)	140.6		121.9		301.1		249.6
Other Income (Expense):
Interest Income	2.8		0.6		6.9		1.7
Allowance for Equity Funds Used During Construction	1.4		3.4		5.4		5.7
Non-Service Cost Components of Net Periodic Benefit Cost	2.1		2.1		6.2		6.3
Interest Expense	(31.7)		(29.3)		(92.4)		(89.1)
INCOME BEFORE INCOME TAX EXPENSE AND EQUITY EARNINGS	115.2		98.7		227.2		174.2
Income Tax Expense (Benefit)	6.3		10.8		19		12.5
Equity Earnings (Loss) of Unconsolidated Subsidiaries	1		0.7		2.5		2.2
Net Income (Loss)	109.9		88.6		210.7		163.9
Net Income (Loss) Attributable to Noncontrolling Interests	1		0.7		2.6		2.1
Earnings Attributable to Common Shareholders	108.9		87.9		208.1		161.8
Southwestern Electric Power Co [Member] | Vertically Integrated Utilities [Member]
Revenues
Revenue from Contracts with Customers	570.1		505.7		1,596.6		1,284.3
Southwestern Electric Power Co [Member] | Other Revenues [Member]
Revenues
Revenue from Contracts with Customers	0.5		0.7		1.5		2.4
TOTAL REVENUES	0	[5]	0	[6]	0	[7]	0	[8]
Southwestern Electric Power Co [Member] | Purchased Electricity, Fuel and Other Consumables Used for Electric Generation [Member]
Expenses
Cost of Goods and Services Sold	$ 214.4		$ 172.7		$ 652.7		$ 431.5
[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.
[5]	Amounts include affiliated and nonaffiliated revenues.
[6]	Amounts include affiliated and nonaffiliated revenues.
[7]	Amounts include affiliated and nonaffiliated revenues.
[8]	Amounts include affiliated and nonaffiliated revenues.

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income (Loss) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Net Income (Loss)	$ 796.9	$ 748.2	$ 1,949.5	$ 1,762
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	179.7	39.3	365.9	17.6
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(2)	(1.8)	(6.1)	(5.3)
Other Comprehensive Income (Loss), Net of Tax, Total	177.7	37.5	359.8	12.3
TOTAL COMPREHENSIVE INCOME (LOSS)	974.6	785.7	2,309.3	1,774.3
Total Comprehensive Income (Loss) Attributable to Noncontrolling Interest	0.9	(0.4)	0.3	(2.6)
TOTAL COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	973.7	786.1	2,309	1,776.9
Cash Flow Hedges, Tax	47.8	10.5	97.3	4.7
Amortization of Pension and OPEB Deferred Costs, Tax	$ (0.5)	$ (0.5)	(1.6)	(1.4)
Common Stock, Dividends Per Share, Declared	$ 0.74	$ 0.70
Appalachian Power Co [Member]
Net Income (Loss)	$ 86.3	$ 116.6	275.1	313.2
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	(0.3)	0.6	8.5	(4.4)
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(1)	(0.9)	(3.1)	(2.8)
Other Comprehensive Income (Loss), Net of Tax, Total	(1.3)	(0.3)	5.4	(7.2)
TOTAL COMPREHENSIVE INCOME (LOSS)	85	116.3	280.5	306
Cash Flow Hedges, Tax	0	0.1	2.3	(1.2)
Amortization of Pension and OPEB Deferred Costs, Tax	(0.2)	(0.3)	(0.8)	(0.8)
AEP Texas Inc. [Member]
Net Income (Loss)	99.5	82.6	225.4	197.1
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	0.3	0.3	0.8	0.8
Amortization of Pension and OPEB Deferred Costs, Net of Tax	0	0	0.1	0.1
Other Comprehensive Income (Loss), Net of Tax, Total	0.3	0.3	0.9	0.9
TOTAL COMPREHENSIVE INCOME (LOSS)	99.8	82.9	226.3	198
Cash Flow Hedges, Tax	0.1	0.1	0.2	0.2
Amortization of Pension and OPEB Deferred Costs, Tax	0	0	0	0
Indiana Michigan Power Co [Member]
Net Income (Loss)	104.1	76.7	232.1	232.8
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	0.4	0.4	1.3	1.2
Amortization of Pension and OPEB Deferred Costs, Net of Tax	0	(0.1)	(0.1)	(0.1)
Other Comprehensive Income (Loss), Net of Tax, Total	0.4	0.3	1.2	1.1
TOTAL COMPREHENSIVE INCOME (LOSS)	104.5	77	233.3	233.9
Cash Flow Hedges, Tax	0.1	0.1	0.3	0.3
Amortization of Pension and OPEB Deferred Costs, Tax	0	0	0	0
Ohio Power Co [Member]
Net Income (Loss)	56.4	59	198.6	215
Public Service Co Of Oklahoma [Member]
Net Income (Loss)	93.2	80.3	136.6	116.4
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	0	(0.3)	(0.1)	(0.8)
Other Comprehensive Income (Loss), Net of Tax, Total		(0.3)
TOTAL COMPREHENSIVE INCOME (LOSS)	93.2	80	136.5	115.6
Cash Flow Hedges, Tax	0	0	0	(0.2)
Southwestern Electric Power Co [Member]
Net Income (Loss)	109.9	88.6	210.7	163.9
OTHER COMPREHENSIVE INCOME
Cash Flow Hedges, Net of Tax	0.3	0.4	1.1	1.1
Amortization of Pension and OPEB Deferred Costs, Net of Tax	(0.4)	(0.4)	(1.2)	(1.1)
Other Comprehensive Income (Loss), Net of Tax, Total	(0.1)	0	(0.1)	0
TOTAL COMPREHENSIVE INCOME (LOSS)	109.8	88.6	210.6	163.9
Total Comprehensive Income (Loss) Attributable to Noncontrolling Interest	1	0.7	2.6	2.1
TOTAL COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	108.8	87.9	208	161.8
Cash Flow Hedges, Tax	0.1	0.1	0.3	0.3
Amortization of Pension and OPEB Deferred Costs, Tax	(0.1)	(0.1)	(0.3)	(0.3)
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
OTHER COMPREHENSIVE INCOME
Other Comprehensive Income (Loss), Net of Tax, Total	(2)	(1.8)	(6.1)	(5.3)
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)	(0.9)	(3.1)	(2.8)
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	0.1	0.1
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	(0.1)	(0.1)	(0.1)
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | Southwestern Electric Power Co [Member]
OTHER COMPREHENSIVE INCOME
Other Comprehensive Income (Loss), Net of Tax, Total	$ (0.4)	$ (0.4)	$ (1.2)	$ (1.1)

Condensed Consolidated Statemen

Condensed Consolidated Statements of Changes in Equity - USD ($) $ in Millions	Total	Generation And Marketing [Member]	Appalachian Power Co [Member]	AEP Texas Inc. [Member]	AEP Transmission Co [Member]	Indiana Michigan Power Co [Member]	Ohio Power Co [Member]	Public Service Co Of Oklahoma [Member]	Southwestern Electric Power Co [Member]	Common Stock [Member]	Common Stock [Member]Appalachian Power Co [Member]	Common Stock [Member]Indiana Michigan Power Co [Member]	Common Stock [Member]Ohio Power Co [Member]	Common Stock [Member]Public Service Co Of Oklahoma [Member]	Common Stock [Member]Southwestern Electric Power Co [Member]	Additional Paid-in Capital [Member]		Additional Paid-in Capital [Member]Appalachian Power Co [Member]	Additional Paid-in Capital [Member]AEP Texas Inc. [Member]	Additional Paid-in Capital [Member]AEP Transmission Co [Member]	Additional Paid-in Capital [Member]Indiana Michigan Power Co [Member]	Additional Paid-in Capital [Member]Ohio Power Co [Member]	Additional Paid-in Capital [Member]Public Service Co Of Oklahoma [Member]	Additional Paid-in Capital [Member]Southwestern Electric Power Co [Member]	Retained Earnings [Member]		Retained Earnings [Member]Appalachian Power Co [Member]	Retained Earnings [Member]AEP Texas Inc. [Member]	Retained Earnings [Member]AEP Transmission Co [Member]	Retained Earnings [Member]Indiana Michigan Power Co [Member]	Retained Earnings [Member]Ohio Power Co [Member]	Retained Earnings [Member]Public Service Co Of Oklahoma [Member]	Retained Earnings [Member]Southwestern Electric Power Co [Member]	Accumulated Other Comprehensive Income [Member]	Accumulated Other Comprehensive Income [Member]Appalachian Power Co [Member]	Accumulated Other Comprehensive Income [Member]AEP Texas Inc. [Member]	Accumulated Other Comprehensive Income [Member]Indiana Michigan Power Co [Member]	Accumulated Other Comprehensive Income [Member]Public Service Co Of Oklahoma [Member]	Accumulated Other Comprehensive Income [Member]Southwestern Electric Power Co [Member]	Noncontrolling Interests [Member]	Noncontrolling Interests [Member]Southwestern Electric Power Co [Member]	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)	$ 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	1.6																1.8					0.4	0.3	0.3	1.6
Capital Contribution from Member					185															185
Net Income (Loss)																									495.2								15.1
Net Income (Loss) Attributable to Noncontrolling Interests																																								4.1	1
Net Income (Loss)	499.3		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)																										(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)	0.9	(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, 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)	1.1	(1.3)	281	0.6
Beginning Balance, Shares at Dec. 31, 2019										514,400,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Other Changes in Equity																									(120.6)
Dividends Paid on Common Stock			(150)		(5)	(63.7)	(65.6)	0
Net Income (Loss)	1,764.6								161.8
Net Income (Loss) Attributable to Noncontrolling Interests	(2.6)								2.1
Net Income (Loss)	1,762	$ 203.6	313.2	197.1	309.1	232.8	215	116.4	163.9
Other Comprehensive Income (Loss)	12.3		(7.2)	0.9		1.1			0
Ending Balance at Sep. 30, 2020					4,498.6															2,665.6									1,833
Ending Balance at Sep. 30, 2020	20,634.6		4,328.4	3,159.1		2,715	2,658.2	1,489.2	2,604.3	$ 3,357.6	260.4	56.6	321.2	157.2	0.1	6,522.3		1,828.7	1,457.9		980.9	838.8	364	812.2	10,621.4		2,241.5	1,713.1		1,688	1,498.2	967.7	1,792.9	(135.4)	(2.2)	(11.9)	(10.5)	0.3	(1.3)	268.7	0.4
Ending Balance, Shares at Sep. 30, 2020										516,600,000
Beginning Balance at Mar. 31, 2020					4,312.3															2,665.6									1,646.7
Beginning 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)	0.9	(1.3)	279.3	0.9
Beginning Balance, Shares at Mar. 31, 2020										515,400,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of Common Stock, Value	54.9									$ 5.2						49.7
Issuance of Common Stock, Shares										800,000
Common Stock Dividends	(340.9)																								(337.7)	[1]
Common Stock Dividends			(50)			(21.2)	(21.9)																				(50)			(21.2)	(21.9)
Common Stock Dividends									(1.2)																															(3.2)	(1.2)
Other Changes in Equity	(1.6)															(2.6)																								1
Dividends Paid on Common Stock					(5)																								(5)
Net Income (Loss)																									520.8								58.8
Net Income (Loss) Attributable to Noncontrolling Interests																																								(6.3)	0.4
Net Income (Loss)	514.5		81.3	66.9	73.7	63.8	80.9	46.4	59.2																		81.3	66.9	73.7	63.8	80.9	46.4
Other Comprehensive Income (Loss)	43.6		(1.8)	0.3		0.4		(0.3)																										43.6	(1.8)	0.3	0.4	(0.3)
Ending Balance at Jun. 30, 2020					4,381															2,665.6									1,715.4
Ending Balance at Jun. 30, 2020	$ 20,278.2		4,262.1	3,076.2		2,659.2	2,621	1,409.2	2,516.1	$ 3,355.4	260.4	56.6	321.2	157.2	135.7	6,603		1,828.7	1,457.9		980.9	838.8	364	676.6	10,221.9		2,174.9	1,630.5		1,632.5	1,461	887.4	1,705	(172.9)	(1.9)	(12.2)	(10.8)	0.6	(1.3)	270.8	0.1
Ending Balance, Shares at Jun. 30, 2020										516,200,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Dividends Per Share, Declared	$ 0.70
Issuance of Common Stock, Value	$ 25.5									$ 2.2						23.3
Issuance of Common Stock, Shares										400,000
Common Stock Dividends	(351.1)																								(349.1)	[1]
Common Stock Dividends			(50)			(21.2)	(21.8)																				(50)			(21.2)	(21.8)
Common Stock Dividends									(0.4)																															(2)	(0.4)
Other Changes in Equity	(103.7)															(104)	[2]																							0.3
Net Income (Loss)	748.6								87.9																748.6								87.9
Net Income (Loss) Attributable to Noncontrolling Interests	(0.4)								0.7																															(0.4)	0.7
Net Income (Loss)	748.2	114.6	116.6	82.6	117.6	76.7	59	80.3	88.6																		116.6	82.6	117.6	76.7	59	80.3
Other Comprehensive Income (Loss)	37.5		(0.3)	0.3		0.3		(0.3)	0																									37.5	(0.3)	0.3	0.3	(0.3)
Reverse Common Stock Split									0						(135.6)									135.6
Ending Balance at Sep. 30, 2020					4,498.6															2,665.6									1,833
Ending Balance at Sep. 30, 2020	$ 20,634.6		4,328.4	3,159.1		2,715	2,658.2	1,489.2	2,604.3	$ 3,357.6	260.4	56.6	321.2	157.2	0.1	6,522.3		1,828.7	1,457.9		980.9	838.8	364	812.2	10,621.4		2,241.5	1,713.1		1,688	1,498.2	967.7	1,792.9	(135.4)	(2.2)	(11.9)	(10.5)	0.3	(1.3)	268.7	0.4
Ending Balance, Shares at Sep. 30, 2020										516,600,000
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)	0.1	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)	[3]
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
Capital Contribution from Member					124			$ 425	100											124			425	100
Acquisition																																										$ 18.9	$ 18.9
Net Income (Loss)																									575								62.4
Net Income (Loss) Attributable to Noncontrolling Interests																																								3.8	1
Net Income (Loss)	578.8		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)																										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	1.9	247.2	1.6
Ending Balance, Shares at Mar. 31, 2021										519,500,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Dividends Per Share, Declared	$ 0.74
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)	0.1	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]
Other Changes in Equity																									0
Acquisition																																												$ 16
Dividends Paid on Common Stock			(37.5)		(112.5)	(175)	(71.9)	$ (20)
Net Income (Loss)	$ 1,949.2								208.1
Net Income (Loss) Attributable to Noncontrolling Interests	0.3								2.6
Net Income (Loss)	1,949.5	184.2	275.1	225.4	445.7	232.1	198.6	136.6	210.7
Other Comprehensive Income (Loss)	359.8		5.4	0.9		1.2			(0.1)
Ending Balance at Sep. 30, 2021					5,230.1															2,949.6									2,280.5
Ending Balance at Sep. 30, 2021	$ 22,527.2		4,587.3	3,432.3		2,807.5	2,819.4	$ 2,287.1	3,114.5	$ 3,404.5	260.4	56.6	321.2	157.2	0.1	7,075.9		1,828.7	1,457.9		980.9	838.8	1,039	1,092.2	11,523		2,485.6	1,982.4		1,775.8	1,659.4	1,090.9	2,020	274.7	12.6	(8)	(5.8)	0	1.8	249.1	0.4
Ending Balance, Shares at Sep. 30, 2021	523,773,631							10,482,000		523,800,000
Beginning Balance at Mar. 31, 2021					4,988.6															2,889.6									2,099
Beginning 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	1.9	247.2	1.6
Beginning Balance, Shares at Mar. 31, 2021										519,500,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of Common Stock, Value	72.3									$ 6.3						66
Issuance of Common Stock, Shares										900,000
Common Stock Dividends	(374.5)																								(371.8)	[3]
Common Stock Dividends			(12.5)			(75)	(21.9)	(10)																			(12.5)			(75)	(21.9)	(10)
Common Stock Dividends									(0.6)																															(2.7)	(0.6)
Other Changes in Equity	10.5															(0.2)									(0.4)															11.1
Capital Contribution from Member					60			200	75											60			200	75
Net Income (Loss)																									578.2								36.8
Net Income (Loss) Attributable to Noncontrolling Interests																																								(4.4)	0.6
Net Income (Loss)	573.8		66.3	79.8	148.6	57.2	74	46.1	37.4																		66.3	79.8	148.6	57.2	74	46.1
Other Comprehensive Income (Loss)	127.8		(1.2)	0.3		0.3																												127.8	(1.2)	0.3	0.3
Ending Balance at Jun. 30, 2021					5,197.2															2,949.6									2,247.6
Ending Balance at Jun. 30, 2021	$ 21,629.9		4,514.8	3,332.5		2,778	2,791.1	2,203.9	2,901.9	$ 3,382.7	260.4	56.6	321.2	157.2	0.1	6,800.3		1,828.7	1,457.9		980.9	838.8	1,039	987.2	11,098.7		2,411.8	1,882.9		1,746.7	1,631.1	1,007.7	1,911.1	97	13.9	(8.3)	(6.2)	0	1.9	251.2	1.6
Ending Balance, Shares at Jun. 30, 2021										520,400,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Dividends Per Share, Declared	$ 0.74
Issuance of Common Stock, Value	$ 291.1									$ 21.8						269.3
Issuance of Common Stock, Shares										3,400,000
Common Stock Dividends	(376.2)																								(371.7)	[3]
Common Stock Dividends			(12.5)			(75)	(28.1)	(10)																			(12.5)			(75)	(28.1)	(10)
Common Stock Dividends									(2.2)																															(4.5)	(2.2)
Other Changes in Equity	7.8															6.3																								1.5
Capital Contribution from Member									105															105
Dividends Paid on Common Stock					(112.5)																								(112.5)
Net Income (Loss)	796								108.9																796								108.9
Net Income (Loss) Attributable to Noncontrolling Interests	0.9								1																															0.9	1
Net Income (Loss)	796.9	$ 99.5	86.3	99.5	145.4	104.1	56.4	93.2	109.9																		86.3	99.5	145.4	104.1	56.4	93.2
Other Comprehensive Income (Loss)	177.7		(1.3)	0.3		0.4			(0.1)																									177.7	(1.3)	0.3	0.4		(0.1)
Ending Balance at Sep. 30, 2021					$ 5,230.1															$ 2,949.6									$ 2,280.5
Ending Balance at Sep. 30, 2021	$ 22,527.2		$ 4,587.3	$ 3,432.3		$ 2,807.5	$ 2,819.4	$ 2,287.1	$ 3,114.5	$ 3,404.5	$ 260.4	$ 56.6	$ 321.2	$ 157.2	$ 0.1	$ 7,075.9		$ 1,828.7	$ 1,457.9		$ 980.9	$ 838.8	$ 1,039	$ 1,092.2	$ 11,523		$ 2,485.6	$ 1,982.4		$ 1,775.8	$ 1,659.4	$ 1,090.9	$ 2,020	$ 274.7	$ 12.6	$ (8)	$ (5.8)	$ 0	$ 1.8	$ 249.1	$ 0.4
Ending Balance, Shares at Sep. 30, 2021	523,773,631							10,482,000		523,800,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Dividends Per Share, Declared	$ 0.74
[1]	Cash dividends declared per AEP common share were $0.70.
[2]	Includes $(121) million related to a forward equity purchase contract associated with the issuance of Equity Units.
[3]	Cash dividends declared per AEP common share were $0.74.

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Millions		Sep. 30, 2021	Dec. 31, 2020
Current Assets
Cash and Cash Equivalents		$ 1,372.7	$ 392.7
Restricted Cash		54	45.6
Other Temporary Investments		218.4	200.8
Accounts Receivable:
Customers		701.2	613.6
Accrued Unbilled Revenues		279.3	248.7
Pledged Accounts Receivable - AEP Credit		1,071.1	1,018.4
Miscellaneous		50.5	33.1
Allowance for Uncollectible Accounts		(51.7)	(71.1)
Total Accounts Receivable		2,050.4	1,842.7
Fuel		290.1	629.4
Materials and Supplies		688.4	680.6
Risk Management Assets		369.2	94.7
Accrued Tax Benefits		226.6	185.3
Regulatory Asset for Under-Recovered Fuel Costs		307	90.7
Margin Deposits		73.2	62
Prepayments and Other Current Assets		135.1	127
TOTAL CURRENT ASSETS		5,785.1	4,351.5
Property, Plant and Equipment
Generation		24,135.9	23,133.9
Transmission		29,555.1	27,886.7
Distribution		25,057.7	23,972.1
Other Property, Plant and Equipment		5,668.5	5,294.6
Construction Work in Progress		4,151	4,025.7
Total Property, Plant and Equipment		88,568.2	84,313
Accumulated Depreciation and Amortization		21,877	20,411.4
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		66,691.2	63,901.6
Other Noncurrent Assets
Regulatory Assets		5,031.5	3,527
Securitized Assets		580.4	657
Spent Nuclear Fuel and Decommissioning Trusts		3,609.8	3,306.7
Goodwill		52.5	52.5
Long-term Risk Management Assets		278.3	242.2
Operating Lease Assets		779.8	866.4
Deferred Charges and Other Noncurrent Assets		3,528.5	3,852.3
TOTAL OTHER NONCURRENT ASSETS		13,860.8	12,504.1
TOTAL ASSETS		86,337.1	80,757.2
Current Liabilities
Accounts Payable		1,597.1	1,709.7
Short-term Debt:
Securitized Debt for Receivables - AEP Credit	[1]	750	592
Other Short-term Debt		1,754	1,887.3
Total Short-term Debt		2,504	2,479.3
Long-term Debt Due Within One Year		2,521.8	2,086.1
Risk Management Liabilities		106.5	78.8
Customer Deposits		400.2	335.6
Accrued Taxes		1,046.6	1,476.4
Accrued Interest		349.7	267.6
Obligations Under Operating Leases		241.8	241.3
Regulatory Liability for Over-Recovered Fuel Costs		3.5	52.6
Other Current Liabilities		1,182.8	1,199.3
TOTAL CURRENT LIABILITIES		9,954	9,926.7
Noncurrent Liabilities
Long-term Debt		32,056.5	28,986.4
Affiliated Long Term Debt Noncurrent		0	0
Long-term Risk Management Liabilities		199.6	232.8
Deferred Income Taxes		8,644.8	8,240.9
Regulatory Liabilities and Deferred Investment Tax Credits		8,687.8	8,378.7
Asset Retirement Obligations		2,612	2,469.2
Employee Benefits and Pension Obligations		322.2	336.4
Obligations Under Operating Leases		586.8	638.4
Deferred Credits and Other Noncurrent Liabilities		672.9	728
TOTAL NONCURRENT LIABILITIES		53,782.6	50,010.8
TOTAL LIABILITIES		63,736.6	59,937.5
Rate Matters
Commitments and Contingencies
Contingently Reedemable Performance Share Awards		73.3	45.2
Total Mezzanine Equity		73.3	45.2
Equity
Common Stock		3,404.5	3,359.3
Paid-in Capital		7,075.9	6,588.9
Retained Earnings		11,523	10,687.8
Accumulated Other Comprehensive Income (Loss)		274.7	(85.1)
TOTAL COMMON SHAREHOLDER'S EQUITY		22,278.1	20,550.9
Noncontrolling Interests		249.1	223.6
TOTAL EQUITY		22,527.2	20,774.5
TOTAL LIABILITIES AND EQUITY		$ 86,337.1	$ 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		523,773,631	516,808,354
Commodity [Member]
Equity
Cross Default Provisions Maximum Third Party Obligation Amount		$ 50	$ 50
Subsidiaries [Member]
Current Assets
Restricted Cash		54	45.6
Other Temporary Investments		211.5	194.6
Short-term Debt:
Long-term Debt Due Within One Year		203.2	198.3
Noncurrent Liabilities
Long-term Debt		887	950.1
AEP Texas Inc. [Member]
Current Assets
Cash and Cash Equivalents		0.1	0.1
Restricted Cash		43.9	28.7
Advances to Affiliates		54.6	7.1
Accounts Receivable:
Customers		142.1	112.8
Affiliated Companies - Contracts with Customers		4.8	5.1
Accrued Unbilled Revenues		81	65.8
Allowance for Uncollectible Accounts		(4.1)	(0.1)
Total Accounts Receivable		223.8	183.6
Materials and Supplies		72.5	70
Accrued Tax Benefits		23.7	16.8
Prepayments and Other Current Assets		6.9	4.6
TOTAL CURRENT ASSETS		425.5	310.9
Property, Plant and Equipment
Transmission		5,627.1	5,279.6
Distribution		4,823.7	4,580.8
Other Property, Plant and Equipment		944.3	868.4
Construction Work in Progress		539.4	614.1
Total Property, Plant and Equipment		11,934.5	11,342.9
Accumulated Depreciation and Amortization		1,621.1	1,529.3
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		10,313.4	9,813.6
Other Noncurrent Assets
Regulatory Assets		290.4	266.8
Securitized Assets		389.1	446.8
Deferred Charges and Other Noncurrent Assets		213.1	192.1
TOTAL OTHER NONCURRENT ASSETS		892.6	905.7
TOTAL ASSETS		11,631.5	11,030.2
Current Liabilities
Advances from Affiliates		0	67.1
Accounts Payable		194.3	231.7
Affiliated Companies		29.4	44
Short-term Debt:
Long-term Debt Due Within One Year		315.1	88.7
Accrued Taxes		114.7	78.3
Accrued Interest		60.7	43.9
Obligations Under Operating Leases		14.1	14.5
Other Current Liabilities		98.4	108.6
TOTAL CURRENT LIABILITIES		826.7	676.8
Noncurrent Liabilities
Long-term Debt		4,901	4,731.7
Deferred Income Taxes		1,087.1	1,016.7
Regulatory Liabilities and Deferred Investment Tax Credits		1,256.8	1,270.8
Obligations Under Operating Leases		64.5	71
Deferred Credits and Other Noncurrent Liabilities		63.1	57.2
TOTAL NONCURRENT LIABILITIES		7,372.5	7,147.4
TOTAL LIABILITIES		8,199.2	7,824.2
Rate Matters
Commitments and Contingencies
Equity
Paid-in Capital		1,457.9	1,457.9
Retained Earnings		1,982.4	1,757
Accumulated Other Comprehensive Income (Loss)		(8)	(8.9)
TOTAL EQUITY		3,432.3	3,206
TOTAL LIABILITIES AND EQUITY		11,631.5	11,030.2
AEP Texas Inc. [Member] | AEP Texas Transition Funding and Restoration Funding [Member]
Current Assets
Restricted Cash		43.9	28.7
Other Noncurrent Assets
Securitized Assets		389.1	446.8
Short-term Debt:
Long-term Debt Due Within One Year		90.1	88.7
Accrued Interest		3	2.5
Noncurrent Liabilities
Long-term Debt		350.9	403.9
AEP Transmission Co [Member]
Current Assets
Cash and Cash Equivalents		0	0
Advances to Affiliates		79.2	109.1
Accounts Receivable:
Customers		31	22.9
Affiliated Companies - Contracts with Customers		96.7	81.2
Total Accounts Receivable		127.7	104.1
Materials and Supplies		9	8.5
Prepayments and Other Current Assets		3.5	14.1
TOTAL CURRENT ASSETS		219.4	235.8
Property, Plant and Equipment
Transmission		10,458.4	9,593.5
Other Property, Plant and Equipment		393.5	329.5
Construction Work in Progress		1,507.4	1,422.6
Total Property, Plant and Equipment		12,359.3	11,345.6
Accumulated Depreciation and Amortization		730.4	572.8
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		11,628.9	10,772.8
Other Noncurrent Assets
Regulatory Assets		10.1	15.1
Deferred Property Taxes		66.1	220.1
Deferred Charges and Other Noncurrent Assets		6.6	2.2
TOTAL OTHER NONCURRENT ASSETS		82.8	237.4
TOTAL ASSETS		11,931.1	11,246
Current Liabilities
Advances from Affiliates		13.9	156.7
Accounts Payable		298.8	380.4
Affiliated Companies		67.6	97.3
Short-term Debt:
Long-term Debt Due Within One Year		50	50
Accrued Taxes		269.5	418.1
Accrued Interest		50.2	23.9
Obligations Under Operating Leases		0.9	1.2
Other Current Liabilities		8.1	9.9
TOTAL CURRENT LIABILITIES		759	1,137.5
Noncurrent Liabilities
Long-term Debt		4,343.4	3,898.5
Deferred Income Taxes		955.2	906.9
Regulatory Liabilities and Deferred Investment Tax Credits		633.9	581.8
Obligations Under Operating Leases		1	0.4
Deferred Credits and Other Noncurrent Liabilities		8.5	8
TOTAL NONCURRENT LIABILITIES		5,942	5,395.6
TOTAL LIABILITIES		6,701	6,533.1
Rate Matters
Commitments and Contingencies
Equity
Paid-in Captial		2,949.6	2,765.6
Retained Earnings		2,280.5	1,947.3
TOTAL MEMBER'S EQUITY		5,230.1	4,712.9
TOTAL LIABILITIES AND EQUITY		11,931.1	11,246
Appalachian Power Co [Member]
Current Assets
Cash and Cash Equivalents		5	5.8
Restricted Cash		10.1	16.9
Advances to Affiliates		185.2	21.4
Accounts Receivable:
Customers		119.3	142.8
Affiliated Companies - Contracts with Customers		77.4	64.3
Accrued Unbilled Revenues		53.6	80.1
Miscellaneous		0.2	0.3
Allowance for Uncollectible Accounts		(1.6)	(3.1)
Total Accounts Receivable		248.9	284.4
Fuel		66.6	193.6
Materials and Supplies		100.3	99.6
Risk Management Assets		47	22.4
Regulatory Asset for Under-Recovered Fuel Costs		49.2	5.3
Prepayments and Other Current Assets		72.1	24.7
TOTAL CURRENT ASSETS		784.4	674.1
Property, Plant and Equipment
Generation		6,670.8	6,633.7
Transmission		4,052.9	3,900.5
Distribution		4,621.1	4,464.3
Other Property, Plant and Equipment		682.4	627.2
Construction Work in Progress		567.7	484.6
Total Property, Plant and Equipment		16,594.9	16,110.3
Accumulated Depreciation and Amortization		4,973.1	4,716.2
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		11,621.8	11,394.1
Other Noncurrent Assets
Regulatory Assets		818.6	686.3
Securitized Assets		191.3	210.1
Employee Benefits and Pension Assets		156.8	150.1
Operating Lease Assets		70.4	78.8
Deferred Charges and Other Noncurrent Assets		93.5	121.7
TOTAL OTHER NONCURRENT ASSETS		1,330.6	1,247
TOTAL ASSETS		13,736.8	13,315.2
Current Liabilities
Advances from Affiliates		0	18.6
Accounts Payable		224.7	212
Affiliated Companies		97.2	97.1
Short-term Debt:
Long-term Debt Due Within One Year		380.6	518.3
Customer Deposits		72.9	77.8
Accrued Taxes		88.5	109.9
Accrued Interest		80	49.9
Obligations Under Operating Leases		15.1	14.9
Other Current Liabilities		107.6	119.2
TOTAL CURRENT LIABILITIES		1,066.6	1,217.7
Noncurrent Liabilities
Long-term Debt		4,557.2	4,315.8
Deferred Income Taxes		1,739.3	1,749.9
Regulatory Liabilities and Deferred Investment Tax Credits		1,250.9	1,224.7
Asset Retirement Obligations		393.6	304.8
Employee Benefits and Pension Obligations		42.9	44
Obligations Under Operating Leases		55.9	64.4
Deferred Credits and Other Noncurrent Liabilities		43.1	49.6
TOTAL NONCURRENT LIABILITIES		8,082.9	7,753.2
TOTAL LIABILITIES		9,149.5	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		2,485.6	2,248
Accumulated Other Comprehensive Income (Loss)		12.6	7.2
TOTAL EQUITY		4,587.3	4,344.3
TOTAL LIABILITIES AND EQUITY		$ 13,736.8	$ 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		$ 3.2	$ 3.3
Advances to Affiliates		80.6	13.3
Accounts Receivable:
Customers		39.8	44
Affiliated Companies - Contracts with Customers		37.9	51.3
Miscellaneous		2.8	2
Allowance for Uncollectible Accounts		(0.3)	(0.3)
Total Accounts Receivable		80.2	97
Fuel		46.7	86
Materials and Supplies		172.2	175.8
Risk Management Assets		5.5	3.6
Accrued Tax Benefits		0.1	10.3
Regulatory Asset for Under-Recovered Fuel Costs		6.1	5.4
Prepayments and Other Current Assets		26.7	24.1
TOTAL CURRENT ASSETS		421.3	418.8
Property, Plant and Equipment
Generation		5,329.6	5,264.7
Transmission		1,749.4	1,696.4
Distribution		2,734.6	2,594.6
Other Property, Plant and Equipment		684.5	686.7
Construction Work in Progress		377.6	362.4
Total Property, Plant and Equipment		10,875.7	10,604.8
Accumulated Depreciation and Amortization		3,811.9	3,552.5
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		7,063.8	7,052.3
Other Noncurrent Assets
Regulatory Assets		436.1	404.8
Spent Nuclear Fuel and Decommissioning Trusts		3,609.8	3,306.7
Operating Lease Assets		154.7	218.1
Deferred Charges and Other Noncurrent Assets		219.5	237.6
TOTAL OTHER NONCURRENT ASSETS		4,420.1	4,167.2
TOTAL ASSETS		11,905.2	11,638.3
Current Liabilities
Advances from Affiliates		0	103
Accounts Payable		132.8	153.2
Affiliated Companies		86.2	80.5
Short-term Debt:
Long-term Debt Due Within One Year		132.7	369.6
Risk Management Liabilities		2.5	0.1
Customer Deposits		42.4	41.7
Accrued Taxes		72	102.5
Accrued Interest		25	35.6
Obligations Under Operating Leases		86.2	85.6
Regulatory Liability for Over-Recovered Fuel Costs		3.5	20.8
Other Current Liabilities		104.2	111.9
TOTAL CURRENT LIABILITIES		687.5	1,104.5
Noncurrent Liabilities
Long-term Debt		3,098.4	2,660.3
Deferred Income Taxes		1,082.9	1,064.4
Regulatory Liabilities and Deferred Investment Tax Credits		2,201.2	2,041.9
Asset Retirement Obligations		1,869.2	1,812.9
Obligations Under Operating Leases		88.4	135.9
Deferred Credits and Other Noncurrent Liabilities		70.1	69.2
TOTAL NONCURRENT LIABILITIES		8,410.2	7,784.6
TOTAL LIABILITIES		9,097.7	8,889.1
Rate Matters
Commitments and Contingencies
Equity
Common Stock		56.6	56.6
Paid-in Capital		980.9	980.9
Retained Earnings		1,775.8	1,718.7
Accumulated Other Comprehensive Income (Loss)		(5.8)	(7)
TOTAL EQUITY		2,807.5	2,749.2
TOTAL LIABILITIES AND EQUITY		$ 11,905.2	$ 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		$ 78.7	$ 75.7
Ohio Power Co [Member]
Current Assets
Cash and Cash Equivalents		6.8	7.4
Advances to Affiliates		622.9	0
Accounts Receivable:
Customers		31	50
Affiliated Companies - Contracts with Customers		64.7	65.1
Accrued Unbilled Revenues		15.3	14.8
Miscellaneous		5.8	3.9
Allowance for Uncollectible Accounts		(0.6)	(0.6)
Total Accounts Receivable		116.2	133.2
Materials and Supplies		70.9	66.9
Renewable Energy Credits		31.1	29.5
Prepayments and Other Current Assets		29.6	19.3
TOTAL CURRENT ASSETS		877.5	256.3
Property, Plant and Equipment
Transmission		2,936.3	2,831.9
Distribution		5,989.2	5,708.3
Other Property, Plant and Equipment		979.9	899.6
Construction Work in Progress		331.7	362.3
Total Property, Plant and Equipment		10,237.1	9,802.1
Accumulated Depreciation and Amortization		2,438.7	2,350
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		7,798.4	7,452.1
Other Noncurrent Assets
Regulatory Assets		343.8	385.8
Operating Lease Assets		84.2	92
Deferred Charges and Other Noncurrent Assets		292.4	524.2
TOTAL OTHER NONCURRENT ASSETS		720.4	1,002
TOTAL ASSETS		9,396.3	8,710.4
Current Liabilities
Advances from Affiliates		0	259.2
Accounts Payable		169	181
Affiliated Companies		101.5	118.4
Short-term Debt:
Long-term Debt Due Within One Year		500.1	500.1
Risk Management Liabilities		3.5	8.7
Customer Deposits		123.5	55.1
Accrued Taxes		344.8	631
Obligations Under Operating Leases		13.1	13.1
Other Current Liabilities		149.6	139.6
TOTAL CURRENT LIABILITIES		1,405.1	1,906.2
Noncurrent Liabilities
Long-term Debt		2,968	1,930.1
Long-term Risk Management Liabilities		86.9	101.6
Deferred Income Taxes		1,010.7	955.1
Regulatory Liabilities and Deferred Investment Tax Credits		995.7	1,005.2
Obligations Under Operating Leases		71.6	79.5
Deferred Credits and Other Noncurrent Liabilities		38.9	40
TOTAL NONCURRENT LIABILITIES		5,171.8	4,111.5
TOTAL LIABILITIES		6,576.9	6,017.7
Rate Matters
Commitments and Contingencies
Equity
Common Stock		321.2	321.2
Paid-in Capital		838.8	838.8
Retained Earnings		1,659.4	1,532.7
TOTAL EQUITY		2,819.4	2,692.7
TOTAL LIABILITIES AND EQUITY		$ 9,396.3	$ 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		$ 3.6	$ 2.6
Advances to Affiliates		59.5	0
Accounts Receivable:
Customers		29.7	30.8
Affiliated Companies - Contracts with Customers		31.7	15.6
Miscellaneous		0.4	2
Total Accounts Receivable		61.8	48.4
Fuel		7.6	17.9
Materials and Supplies		54.4	54
Risk Management Assets		18.5	10.3
Accrued Tax Benefits		35.7	10.9
Regulatory Asset for Under-Recovered Fuel Costs		133.4	30.1
Prepayments and Other Current Assets		13.1	7.1
TOTAL CURRENT ASSETS		387.6	181.3
Property, Plant and Equipment
Generation		1,795.2	1,480.7
Transmission		1,095.9	1,069.9
Distribution		2,959.7	2,853
Other Property, Plant and Equipment		427.8	393.3
Construction Work in Progress		127.7	128.7
Total Property, Plant and Equipment		6,406.3	5,925.6
Accumulated Depreciation and Amortization		1,682.6	1,605.6
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		4,723.7	4,320
Other Noncurrent Assets
Regulatory Assets		1,052.3	375
Employee Benefits and Pension Assets		66.2	65.8
Operating Lease Assets		70.4	42.6
Deferred Charges and Other Noncurrent Assets		18.9	6
TOTAL OTHER NONCURRENT ASSETS		1,207.8	489.4
TOTAL ASSETS		6,319.1	4,990.7
Current Liabilities
Advances from Affiliates		0	155.4
Accounts Payable		146.4	107
Affiliated Companies		32	43.4
Short-term Debt:
Long-term Debt Due Within One Year		0.5	0.5
Customer Deposits		54	54.8
Accrued Taxes		60.9	26.8
Obligations Under Operating Leases		6.9	6.5
Other Current Liabilities		67.9	84.2
TOTAL CURRENT LIABILITIES		368.6	478.6
Noncurrent Liabilities
Long-term Debt		1,912.8	1,373.3
Deferred Income Taxes		764	688.5
Regulatory Liabilities and Deferred Investment Tax Credits		846.2	802.2
Asset Retirement Obligations		55	45.7
Obligations Under Operating Leases		63.7	36.2
Deferred Credits and Other Noncurrent Liabilities		21.7	20.6
TOTAL NONCURRENT LIABILITIES		3,663.4	2,966.5
TOTAL LIABILITIES		4,032	3,445.1
Rate Matters
Commitments and Contingencies
Equity
Common Stock		157.2	157.2
Paid-in Capital		1,039	414
Retained Earnings		1,090.9	974.3
Accumulated Other Comprehensive Income (Loss)		0	0.1
TOTAL EQUITY		2,287.1	1,545.6
TOTAL LIABILITIES AND EQUITY		$ 6,319.1	$ 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		$ 45	$ 13.2
Advances to Affiliates		2.1	2.1
Accounts Receivable:
Customers		76.2	27.1
Affiliated Companies - Contracts with Customers		35.6	25.1
Miscellaneous		23.3	12.7
Total Accounts Receivable		135.1	64.9
Fuel		95.4	191.1
Materials and Supplies		86.8	95.8
Risk Management Assets		17.5	3.2
Accrued Tax Benefits		19.8	29.9
Regulatory Asset for Under-Recovered Fuel Costs		38.7	2.6
Prepayments and Other Current Assets		20.8	25.2
TOTAL CURRENT ASSETS		461.2	428
Property, Plant and Equipment
Generation		5,065.5	4,681.4
Transmission		2,264.6	2,165.7
Distribution		2,499.2	2,382.5
Other Property, Plant and Equipment		817.6	788.8
Construction Work in Progress		195.5	228.3
Total Property, Plant and Equipment		10,842.4	10,246.7
Accumulated Depreciation and Amortization		3,478.5	3,158.5
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		7,363.9	7,088.2
Other Noncurrent Assets
Regulatory Assets		1,068	403.1
Long-term Risk Management Assets		2.1	0
Deferred Charges and Other Noncurrent Assets		277.3	234.8
TOTAL OTHER NONCURRENT ASSETS		1,347.4	637.9
TOTAL ASSETS		9,172.5	8,154.1
Current Liabilities
Advances from Affiliates		122.9	124.6
Accounts Payable		114.7	135.9
Affiliated Companies		43.4	43
Short-term Debt:
Other Short-term Debt		0	35
Long-term Debt Due Within One Year		381.2	106.2
Risk Management Liabilities		0	0.7
Customer Deposits		60.7	61.3
Accrued Taxes		103.1	41
Accrued Interest		23	34.6
Obligations Under Operating Leases		8.3	7.9
Other Current Liabilities		119.6	173.4
TOTAL CURRENT LIABILITIES		976.9	763.6
Noncurrent Liabilities
Long-term Debt		2,748.7	2,530.2
Long-term Risk Management Liabilities		0	1
Deferred Income Taxes		1,067.6	1,017.6
Regulatory Liabilities and Deferred Investment Tax Credits		879.8	863.4
Asset Retirement Obligations		193.4	193.7
Employee Benefits and Pension Obligations		23.8	18.6
Obligations Under Operating Leases		79.2	44.1
Deferred Credits and Other Noncurrent Liabilities		88.6	94.2
TOTAL NONCURRENT LIABILITIES		5,081.1	4,762.8
TOTAL LIABILITIES		6,058	5,526.4
Rate Matters
Commitments and Contingencies
Equity
Common Stock		0.1	0.1
Paid-in Capital		1,092.2	812.2
Retained Earnings		2,020	1,811.9
Accumulated Other Comprehensive Income (Loss)		1.8	1.9
TOTAL COMMON SHAREHOLDER'S EQUITY		3,114.1	2,626.1
Noncontrolling Interests		0.4	1.6
TOTAL EQUITY		3,114.5	2,627.7
TOTAL LIABILITIES AND EQUITY		$ 9,172.5	$ 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		$ 41	$ 10.1
Accounts Receivable:
Fuel		6.7	35.2
Materials and Supplies		15.9	23.3
Property, Plant and Equipment
Other Property, Plant and Equipment		220.2	223.7
Accumulated Depreciation and Amortization		$ 156.7	$ 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	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
Operating Activities
Net Income (Loss)	$ 1,949.5	$ 1,762
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	2,103.9	1,996.3
Rockport Plant, Unit 2 Operating Lease Amortization	100.8	102.4
Deferred Income Taxes	191.1	142.5
Allowance for Equity Funds Used During Construction	(103.9)	(111.7)
Mark-to-Market of Risk Management Contracts	101	46.4
Amortization of Nuclear Fuel	61.9	67.2
Pension Contributions to Qualified Plan Trust	0	(110.3)
Property Taxes	415.1	396.9
Deferred Fuel Over/Under-Recovery, Net	(1,356.8)	27.4
Change in Other Noncurrent Assets	(270.7)	(322)
Change in Other Noncurrent Liabilities	162.7	(25.1)
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(199.2)	(138.9)
Fuel, Materials and Supplies	347.4	(97.4)
Accounts Payable	107.6	21.9
Accrued Taxes, Net	(471.1)	(502.9)
Rockport Plant, Unit 2 Operating Lease	(73.9)	(73.9)
Other Current Assets	(33.3)	26
Other Current Liabilities	(59.1)	(284.6)
Net Cash Flows from (Used for) Operating Activities	2,973	2,922.2
Investing Activities
Construction Expenditures	(4,087)	(4,690.4)
Purchases of Investment Securities	(1,612.3)	(1,329.5)
Sales of Investment Securities	1,571.7	1,293
Acquisitions of Nuclear Fuel	(63.2)	(68.4)
Other Investing Activities	51.8	88
Net Cash Flows from (Used for) Investing Activities	(4,906.2)	(4,707.3)
Financing Activities
Issuance of Common Stock	548	136.5
Issuance of Long-term Debt	5,062.3	3,985.8
Issuance of Short-term Debt with Original Maturities greater than 90 Days	1,178.5	1,304.5
Change in Short-term Debt with Original Maturities less than 90 Days, Net	(632.5)	(1,445.8)
Retirement of Long-term Debt	(1,549.8)	(700.5)
Redemption of Short-term Debt with Original Maturities Greater than 90 Days	(521.3)	(300)
Principal Payments for Finance Leases Obligations	(45.3)	(46.3)
Dividends Paid on Common Stock	(1,122.7)	(1,055.7)
Redemption of Noncontrolling Interest in Trent & Desert Sky Windfarms	0	(56.5)
Other Financing Activities	4.4	(5.7)
Net Cash Flows from (Used for) Financing Activities	2,921.6	1,816.3
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	988.4	31.2
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	1,426.7	463.8
Cash and Cash Equivalents at End of Period	1,372.7
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	775.2	690.5
Net Cash Paid (Received) for Income Taxes	9.3	(23.9)
Noncash Acquisitions Under Finance Leases	23	33
Construction Expenditures Included in Current Liabilities as of September 30,	764.1	830.1
Construction Expenditures Included in Noncurrent Liabilities as of September 30,	0	8.3
Acquisition of Nuclear Fuel Included in Current Liabilities as of September 30,	0.3	1
Noncash Contribution of Assets to Cedar Creek Project	(9.3)	0
Expected Reimbursement for Spent Nuclear Fuel Dry Cask Storage	0.6	2.4
Retained Earnings [Member]
Supplementary Information
Forward Equity Purchase Contract Included in Current and Noncurrent Liabilities as of September 30,	0	120.6
Dry Lake Solar Project
Investing Activities
Acquisitions of Assets	(114.4)	0
North Central Wind Energy Facilities
Investing Activities
Acquisitions of Assets	(652.8)	0
AEP Texas Inc. [Member]
Operating Activities
Net Income (Loss)	225.4	197.1
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	287.1	435.8
Deferred Income Taxes	45.8	(11.5)
Allowance for Equity Funds Used During Construction	(16.7)	(14.4)
Mark-to-Market of Risk Management Contracts	0	0.1
Pension Contributions to Qualified Plan Trust	0	(11.3)
Change in Other Noncurrent Assets	(73.4)	(77.3)
Change in Other Noncurrent Liabilities	17.5	(30)
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(40.2)	(40.2)
Fuel, Materials and Supplies	(2.5)	(9.4)
Accounts Payable	(10.9)	24.2
Accrued Taxes, Net	29.5	73.4
Other Current Assets	(2)	(0.8)
Other Current Liabilities	(5)	(49.8)
Net Cash Flows from (Used for) Operating Activities	454.6	485.9
Investing Activities
Construction Expenditures	(742.4)	(976.1)
Change in Advances to Affiliates, Net	(47.5)	58.8
Other Investing Activities	29.6	24.1
Net Cash Flows from (Used for) Investing Activities	(760.3)	(893.2)
Financing Activities
Issuance of Long-term Debt	444.2	652.8
Change in Short-term Debt with Original Maturities less than 90 Days, Net	0	2
Change in Advances from Affiliates, Net	(67.1)	0
Retirement of Long-term Debt	(52.2)	(356.5)
Principal Payments for Finance Leases Obligations	(5)	(4.7)
Other Financing Activities	1	0.8
Net Cash Flows from (Used for) Financing Activities	320.9	294.4
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	15.2	(112.9)
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	44	44.9
Cash and Cash Equivalents at End of Period	0.1
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	110	102
Net Cash Paid (Received) for Income Taxes	(8.4)	(55.6)
Noncash Acquisitions Under Finance Leases	3.3	5.1
Construction Expenditures Included in Current Liabilities as of September 30,	134.9	167.6
AEP Transmission Co [Member]
Operating Activities
Net Income (Loss)	445.7	309.1
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	219	176.4
Deferred Income Taxes	46.8	65.4
Allowance for Equity Funds Used During Construction	(49.3)	(54.9)
Property Taxes	154	136.3
Change in Other Noncurrent Assets	2.3	(1.5)
Change in Other Noncurrent Liabilities	8.3	19.5
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(23.6)	(30.1)
Fuel, Materials and Supplies	(0.5)	0.2
Accounts Payable	(10.7)	26
Accrued Taxes, Net	(138.8)	(139)
Accrued Interest	26.3	29
Other Current Assets	0.5	9.1
Other Current Liabilities	(3.6)	(10.7)
Net Cash Flows from (Used for) Operating Activities	676.4	534.8
Investing Activities
Construction Expenditures	(1,070.8)	(1,163.8)
Change in Advances to Affiliates, Net	29.9	(21.3)
Other Investing Activities	(7.9)	1.1
Net Cash Flows from (Used for) Investing Activities	(1,048.8)	(1,184)
Financing Activities
Capital Contributions from Parent	184	185
Issuance of Long-term Debt	443.7	519.4
Change in Advances from Affiliates, Net	(142.8)	(50.2)
Dividends Paid on Common Stock	(112.5)	(5)
Net Cash Flows from (Used for) Financing Activities	372.4	649.2
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	75.8	63.3
Net Cash Paid (Received) for Income Taxes	37.6	1.9
Construction Expenditures Included in Current Liabilities as of September 30,	206.8	283.6
Appalachian Power Co [Member]
Operating Activities
Net Income (Loss)	275.1	313.2
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	406.6	366
Deferred Income Taxes	(12)	(28.2)
Allowance for Equity Funds Used During Construction	(12.1)	(11.5)
Mark-to-Market of Risk Management Contracts	(26.8)	8
Pension Contributions to Qualified Plan Trust	0	(7)
Deferred Fuel Over/Under-Recovery, Net	(43.9)	38.8
Change in Other Noncurrent Assets	(39.2)	5.4
Change in Other Noncurrent Liabilities	20.2	(26)
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	38.1	7.2
Fuel, Materials and Supplies	126.3	12.4
Accounts Payable	26.5	(74)
Accrued Taxes, Net	(48)	1.9
Other Current Assets	(20.7)	10.1
Other Current Liabilities	0.5	(9.7)
Net Cash Flows from (Used for) Operating Activities	690.6	606.6
Investing Activities
Construction Expenditures	(586.4)	(566.6)
Change in Advances to Affiliates, Net	(163.8)	(137.4)
Other Investing Activities	12.4	4.6
Net Cash Flows from (Used for) Investing Activities	(737.8)	(699.4)
Financing Activities
Issuance of Long-term Debt	494	557.2
Change in Advances from Affiliates, Net	(18.6)	(232.4)
Retirement of Long-term Debt	(393)	(90.3)
Principal Payments for Finance Leases Obligations	(5.8)	(5.6)
Dividends Paid on Common Stock	(37.5)	(150)
Other Financing Activities	0.5	0.3
Net Cash Flows from (Used for) Financing Activities	39.6	79.2
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(7.6)	(13.6)
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	15.1	13.2
Cash and Cash Equivalents at End of Period	5
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	124.2	130
Net Cash Paid (Received) for Income Taxes	52.6	(10.7)
Noncash Acquisitions Under Finance Leases	1.3	3
Construction Expenditures Included in Current Liabilities as of September 30,	92.3	90
Indiana Michigan Power Co [Member]
Operating Activities
Net Income (Loss)	232.1	232.8
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	328.7	303.6
Rockport Plant, Unit 2 Operating Lease Amortization	51.1	51.9
Deferred Income Taxes	(36.6)	(6.1)
Amortization (Deferral) of Incremental Nuclear Refueling Outage Expenses, Net	(2.5)	21.3
Allowance for Equity Funds Used During Construction	(9.7)	(8.8)
Mark-to-Market of Risk Management Contracts	0.5	5.6
Amortization of Nuclear Fuel	61.9	67.2
Pension Contributions to Qualified Plan Trust	0	(6.4)
Deferred Fuel Over/Under-Recovery, Net	(18)	23.4
Change in Other Noncurrent Assets	7.3	40.8
Change in Other Noncurrent Liabilities	(10.2)	30.2
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	18.2	32.2
Fuel, Materials and Supplies	43	(15.4)
Accounts Payable	20.1	(0.9)
Accrued Taxes, Net	(20.3)	(84.4)
Operating Lease, Payments	(36.9)	(36.9)
Other Current Assets	(0.7)	6.6
Other Current Liabilities	(28)	(59.1)
Net Cash Flows from (Used for) Operating Activities	600	597.6
Investing Activities
Construction Expenditures	(370.2)	(409.1)
Change in Advances to Affiliates, Net	(67.3)	(0.1)
Purchases of Investment Securities	(1,586.3)	(1,290)
Sales of Investment Securities	1,556.6	1,257.1
Acquisitions of Nuclear Fuel	(63.2)	(68.4)
Other Investing Activities	12.9	8.3
Net Cash Flows from (Used for) Investing Activities	(517.5)	(502.2)
Financing Activities
Issuance of Long-term Debt	507	0
Change in Advances from Affiliates, Net	(103)	44.7
Retirement of Long-term Debt	(307.2)	(71.1)
Principal Payments for Finance Leases Obligations	(4.9)	(4.8)
Dividends Paid on Common Stock	(175)	(63.7)
Other Financing Activities	0.5	0.3
Net Cash Flows from (Used for) Financing Activities	(82.6)	(94.6)
Net Increase (Decrease) in Cash and Cash Equivalents	(0.1)	0.8
Cash and Cash Equivalents at Beginning of Period	3.3	2
Cash and Cash Equivalents at End of Period	3.2	2.8
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	93.9	97.5
Net Cash Paid (Received) for Income Taxes	11.8	59.7
Noncash Acquisitions Under Finance Leases	3.1	1.9
Construction Expenditures Included in Current Liabilities as of September 30,	59	57.6
Acquisition of Nuclear Fuel Included in Current Liabilities as of September 30,	0.3	1
Expected Reimbursement for Spent Nuclear Fuel Dry Cask Storage	0.6	2.4
Ohio Power Co [Member]
Operating Activities
Net Income (Loss)	198.6	215
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	228.6	204.4
Deferred Income Taxes	29.3	35.6
Carrying Costs Income	(1.1)	(1.3)
Allowance for Equity Funds Used During Construction	(7.6)	(9.3)
Mark-to-Market of Risk Management Contracts	(19.9)	9.7
Pension Contributions to Qualified Plan Trust		(0.1)
Property Taxes	234.9	225.1
Change in Other Noncurrent Assets	(1.1)	(93.8)
Change in Other Noncurrent Liabilities	4.6	(58.3)
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	20.7	33.4
Fuel, Materials and Supplies	(0.6)	(19.8)
Accounts Payable	(19.1)	(19.9)
Increase (Decrease) in Contract with Customer, Liability	68.4	12.4
Accrued Taxes, Net	(289.7)	(266.2)
Other Current Assets	(7.8)	(2.5)
Other Current Liabilities	5.8	(35.7)
Net Cash Flows from (Used for) Operating Activities	445.1	230.1
Investing Activities
Construction Expenditures	(536.6)	(604.6)
Change in Advances to Affiliates, Net	(622.9)	0
Other Investing Activities	10.7	14.1
Net Cash Flows from (Used for) Investing Activities	(1,148.8)	(590.5)
Financing Activities
Issuance of Long-term Debt	1,037.5	347
Change in Advances from Affiliates, Net	(259.2)	84.9
Retirement of Long-term Debt	(0.1)	(0.1)
Principal Payments for Finance Leases Obligations	(3.7)	(3.5)
Dividends Paid on Common Stock	(71.9)	(65.6)
Other Financing Activities	0.5	0.6
Net Cash Flows from (Used for) Financing Activities	703.1	363.3
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(0.6)	2.9
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	6.8	6.6
Cash and Cash Equivalents at End of Period	6.8
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	78.6	69.7
Net Cash Paid (Received) for Income Taxes	0.3	(6)
Noncash Acquisitions Under Finance Leases	1.4	5.2
Construction Expenditures Included in Current Liabilities as of September 30,	66.5	75.9
Public Service Co Of Oklahoma [Member]
Operating Activities
Net Income (Loss)	136.6	116.4
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	149	129.8
Deferred Income Taxes	109.8	(3.2)
Allowance for Equity Funds Used During Construction	(1.5)	(3.2)
Mark-to-Market of Risk Management Contracts	(8.2)	(0.3)
Property Taxes	(10.9)	(10.6)
Deferred Fuel Over/Under-Recovery, Net	(776.4)	(46.6)
Change in Other Noncurrent Assets	(12.8)	(7.2)
Change in Other Noncurrent Liabilities	4.5	6.1
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(13.4)	(5.6)
Fuel, Materials and Supplies	9.9	(17.2)
Accounts Payable	16.4	(26.1)
Accrued Taxes, Net	9.3	36.9
Other Current Assets	(5.9)	(0.1)
Other Current Liabilities	(18.4)	(16.4)
Net Cash Flows from (Used for) Operating Activities	(412)	152.7
Investing Activities
Construction Expenditures	(219.6)	(256.4)
Change in Advances to Affiliates, Net	(59.5)	38.8
Acquisitions of Assets	297	0
Other Investing Activities	1.9	3.9
Net Cash Flows from (Used for) Investing Activities	(574.2)	(213.7)
Financing Activities
Capital Contributions from Parent	625	0
Issuance of Long-term Debt	1,290	0
Change in Advances from Affiliates, Net	(155.4)	77.8
Retirement of Long-term Debt	(750.4)	(13)
Principal Payments for Finance Leases Obligations	(2.5)	(2.7)
Dividends Paid on Common Stock	(20)	0
Other Financing Activities	0.5	0.4
Net Cash Flows from (Used for) Financing Activities	987.2	62.5
Net Increase (Decrease) in Cash and Cash Equivalents	1	1.5
Cash and Cash Equivalents at Beginning of Period	2.6	1.5
Cash and Cash Equivalents at End of Period	3.6	3
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	42.9	45.5
Net Cash Paid (Received) for Income Taxes	(101.2)	(9.5)
Noncash Acquisitions Under Finance Leases	3.1	3
Construction Expenditures Included in Current Liabilities as of September 30,	44.2	23.5
Southwestern Electric Power Co [Member]
Operating Activities
Net Income (Loss)	210.7	163.9
Adjustments to Reconcile Net Income to Net Cash Flows from (Used for) Operating Activities:
Depreciation and Amortization	217.4	203.9
Deferred Income Taxes	22.5	(0.3)
Allowance for Equity Funds Used During Construction	(5.4)	(5.7)
Mark-to-Market of Risk Management Contracts	(18.1)	(2.3)
Pension Contributions to Qualified Plan Trust	0	(8.9)
Property Taxes	(20)	(16.5)
Deferred Fuel Over/Under-Recovery, Net	(506.8)	16.3
Change in Regulatory Assets	(91.5)	(64.5)
Change in Other Noncurrent Assets	38.3	3.2
Change in Other Noncurrent Liabilities	40	21
Changes in Certain Components of Working Capital:
Accounts Receivable, Net	(70.2)	8
Fuel, Materials and Supplies	115.1	(70.9)
Accounts Payable	(21.1)	88
Accrued Taxes, Net	72.2	46.6
Other Current Assets	4.2	1.3
Other Current Liabilities	(48.2)	(50.3)
Net Cash Flows from (Used for) Operating Activities	(60.9)	332.8
Investing Activities
Construction Expenditures	(277.2)	(319.5)
Acquisitions of Assets	355.8	0
Other Investing Activities	2.1	4.8
Net Cash Flows from (Used for) Investing Activities	(630.9)	(314.7)
Financing Activities
Capital Contributions from Parent	280	0
Issuance of Long-term Debt	496.4	0
Change in Short-term Debt with Original Maturities less than 90 Days, Net	(35)	23.7
Change in Advances from Affiliates, Net	(1.7)	11.9
Retirement of Long-term Debt	(4.7)	(19.7)
Principal Payments for Finance Leases Obligations	(8.1)	(8)
Dividends Paid on Common Stock	(3.8)	(2.3)
Other Financing Activities	0.5	0.3
Net Cash Flows from (Used for) Financing Activities	723.6	5.9
Net Increase (Decrease) in Cash and Cash Equivalents	31.8	24
Cash and Cash Equivalents at Beginning of Period	13.2	1.6
Cash and Cash Equivalents at End of Period	45	25.6
Supplementary Information
Cash Paid for Interest, Net of Capitalized Amounts	98	95.2
Net Cash Paid (Received) for Income Taxes	(11.3)	11.9
Noncash Acquisitions Under Finance Leases	4.4	5.9
Construction Expenditures Included in Current Liabilities as of September 30,	46.8	50.6
Noncontrolling Interest [Member]
Supplementary Information
Noncontrolling Interest Assumed - Dry Lake Solar Project	$ 35	$ 0

Significant Accounting Matters

Significant Accounting Matters	9 Months Ended
	Sep. 30, 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 and nine months ended September 30, 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 (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 September 30, 2021 2020 (in millions, except per share data) $/share $/share Earnings Attributable to AEP Common Shareholders $ 796.0 $ 748.6 Weighted-Average Number of Basic AEP Common Shares Outstanding 501.2 $ 1.59 496.2 $ 1.51 Weighted-Average Dilutive Effect of Stock-Based Awards 1.4 (0.01) 1.3 (0.01) Weighted-Average Number of Diluted AEP Common Shares Outstanding 502.6 $ 1.58 497.5 $ 1.50 Nine Months Ended September 30, 2021 2020 (in millions, except per share data) $/share $/share Earnings Attributable to AEP Common Shareholders $ 1,949.2 $ 1,764.6 Weighted-Average Number of Basic AEP Common Shares Outstanding 499.4 $ 3.90 495.5 $ 3.56 Weighted-Average Dilutive Effect of Stock-Based Awards 1.2 (0.01) 1.4 (0.01) Weighted-Average Number of Diluted AEP Common Shares Outstanding 500.6 $ 3.89 496.9 $ 3.55 Equity Units are potentially dilutive securities but were excluded from the calculation of diluted EPS for the three and nine months ended September 30, 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 377 thousand and 0 antidilutive shares outstanding as of September 30, 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: September 30, 2021 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 1,372.7 $ 0.1 $ 5.0 Restricted Cash 54.0 43.9 10.1 Total Cash, Cash Equivalents and Restricted Cash $ 1,426.7 $ 44.0 $ 15.1 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	9 Months Ended
	Sep. 30, 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	9 Months Ended
	Sep. 30, 2021
Comprehensive Income	COMPREHENSIVE INCOME The disclosures in this note apply to all Registrants except AEPTCo and OPCo 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 September 30, 2021 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2021 $ 110.3 $ (32.2) $ 18.9 $ 97.0 Change in Fair Value Recognized in AOCI 220.8 4.9 (a) — 225.7 Amount of (Gain) Loss Reclassified from AOCI Purchased Electricity for Resale (b) (59.7) — — (59.7) 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 (59.7) 1.5 (2.5) (60.7) Income Tax (Expense) Benefit (12.5) 0.3 (0.5) (12.7) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (47.2) 1.2 (2.0) (48.0) Net Current Period Other Comprehensive Income (Loss) 173.6 6.1 (2.0) 177.7 Balance in AOCI as of September 30, 2021 $ 283.9 $ (26.1) $ 16.9 $ 274.7 Cash Flow Hedges Pension Three Months Ended September 30, 2020 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2020 $ (81.4) $ (55.3) $ (36.2) $ (172.9) Change in Fair Value Recognized in AOCI 10.2 1.9 (a) — 12.1 Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (b) (0.1) — — (0.1) Purchased Electricity for Resale (b) 33.3 — — 33.3 Interest Expense (b) — 1.3 — 1.3 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 33.2 1.3 (2.3) 32.2 Income Tax (Expense) Benefit 7.1 0.2 (0.5) 6.8 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 26.1 1.1 (1.8) 25.4 Net Current Period Other Comprehensive Income (Loss) 36.3 3.0 (1.8) 37.5 Balance in AOCI as of September 30, 2020 $ (45.1) $ (52.3) $ (38.0) $ (135.4) AEP Cash Flow Hedges Pension Nine Months Ended September 30, 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 534.5 17.6 (a) — 552.1 Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (b) 0.7 — — 0.7 Purchased Electricity for Resale (b) (241.2) — — (241.2) Interest Expense (b) — 4.8 — 4.8 Amortization of Prior Service Cost (Credit) — — (14.5) (14.5) Amortization of Actuarial (Gains) Losses — — 6.8 6.8 Reclassifications from AOCI, before Income Tax (Expense) Benefit (240.5) 4.8 (7.7) (243.4) Income Tax (Expense) Benefit (50.5) 1.0 (1.6) (51.1) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (190.0) 3.8 (6.1) (192.3) Net Current Period Other Comprehensive Income (Loss) 344.5 21.4 (6.1) 359.8 Balance in AOCI as of September 30, 2021 $ 283.9 $ (26.1) $ 16.9 $ 274.7 Cash Flow Hedges Pension Nine Months Ended September 30, 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 (48.6) (43.6) (a) — (92.2) Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (b) (0.3) — — (0.3) Purchased Electricity for Resale (b) 135.7 — — 135.7 Interest Expense (b) — 3.6 — 3.6 Amortization of Prior Service Cost (Credit) — — (14.4) (14.4) Amortization of Actuarial (Gains) Losses — — 7.7 7.7 Reclassifications from AOCI, before Income Tax (Expense) Benefit 135.4 3.6 (6.7) 132.3 Income Tax (Expense) Benefit 28.4 0.8 (1.4) 27.8 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 107.0 2.8 (5.3) 104.5 Net Current Period Other Comprehensive Income (Loss) 58.4 (40.8) (5.3) 12.3 Balance in AOCI as of September 30, 2020 $ (45.1) $ (52.3) $ (38.0) $ (135.4) AEP Texas Cash Flow Hedge – Pension Three Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2021 $ (1.8) $ (6.5) $ (8.3) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.4 — 0.4 Amortization of Prior Service Cost (Credit) — (0.1) (0.1) Amortization of Actuarial (Gains) Losses — 0.1 0.1 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 September 30, 2021 $ (1.5) $ (6.5) $ (8.0) Cash Flow Hedge – Pension Three Months Ended September 30, 2020 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2020 $ (2.9) $ (9.3) $ (12.2) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.4 — 0.4 Amortization of Prior Service Cost (Credit) — (0.1) (0.1) Amortization of Actuarial (Gains) Losses — 0.1 0.1 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 September 30, 2020 $ (2.6) $ (9.3) $ (11.9) AEP Texas Cash Flow Hedge – Pension Nine Months Ended September 30, 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 — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.0 — 1.0 Amortization of Prior Service Cost (Credit) — (0.1) (0.1) Amortization of Actuarial (Gains) Losses — 0.2 0.2 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.0 0.1 1.1 Income Tax (Expense) Benefit 0.2 — 0.2 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.8 0.1 0.9 Net Current Period Other Comprehensive Income (Loss) 0.8 0.1 0.9 Balance in AOCI as of September 30, 2021 $ (1.5) $ (6.5) $ (8.0) Cash Flow Hedge – Pension Nine Months Ended September 30, 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) 1.0 — 1.0 Amortization of Prior Service Cost (Credit) — (0.1) (0.1) Amortization of Actuarial (Gains) Losses — 0.2 0.2 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.0 0.1 1.1 Income Tax (Expense) Benefit 0.2 — 0.2 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.8 0.1 0.9 Net Current Period Other Comprehensive Income (Loss) 0.8 0.1 0.9 Balance in AOCI as of September 30, 2020 $ (2.6) $ (9.3) $ (11.9) APCo Cash Flow Hedge – Pension Three Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2021 $ 8.0 $ 5.9 $ 13.9 Change in Fair Value Recognized in AOCI 0.2 — 0.2 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (0.6) — (0.6) Amortization of Prior Service Cost (Credit) — (1.2) (1.2) Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.6) (1.2) (1.8) Income Tax (Expense) Benefit (0.1) (0.2) (0.3) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.5) (1.0) (1.5) Net Current Period Other Comprehensive Income (Loss) (0.3) (1.0) (1.3) Balance in AOCI as of September 30, 2021 $ 7.7 $ 4.9 $ 12.6 Cash Flow Hedge – Pension Three Months Ended September 30, 2020 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2020 $ (4.1) $ 2.2 $ (1.9) Change in Fair Value Recognized in AOCI 0.7 — 0.7 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (0.2) — (0.2) 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 (0.2) (1.2) (1.4) Income Tax (Expense) Benefit (0.1) (0.3) (0.4) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.1) (0.9) (1.0) Net Current Period Other Comprehensive Income (Loss) 0.6 (0.9) (0.3) Balance in AOCI as of September 30, 2020 $ (3.5) $ 1.3 $ (2.2) APCo Cash Flow Hedge – Pension Nine Months Ended September 30, 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) (1.0) — (1.0) Amortization of Prior Service Cost (Credit) — (3.9) (3.9) Reclassifications from AOCI, before Income Tax (Expense) Benefit (1.0) (3.9) (4.9) Income Tax (Expense) Benefit (0.2) (0.8) (1.0) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.8) (3.1) (3.9) Net Current Period Other Comprehensive Income (Loss) 8.5 (3.1) 5.4 Balance in AOCI as of September 30, 2021 $ 7.7 $ 4.9 $ 12.6 Cash Flow Hedge – Pension Nine Months Ended September 30, 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 (3.8) — (3.8) Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (0.8) — (0.8) Amortization of Prior Service Cost (Credit) — (4.0) (4.0) Amortization of Actuarial (Gains) Losses — 0.4 0.4 Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.8) (3.6) (4.4) Income Tax (Expense) Benefit (0.2) (0.8) (1.0) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.6) (2.8) (3.4) Net Current Period Other Comprehensive Income (Loss) (4.4) (2.8) (7.2) Balance in AOCI as of September 30, 2020 $ (3.5) $ 1.3 $ (2.2) I&M Cash Flow Hedge – Pension Three Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2021 $ (7.4) $ 1.2 $ (6.2) 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 September 30, 2021 $ (7.0) $ 1.2 $ (5.8) Cash Flow Hedge – Pension Three Months Ended September 30, 2020 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2020 $ (9.1) $ (1.7) $ (10.8) 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) — (0.3) (0.3) Amortization of Actuarial (Gains) Losses — 0.2 0.2 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.5 (0.1) 0.4 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.4 (0.1) 0.3 Net Current Period Other Comprehensive Income (Loss) 0.4 (0.1) 0.3 Balance in AOCI as of September 30, 2020 $ (8.7) $ (1.8) $ (10.5) I&M Cash Flow Hedge – Pension Nine Months Ended September 30, 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) 1.6 — 1.6 Amortization of Prior Service Cost (Credit) — (0.6) (0.6) Amortization of Actuarial (Gains) Losses — 0.5 0.5 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.6 (0.1) 1.5 Income Tax (Expense) Benefit 0.3 — 0.3 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.3 (0.1) 1.2 Net Current Period Other Comprehensive Income (Loss) 1.3 (0.1) 1.2 Balance in AOCI as of September 30, 2021 $ (7.0) $ 1.2 $ (5.8) Cash Flow Hedge – Pension Nine Months Ended September 30, 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) 1.5 — 1.5 Amortization of Prior Service Cost (Credit) — (0.6) (0.6) Amortization of Actuarial (Gains) Losses — 0.5 0.5 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.5 (0.1) 1.4 Income Tax (Expense) Benefit 0.3 — 0.3 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.2 (0.1) 1.1 Net Current Period Other Comprehensive Income (Loss) 1.2 (0.1) 1.1 Balance in AOCI as of September 30, 2020 $ (8.7) $ (1.8) $ (10.5) PSO Cash Flow Hedge – Three Months Ended September 30, 2021 Interest Rate (in millions) Balance in AOCI as of June 30, 2021 $ — 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 September 30, 2021 $ — Cash Flow Hedge – Three Months Ended September 30, 2020 Interest Rate (in millions) Balance in AOCI as of June 30, 2020 $ 0.6 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 — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.3) Net Current Period Other Comprehensive Income (Loss) (0.3) Balance in AOCI as of September 30, 2020 $ 0.3 Cash Flow Hedge – Nine Months Ended September 30, 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 September 30, 2021 $ — Cash Flow Hedge – Nine Months Ended September 30, 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) (1.0) Reclassifications from AOCI, before Income Tax (Expense) Benefit (1.0) Income Tax (Expense) Benefit (0.2) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.8) Net Current Period Other Comprehensive Income (Loss) (0.8) Balance in AOCI as of September 30, 2020 $ 0.3 SWEPCo Cash Flow Hedge – Pension Three Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2021 $ 0.5 $ 1.4 $ 1.9 Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.4 — 0.4 Amortization of Prior Service Cost (Credit) — (0.5) (0.5) Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.4 (0.5) (0.1) Income Tax (Expense) Benefit 0.1 (0.1) — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.3 (0.4) (0.1) Net Current Period Other Comprehensive Income (Loss) 0.3 (0.4) (0.1) Balance in AOCI as of September 30, 2021 $ 0.8 $ 1.0 $ 1.8 Cash Flow Hedge – Pension Three Months Ended September 30, 2020 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2020 $ (1.1) $ (0.2) $ (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) Amortization of Actuarial (Gains) Losses — — — 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 September 30, 2020 $ (0.7) $ (0.6) $ (1.3) SWEPCo Cash Flow Hedge – Pension Nine Months Ended September 30, 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) 1.4 — 1.4 Amortization of Prior Service Cost (Credit) — (1.5) (1.5) Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.4 (1.5) (0.1) Income Tax (Expense) Benefit 0.3 (0.3) — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.1 (1.2) (0.1) Net Current Period Other Comprehensive Income (Loss) 1.1 (1.2) (0.1) Balance in AOCI as of September 30, 2021 $ 0.8 $ 1.0 $ 1.8 Cash Flow Hedge – Pension Nine Months Ended September 30, 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) 1.4 — 1.4 Amortization of Prior Service Cost (Credit) — (1.5) (1.5) Amortization of Actuarial (Gains) Losses — 0.1 0.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.4 (1.4) — Income Tax (Expense) Benefit 0.3 (0.3) — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.1 (1.1) — Net Current Period Other Comprehensive Income (Loss) 1.1 (1.1) — Balance in AOCI as of September 30, 2020 $ (0.7) $ (0.6) $ (1.3) (a) The change in fair value includes $(1) million and $(1) million, respectively, for the three months ended September 30, 2021 and 2020 and $(5) million and $6 million, respectively, for the nine months ended September 30, 2021 and 2020 related to AEP's investment in joint venture wind farms acquired as part of the purchase of Sempra Renewables LLC. (b) Amounts reclassified to the referenced line item on the statements of income.

Rate Matters

Rate Matters	9 Months Ended
	Sep. 30, 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 The Oklaunion Power Station was retired in September 2020 and sold to a nonaffiliated third-party in October 2020. As of September 30, 2021, PSO has a regulatory asset for accelerated depreciation pending approval recorded on its balance sheet of $33 million. PSO has requested recovery of the Oklaunion Power Station as part of its 2021 Oklahoma base rate case. See “2021 Oklahoma Base Rate Case” section below for additional information. 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 below 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. See “2020 Louisiana Base Rate Case” section below for additional information. As of September 30, 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. 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. PSO has requested recovery of Northeastern Plant, Unit 3 as part of its 2021 Oklahoma base rate case. See “2021 Oklahoma Base Rate Case” section below for additional information. 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 September 30, 2021, of generating facilities planned for early retirement: Plant Net Book Value Accelerated Depreciation Regulatory Asset Cost of Removal Projected Current Authorized Annual (dollars in millions) Northeastern Plant, Unit 3 $ 175.1 $ 123.6 $ 20.0 (b) 2026 (c) $ 14.9 Dolet Hills Power Station 13.0 126.8 24.4 2021 (d) 7.8 Pirkey Power Plant 135.4 68.0 39.2 2023 (e) 13.5 Welsh Plant, Units 1 and 3 493.7 35.6 58.2 (f) 2028 (g) 33.1 (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) DHLC provides 100% of the fuel supply to Dolet Hills Power Station. During the second quarter of 2019, the Dolet Hills Power Station initiated a seasonal operating schedule. In 2020, 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 ceased in October 2021. In addition, 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 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 non-fuel costs are recoverable by SWEPCo through base rates. As of September 30, 2021, SWEPCo’s share of the net investment in the Dolet Hills Power Station is $146 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 $44 million as of September 30, 2021. Also, as of September 30, 2021, SWEPCo had a net under-recovered fuel balance of $39 million, excluding impacts of the February 2021 severe winter weather event, which includes fuel consumed at the Dolet Hills Power Station. Additional operational, reclamation and other land-related costs incurred by DHLC and Oxbow will be billed to SWEPCo and included in future 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 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 2020, management announced plans to retire the Pirkey Power Plant in 2023. The Pirkey Power Plant non-fuel costs are recoverable by SWEPCo through base rates and fuel costs are recovered through active fuel clauses. As of September 30, 2021, SWEPCo’s share of the net investment in the Pirkey Power Plant is $203 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 $108 million as of September 30, 2021. Also, as of September 30, 2021, SWEPCo had a net under-recovered fuel balance of $39 million, excluding impacts of the February 2021 severe winter weather event, which includes fuel consumed at the Pirkey Power Plant. Additional operational, reclamation and other land-related costs incurred by Sabine will be billed to SWEPCo and included in future 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 a $10 million reduction in recoverable fuel costs for the reconciliation period, which was recognized in SWEPCo’s 2020 financial statements. In June 2021, the settlement was filed and is currently awaiting approval from the PUCT. 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 September 30, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Unrecovered Winter Storm Fuel Costs (a) $ 1,106.3 $ — Dolet Hills Power Station Accelerated Depreciation 126.8 71.2 Pirkey Power Plant Accelerated Depreciation 68.0 12.2 Kentucky Deferred Purchase Power Expenses 45.9 41.3 Welsh Plant, Units 1 and 3 Accelerated Depreciation 35.6 3.6 Plant Retirement Costs – Unrecovered Plant, Louisiana 35.2 35.2 Oklaunion Power Station Accelerated Depreciation 33.0 34.4 Dolet Hills Power Station Fuel Costs - Louisiana 20.3 — Other Regulatory Assets Pending Final Regulatory Approval 25.5 22.8 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 325.8 134.2 Plant Retirement Costs – Asset Retirement Obligation Costs 25.9 25.9 COVID-19 14.0 24.9 Asset Retirement Obligation - Louisiana 10.0 9.1 Other Regulatory Assets Pending Final Regulatory Approval 32.6 27.4 Total Regulatory Assets Pending Final Regulatory Approval $ 1,904.9 $ 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 September 30, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Advanced Metering System $ 16.6 $ 16.3 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 22.7 0.8 Vegetation Management Program 5.2 3.8 Texas Retail Electric Provider Bad Debt Expense 4.1 — COVID-19 3.9 10.5 Other Regulatory Assets Pending Final Regulatory Approval 5.3 1.5 Total Regulatory Assets Pending Final Regulatory Approval $ 57.8 $ 32.9 APCo September 30, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return COVID-19 – Virginia $ 6.6 $ 3.7 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 59.8 3.4 Plant Retirement Costs – Asset Retirement Obligation Costs 25.9 25.9 COVID-19 – West Virginia 0.4 1.5 Environmental Expense Deferral - Virginia — 9.3 Other Regulatory Assets Pending Final Regulatory Approval 1.2 — Total Regulatory Assets Pending Final Regulatory Approval $ 93.9 $ 43.8 I&M September 30, 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 1.7 3.8 Other Regulatory Assets Pending Final Regulatory Approval 1.7 — Total Regulatory Assets Pending Final Regulatory Approval $ 3.4 $ 4.3 OPCo September 30, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Not Earning a Return Storm-Related Costs $ 5.5 $ 4.0 COVID-19 1.9 4.4 Other Regulatory Assets Pending Final Regulatory Approval 0.1 — Total Regulatory Assets Pending Final Regulatory Approval $ 7.5 $ 8.4 PSO September 30, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Unrecovered Winter Storm Fuel Costs (a) $ 673.2 $ — Oklaunion Power Station Accelerated Depreciation 33.0 34.4 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 29.3 15.8 Other Regulatory Assets Pending Final Regulatory Approval 0.9 0.3 Total Regulatory Assets Pending Final Regulatory Approval $ 736.4 $ 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 September 30, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Unrecovered Winter Storm Fuel Costs (a) $ 433.1 $ — Dolet Hills Power Station Accelerated Depreciation 126.8 71.2 Pirkey Power Plant Accelerated Depreciation 68.0 12.2 Welsh Plant, Units 1 and 3 Accelerated Depreciation 35.6 3.6 Plant Retirement Costs – Unrecovered Plant, Louisiana 35.2 35.2 Dolet Hills Power Station Fuel Costs- Louisiana 20.3 — Other Regulatory Assets Pending Final Regulatory Approval 2.3 2.2 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 155.4 99.3 Asset Retirement Obligation - Louisiana 10.0 9.1 Other Regulatory Assets Pending Final Regulatory Approval 19.3 14.5 Total Regulatory Assets Pending Final Regulatory Approval $ 906.0 $ 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 storm restoration costs are as follows: September 30, 2021 Company Jurisdiction Capital O&M Regulatory Asset Total (in millions) APCo Virginia $ 8.1 $ 2.2 $ 6.6 $ 16.9 APCo West Virginia 23.5 — 47.0 70.5 SWEPCo Louisiana 6.0 — 45.4 51.4 KPCo Kentucky 29.0 5.0 42.6 76.6 Total $ 66.6 $ 7.2 $ 141.6 $ 215.4 The amounts in the table above represents costs as of September 30, 2021. 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. KPCo intends to seek recovery of these incremental storm restoration costs in their next base rate case while APCo is expected to seek recovery in separate filings. In October 2021, SWEPCo requested recovery of these storm costs, in addition to storm costs from Hurricanes Delta and Laura, in a filing with the LPSC. As part of the filing, SWEPCo requested recovery of the carrying charges on the regulatory asset at a weighted average cost of capital through a rider beginning in January 2022. 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 natural gas expenses and purchases of electricity still to be recovered from customers are as follows: PSO SWEPCo Total (in millions) Retail Customers (a) $ 673.2 $ 433.1 (b) $ 1,106.3 Wholesale Customers — 55.8 55.8 Total $ 673.2 $ 488.9 $ 1,162.1 (a) These costs were deferred as regulatory assets as of September 30, 2021. (b) SWEPCo’s balance consists of $107 million, $151 million and $175 million related to the Arkansas, Louisiana and Texas jurisdictions, respectively. 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. SWEPCo is recovering these fuel costs at an interim carrying charge of 0.8%. Also in April 2021, SWEPCo filed testimony supporting a five-year recovery with a carrying charge of 6.05% which has been supported by APSC staff. Various other parties have recommended recovery periods ranging from 5-20 years with a carrying charge of 1.65%. The APSC ordered more testimony regarding the option of utilizing securitization to recover the fuel costs. SWEPCo is awaiting a decision from the APSC. The prudency of these fuel costs is expected to be addressed in a separate proceeding. 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 these retail fuel costs over a longer period than what the FAC traditionally allows. In April 2021, SWEPCo began recovery of its Louisiana jurisdictional share of these fuel costs based on a five year recovery period. SWEPCo is recovering these fuel costs at an interim carrying charge of 3.25%. 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 a carrying charge at an interim rate of 0.75%, over a longer time period than what the FAC traditionally allows. Also in April 2021, legislation was enacted in Oklahoma to permit securitization of the extraordinary fuel and purchase of electricity costs impacting the utilities within the state. Under the legislation, the OCC has the authority to determine, after receiving an application from a rate-regulated utility, if the extraordinary fuel and purchase of electricity costs incurred in February 2021 may be mitigated through securitization to reduce the impact on customer bills. PSO has filed an application for a financing order to pursue securitization. The application requests an order on the prudency of the extraordinary fuel and purchase of electricity costs and a carrying charge of the commission authorized weighted average cost of capital until securitization bonds can be issued. In October 2021, OCC staff and intervenors filed testimony supporting securitization of these costs and a carrying charge until costs are securitized ranging from the interim rate of 0.75% to the actual cost of capital used to finance the costs of 2.32%. In addition, OCC staff supported the prudency of PSO's requested costs while one intervenor recommended disallowances of up to $40 million. A procedural schedule has been set with an ALJ report to be filed in January 2022. An order from the OCC is expected in the first quarter of 2022. In August 2021, SWEPCo filed an application with the PUCT to implement a net interim fuel surcharge for the Texas jurisdictional share of these retail fuel costs. The application supported a five-year recovery at a carrying charge of 7.18%. In October 2021, various intervenors filed testimony supporting a five-year recovery with a carrying charge ranging from 0.082% to 1.625%. A hearing with the PUCT is scheduled for November 2021. Wholesale Customers During the first quarter of 2021, SWEPCo billed wholesale customers $104 million resulting from the severe winter weather events. SWEPCo worked with wholesale customers to establish payment terms for the outstanding accounts receivable. As of September 30, 2021, $56 million of accounts receivable from wholesale customers are outstanding. 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 and nine months ended September 30, 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. 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 September 30, 2021, AEP’s electric operating companies have resumed customary disconnection practices in all regulated jurisdictions with the exception of residential customers in Virginia. AEP continues to work with regulators and stakeholders in Virginia and management currently anticipates resuming customary disconnection practices once available relief funds are received from the state. 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 September 30, 2021, AEP Texas’ cumulative revenues from interim base rate increases that are subject to review is approximately $229 million. A base rate review could result in a refund to customers if AEP Texas incurs a disallowance of the transmission or distribution investment on which an interim increase was based. Management is unable to determine a range of potential losses, if any, that are reasonably possible of occurring. A revenue decrease, including a refund of interim transmission and distribution rates, could reduce future net income and cash flows and impact financial condition. AEP Texas is required to file for a comprehensive rate review no later than April 5, 2024. APCo and WPCo Rate Matters (Applies to AEP and APCo) 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. In September 2021, APCo submitted its brief before the Virginia Supreme Court. The brief was in alignment with the assignments of error filed by APCo in March 2021. In October 2021, the Virginia SCC and certain intervenors filed briefs with the Virginia Supreme Court disagreeing with APCo’s assignments of error in its appeal of the Triennial Review decision. Additionally, the Virginia SCC and APCo filed briefs disagreeing with an intervenor’ s assignments of error in a separate appeal of the same decision. 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. The initial negative impact for the write-off of closed coal-fired plant asset balances would potentially be partially offset by an increase in base rates for earning below APCo’s 2017-2019 authorized ROE band. CCR/ELG Compliance Plan Filings In December 2020, APCo submitted filings with the Virginia SCC and WVPSC requesting approvals necessary to implement CCR/ELG compliance plans at the Amos and Mountaineer Plants. Intervenors in Virginia and West Virginia recommended that only the CCR-related investments be constructed at Amos and Mountaineer and, as a consequence, that APCo close these generating facilities at the end of 2028. In August 2021, the Virginia SCC issued an order approving APCo’s request to construct CCR-related investments at the Amos and Mountaineer Plants and approved recovery of CCR-related other operation and maintenance expenses and investments through an active rider. The order denie

Commitments, Guarantees and Con

Commitments, Guarantees and Contingencies	9 Months Ended
	Sep. 30, 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 September 30, 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 five uncommitted facilities totaling $375 million. The Registrants’ maximum future payments for letters of credit issued under the uncommitted facilities as of September 30, 2021 were as follows: Company Amount Maturity (in millions) AEP $ 179.5 October 2021 to August 2022 AEP Texas 2.2 July 2022 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 September 30, 2021, the maximum potential amount of future payments associated with these guarantees was $148 million, with the last guarantee expiring in December 2037. The non-contingent liability recorded associated with these guarantees was $29 million, with an additional $2 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 September 30, 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 September 30, 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 $ 47.8 AEP Texas 11.1 APCo 6.2 I&M 4.1 OPCo 7.6 PSO 4.7 SWEPCo 5.2 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 September 30, 2021 were as follows: Future Minimum Lease Payments AEP (a) I&M (in millions) 2021 $ 74.0 $ 37.0 2022 147.6 73.8 Total Future Minimum Lease Payments $ 221.6 $ 110.8 (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 September 30, 2021, the maximum potential amount of future payments required under the guaranteed leases was $43 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 September 30, 2021, AEP’s boat and barge lease guarantee liability was $2 million, of which $1 million was recorded in Other Current Liabilities and $1 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 suit 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 sought a judgment declaring that the defendants breached the lease, must satisfy obligations related to installation of emission control equipment and indemnify the plaintiffs. After the litigation proceeded at the District Court and Circuit Court levels, 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. 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. As a result, in May 2021, at the parties’ request, the district court entered a stipulation and order dismissing the case without prejudice to plaintiffs asserting their claims in a re-filed action or a new action. Management believes its financial statements appropriately reflect the resolution of the 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 2019, Ohio adopted and implemented HB 6 which benefits OPCo by authorizing rate recovery for certain costs including renewable energy contracts and OVEC’s coal-fired generating units. OPCo engaged in lobbying efforts and provided testimony during the legislative process in connection with HB 6. In July 2020, an investigation led by the U.S. Attorney’s Office resulted in a federal grand jury indictment of an Ohio legislator and associates in connection with an alleged racketeering conspiracy involving the adoption of HB 6. After AEP learned of the criminal allegations against the Ohio legislator and others relating to HB 6, the Company, with assistance from outside advisors, conducted a review of the circumstances surrounding the passage of the bill. We do not believe that AEP was involved in any wrongful conduct in connection with the passage of HB 6. In August 2020, an AEP shareholder filed a putative class action lawsuit in the 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. On May 10, 2021, the defendants filed a motion to dismiss the securities litigation for failure to state a claim and the motion was fully briefed as of July 26, 2021. The Court has scheduled oral argument for November 23, 2021 on the motion to dismiss. 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 and a fourth AEP shareholder filed a similar derivative action in the Supreme Court for the State of New York, Nassau County. These derivative complaints allege the officers and directors made misrepresentations and omissions similar to those alleged in the putative securities class action lawsuit filed against AEP. The derivative complaints together assert claims for: (a) breach of fiduciary duty, (b) waste of corporate assets, (c) unjust enrichment, (d) breach of duty for insider trading and (e) contribution for violations of sections 10(b) and 21D of the Securities Exchange Act of 1934; and seek monetary damages and changes to AEP’s corporate governance and internal policies among other forms of relief. The first three derivative actions have been stayed pending the resolution of the motion to dismiss the securities litigation. The fourth has been stayed until such time as the court determines to lift the stay. 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 shareholder that sent the letter has agreed that AEP and the AEP Board may defer consideration of the litigation demand until the resolution of the motion to dismiss the securities litigation. The AEP Board will act in response to the letter as appropriate. Management is unable to determine a range of potential losses that is reasonably possible of occurring. In May 2021, AEP received a subpoena from the SEC’s Division of Enforcement seeking various documents, including documents relating to the benefits to AEP from the passage of HB 6 and documents relating to AEP’s financial processes and controls. AEP is cooperating fully with the SEC’s subpoena. Although the outcome of the SEC’s investigation cannot be predicted, management does not believe the results of this inquiry will have a material impact on our financial condition, results of operations, or cash flows.

Acquisitions and Dispositions

Acquisitions and Dispositions	9 Months Ended
	Sep. 30, 2021
Acquisitions and Dispositions	ACQUISITIONS AND DISPOSITIONS The disclosures in this note apply to AEP unless indicated otherwise. ACQUISITIONS Dry Lake Solar Project (Generation & Marketing Segment) In November 2020, AEP signed a Purchase and Sale Agreement with a nonaffiliate to acquire a 75% interest in the 100 MW Dry Lake Solar Project (Dry Lake) located in southern Nevada for approximately $114 million. In March 2021, AEP closed the transaction and the solar project was placed in-service in May 2021. Approximately $103 million of the purchase price was paid upon closing of the transaction and the remaining $11 million was paid when the project was placed in-service. In accordance with the accounting guidance for “Business Combinations,” management determined that the acquisition of Dry Lake represents an asset acquisition. Additionally, and in accordance with the accounting guidance for “Consolidation,” management concluded that Dry Lake is a VIE and that AEP is the primary beneficiary based on its power as managing member to direct the activities that most significantly impact Dry Lake’s economic performance. As the primary beneficiary of Dry Lake, AEP consolidates Dry Lake into its financial statements. As a result, to account for the initial consolidation of Dry Lake, management applied the acquisition method by allocating the purchase price based on the relative fair value of the assets acquired and noncontrolling interest assumed. The fair value of the primary assets acquired and the noncontrolling interest assumed was determined using the market approach. The key input assumptions were the transaction price paid for AEP’s interest in Dry Lake and recent third-party market transactions for similar solar generation facilities. The nonaffiliated interest in Dry Lake is presented in Noncontrolling Interests on the balance sheets. Subsequent to close of the transaction, the noncontrolling interest made additional asset contributions of $16 million. As of September 30, 2021, AEP recognized approximately $146 million of Property, Plant and Equipment and approximately $35 million of Noncontrolling Interest on the balance sheets. North Central Wind Energy Facilities (Vertically Integrated Utilities Segment) (Applies to AEP, PSO and SWEPCo) In 2020, PSO and SWEPCo received regulatory approvals to acquire the NCWF, comprised of three Oklahoma wind facilities totaling 1,485 MWs, on a fixed cost turn-key basis at completion. PSO and SWEPCo will own undivided interests of 45.5% and 54.5% of the NCWF, respectively. In total, the three wind facilities will cost approximately $2 billion and consist of Traverse (999 MW), Maverick (287 MW) and Sundance (199 MW). Output from the NCWF will serve retail load in PSO’s Oklahoma service territory and both retail and FERC wholesale load in SWEPCo’s service territories in Arkansas and Louisiana. The Oklahoma and Louisiana portions of the NCWF revenue requirement, net of PTC benefit, are recoverable through authorized riders beginning at commercial operation and until such time as amounts are reflected in base rates. Recovery of the Arkansas portion of the NCWF revenue requirement is requested in SWEPCo’s pending 2021 Arkansas Base Rate Case. The NCWF are subject to various regulatory performance requirements. If these performance requirements are not met, PSO and SWEPCo would recognize a regulatory liability to refund retail customers. In April 2021, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Sundance during its development and construction for $270 million, the first of the three NCWF acquisitions. Immediately following the acquisition, PSO and SWEPCo liquidated the entity and simultaneously distributed the Sundance assets in proportion to their undivided ownership interests. Sundance was placed in-service in April 2021. In September 2021, PSO and SWEPCo acquired respective undivided ownership interests in the entity that owned Maverick during its development and construction for $383 million, the second of the three NCWF acquisitions. Immediately following the acquisition, PSO and SWEPCo liquidated the entity and simultaneously distributed the Maverick assets in proportion to their undivided ownership interests. Maverick was placed in-service in September 2021. In accordance with the guidance for “Business Combinations,” management determined that the acquisitions of Sundance and Maverick represent asset acquisitions. As of September 30, 2021, PSO and SWEPCo had approximately $314 million and $376 million, of Property, Plant and Equipment on the balance sheets, respectively, related to the Sundance and Maverick NCWF projects. On an ongoing basis, management further determined that PSO and SWEPCo should apply the joint plant accounting model to account for their respective undivided interests in the assets, liabilities, revenues and expenses of Sundance and Maverick. The Purchase and Sale Agreement (PSA) includes collective interests in numerous land contracts, as originally executed between the nonaffiliated party and the respective owners of the properties as defined in the contracts. These contracts provide for easement and access rights to the land that Sundance and Maverick were built upon. These interests as lessee in each of the land contracts were transferred to Sundance and Maverick (and subsequently to PSO and SWEPCo) as a part of the closing of the PSA. As of September 30, 2021, the Noncurrent Obligations Under Operating Leases for Sundance are $13 million and $15 million on the balance sheets for PSO and SWEPCo, respectively, and the Noncurrent Obligations Under Operating Leases for Maverick are $18 million and $22 million on the balance sheets for PSO and SWEPCo, respectively. Desert Sky Wind Farm and Trent Wind Farm (Generation & Marketing Segment) In August 2020, AEP exercised its call right which required the nonaffiliated member of Desert Sky Wind Farm LLC and Trent Wind Farm LLC (collectively the LLCs) to sell its noncontrolling interest to AEP. The exercise price for the call right was determined using a discounted cash flow model with agreed input assumptions as well as updates to certain assumptions reasonably expected based on the actual results of the LLCs. As a result, the LLCs are wholly-owned by AEP and management has concluded that the LLCs are no longer VIEs. AEP paid $57 million in cash, derecognized $63 million of Redeemable Noncontrolling Interest within Mezzanine Equity and recorded an increase of $6 million of Paid-In Capital on the balance sheets. DISPOSITIONS Conesville Plant (Generation & Marketing Segment) In June 2020, AEP and a nonaffiliated joint-owner executed an Environmental Liability and Property Transfer and Asset Purchase Agreement with a nonaffiliated third-party related to the merchant Conesville Plant site. The purchaser took ownership of the assets and assumed responsibility for environmental liabilities, including ash pond closure, asbestos abatement and decommissioning and demolition of the Conesville Plant site. In consideration of the transfer of the acquired assets to the purchaser and the purchaser’s assumption of liabilities, AEP will pay a total of approximately $98 million over three years, derecognized $106 million in ARO and recorded an immaterial gain on the transaction which is recorded in Other Operation on the statements of income. AEP paid approximately $26 million at closing in June 2020 and made additional payments totaling $38 million in quarterly installments from October 2020 to July 2021. AEP will make additional payments totaling $34 million in quarterly installments from October 2021 to July 2022.

Benefit Plans

Benefit Plans	9 Months Ended
	Sep. 30, 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 September 30, Three Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 32.3 $ 28.0 $ 2.4 $ 2.5 Interest Cost 34.3 42.0 7.7 10.0 Expected Return on Plan Assets (57.4) (66.3) (22.8) (23.9) Amortization of Prior Service Credit — — (17.8) (17.4) Amortization of Net Actuarial Loss 25.3 23.5 — 1.4 Net Periodic Benefit Cost (Credit) $ 34.5 $ 27.2 $ (30.5) $ (27.4) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 96.9 $ 84.0 $ 7.2 $ 7.5 Interest Cost 102.9 125.9 22.9 29.9 Expected Return on Plan Assets (172.3) (198.7) (68.4) (71.8) Amortization of Prior Service Credit — — (53.2) (52.3) Amortization of Net Actuarial Loss 76.1 70.3 — 4.4 Net Periodic Benefit Cost (Credit) $ 103.6 $ 81.5 $ (91.5) $ (82.3) AEP Texas Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 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) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 8.9 $ 7.6 $ 0.5 $ 0.6 Interest Cost 8.4 10.5 1.8 2.4 Expected Return on Plan Assets (14.6) (17.1) (5.6) (6.0) Amortization of Prior Service Credit — — (4.5) (4.4) Amortization of Net Actuarial Loss 6.2 5.8 — 0.4 Net Periodic Benefit Cost (Credit) $ 8.9 $ 6.8 $ (7.8) $ (7.0) APCo Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 3.0 $ 2.7 $ 0.3 $ 0.3 Interest Cost 4.1 5.0 1.3 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 $ (4.4) $ (4.0) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 8.9 $ 7.9 $ 0.8 $ 0.8 Interest Cost 12.3 15.2 3.7 4.9 Expected Return on Plan Assets (21.8) (25.2) (10.1) (10.9) Amortization of Prior Service Credit — — (7.8) (7.6) Amortization of Net Actuarial Loss 9.0 8.4 — 0.7 Net Periodic Benefit Cost (Credit) $ 8.4 $ 6.3 $ (13.4) $ (12.1) I&M Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 4.4 $ 3.9 $ 0.4 $ 0.4 Interest Cost 4.0 4.9 0.8 1.2 Expected Return on Plan Assets (7.2) (8.3) (2.7) (3.0) Amortization of Prior Service Credit — — (2.5) (2.3) Amortization of Net Actuarial Loss 2.9 2.7 — 0.1 Net Periodic Benefit Cost (Credit) $ 4.1 $ 3.2 $ (4.0) $ (3.6) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 13.1 $ 11.6 $ 1.0 $ 1.1 Interest Cost 12.1 14.7 2.6 3.5 Expected Return on Plan Assets (21.6) (24.9) (8.3) (8.8) Amortization of Prior Service Credit — — (7.3) (7.1) Amortization of Net Actuarial Loss 8.8 8.1 — 0.5 Net Periodic Benefit Cost (Credit) $ 12.4 $ 9.5 $ (12.0) $ (10.8) OPCo Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 2.9 $ 2.4 $ 0.2 $ 0.2 Interest Cost 3.1 3.9 0.7 1.0 Expected Return on Plan Assets (5.7) (6.6) (2.4) (2.6) Amortization of Prior Service Credit — — (1.7) (1.8) Amortization of Net Actuarial Loss 2.3 2.1 — 0.2 Net Periodic Benefit Cost (Credit) $ 2.6 $ 1.8 $ (3.2) $ (3.0) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 8.6 $ 7.2 $ 0.6 $ 0.7 Interest Cost 9.3 11.6 2.3 3.1 Expected Return on Plan Assets (16.8) (19.7) (7.3) (7.9) Amortization of Prior Service Credit — — (5.3) (5.3) Amortization of Net Actuarial Loss 6.8 6.4 — 0.5 Net Periodic Benefit Cost (Credit) $ 7.9 $ 5.5 $ (9.7) $ (8.9) PSO Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 2.0 $ 1.9 $ 0.1 $ 0.1 Interest Cost 1.7 2.1 0.4 0.6 Expected Return on Plan Assets (3.0) (3.6) (1.3) (1.3) Amortization of Prior Service Credit — — (1.1) (1.0) Amortization of Net Actuarial Loss 1.2 1.1 — — Net Periodic Benefit Cost (Credit) $ 1.9 $ 1.5 $ (1.9) $ (1.6) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 6.0 $ 5.5 $ 0.4 $ 0.4 Interest Cost 5.0 6.4 1.2 1.6 Expected Return on Plan Assets (9.2) (10.9) (3.8) (3.9) Amortization of Prior Service Credit — — (3.3) (3.2) Amortization of Net Actuarial Loss 3.7 3.5 — 0.2 Net Periodic Benefit Cost (Credit) $ 5.5 $ 4.5 $ (5.5) $ (4.9) SWEPCo Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 2.7 $ 2.6 $ 0.3 $ 0.2 Interest Cost 2.2 2.5 0.4 0.6 Expected Return on Plan Assets (3.3) (3.9) (1.5) (1.5) Amortization of Prior Service Credit — — (1.4) (1.3) Amortization of Net Actuarial Loss 1.5 1.4 — 0.1 Net Periodic Benefit Cost (Credit) $ 3.1 $ 2.6 $ (2.2) $ (1.9) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 8.4 $ 7.5 $ 0.6 $ 0.6 Interest Cost 6.4 7.6 1.4 1.9 Expected Return on Plan Assets (10.1) (11.7) (4.5) (4.7) Amortization of Prior Service Credit — — (4.0) (3.9) Amortization of Net Actuarial Loss 4.6 4.2 — 0.3 Net Periodic Benefit Cost (Credit) $ 9.3 $ 7.6 $ (6.5) $ (5.8) Qualified Pension Contribution (Applies to all Registrants except AEPTCo and PSO) For the qualified pension plan, discretionary contributions may be made to maintain the funded status of the plan. In the third quarter of 2020, AEP made a discretionary contribution to the qualified pension plan. The following table provides details of the contribution by Registrant: Company Qualified Pension Plan (in millions) AEP $ 110.3 AEP Texas 11.3 APCo 7.0 I&M 6.4 OPCo 0.1 SWEPCo 8.9

Business Segments

Business Segments	9 Months Ended
	Sep. 30, 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 represent AEP’s reportable segment income statement information for the three and nine months ended September 30, 2021 and 2020 and reportable segment balance sheet information as of September 30, 2021 and December 31, 2020. Three Months Ended September 30, 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 $ 2,716.8 $ 1,195.0 $ 90.3 $ 617.4 $ 3.5 $ — $ 4,623.0 Other Operating Segments 42.5 5.3 301.3 3.7 23.2 (376.0) — Total Revenues $ 2,759.3 $ 1,200.3 $ 391.6 $ 621.1 $ 26.7 $ (376.0) $ 4,623.0 Net Income (Loss) $ 438.7 $ 155.9 $ 167.9 $ 99.5 $ (65.1) $ — $ 796.9 Three Months Ended September 30, 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 $ 2,400.1 $ 1,124.1 $ 73.4 $ 464.8 $ 4.0 $ — $ 4,066.4 Other Operating Segments 34.7 41.2 244.5 25.2 28.6 (374.2) — Total Revenues $ 2,434.8 $ 1,165.3 $ 317.9 $ 490.0 $ 32.6 $ (374.2) $ 4,066.4 Net Income (Loss) $ 394.2 $ 147.4 $ 139.3 $ 114.6 $ (47.3) $ — $ 748.2 Nine Months Ended September 30, 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 $ 7,445.9 $ 3,366.9 $ 264.6 $ 1,641.6 $ 11.6 $ — $ 12,730.6 Other Operating Segments 111.3 24.9 882.2 50.3 43.5 (1,112.2) — Total Revenues $ 7,557.2 $ 3,391.8 $ 1,146.8 $ 1,691.9 $ 55.1 $ (1,112.2) $ 12,730.6 Net Income (Loss) $ 938.9 $ 424.0 $ 510.7 $ 184.2 $ (108.3) $ — $ 1,949.5 Nine Months Ended September 30, 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 $ 6,655.4 $ 3,208.7 $ 215.7 $ 1,223.4 $ 4.7 $ — $ 11,307.9 Other Operating Segments 98.1 98.0 662.1 82.1 67.3 (1,007.6) — Total Revenues $ 6,753.5 $ 3,306.7 $ 877.8 $ 1,305.5 $ 72.0 $ (1,007.6) $ 11,307.9 Net Income (Loss) $ 896.8 $ 403.1 $ 373.1 $ 203.6 $ (114.6) $ — $ 1,762.0 September 30, 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 $ 50,990.6 $ 22,171.7 $ 12,865.6 $ 2,125.8 $ 414.5 $ — $ 88,568.2 Accumulated Depreciation and Amortization 16,647.1 4,059.9 758.1 222.8 189.1 — 21,877.0 Total Property Plant and Equipment - Net $ 34,343.5 $ 18,111.8 $ 12,107.5 $ 1,903.0 $ 225.4 $ — $ 66,691.2 Total Assets $ 45,775.5 $ 21,053.1 $ 13,287.6 $ 4,387.6 $ 6,421.4 (b) $ (4,588.1) (c) $ 86,337.1 Long-term Debt Due Within One Year: Nonaffiliated $ 1,243.0 $ 815.2 $ 52.4 $ — $ 411.2 (d) $ — $ 2,521.8 Long-term Debt: Affiliated 65.0 — — — — (65.0) — Nonaffiliated 13,616.0 7,869.0 4,544.2 — 6,027.3 (d) — 32,056.5 Total Long-term Debt $ 14,924.0 $ 8,684.2 $ 4,596.6 $ — $ 6,438.5 (d) $ (65.0) $ 34,578.3 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 and nine months ended September 30, 2021 and 2020 and reportable segment balance sheet information as of September 30, 2021 and December 31, 2020. Three Months Ended September 30, 2021 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Revenues from: External Customers $ 79.2 $ — $ — $ 79.2 Sales to AEP Affiliates 297.6 — — 297.6 Other Revenues 0.2 — — 0.2 Total Revenues $ 377.0 $ — $ — $ 377.0 Interest Income $ 0.1 $ 40.3 $ (40.2) (a) $ 0.2 Interest Expense 36.1 40.2 (40.2) (a) 36.1 Income Tax Expense 36.7 — — 36.7 Net Income $ 145.3 $ 0.1 (b) $ — $ 145.4 Three Months Ended September 30, 2020 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Revenues from: External Customers $ 62.9 $ — $ — $ 62.9 Sales to AEP Affiliates 241.2 — — 241.2 Total Revenues $ 304.1 $ — $ — $ 304.1 Interest Income $ — $ 38.4 $ (38.2) (a) $ 0.2 Interest Expense 32.7 38.2 (38.2) (a) 32.7 Income Tax Expense 31.7 — — 31.7 Net Income $ 117.5 $ 0.1 (b) $ — $ 117.6 Nine Months Ended September 30, 2021 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo Consolidated (in millions) Revenues from: External Customers $ 239.3 $ — $ — $ 239.3 Sales to AEP Affiliates 864.6 — — 864.6 Other Revenues 0.3 — — 0.3 Total Revenues $ 1,104.2 $ — $ — $ 1,104.2 Interest Income $ 0.1 $ 117.0 $ (116.7) (a) $ 0.4 Interest Expense 104.5 116.6 (116.6) (a) 104.5 Income Tax Expense 115.4 — — 115.4 Net Income $ 445.5 $ 0.2 (b) $ — $ 445.7 Nine Months Ended September 30, 2020 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo Consolidated (in millions) Revenues from: External Customers $ 184.6 $ — $ — $ 184.6 Sales to AEP Affiliates 652.6 — — 652.6 Other Revenues 0.6 — — 0.6 Total Revenues $ 837.8 $ — $ — $ 837.8 Interest Income $ 0.9 $ 111.3 $ (109.9) (a) $ 2.3 Interest Expense 95.1 109.9 (109.9) (a) 95.1 Income Tax Expense 82.7 0.1 — 82.8 Net Income $ 308.0 $ 1.1 (b) $ — $ 309.1 September 30, 2021 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Total Transmission Property $ 12,359.3 $ — $ — $ 12,359.3 Accumulated Depreciation and Amortization 730.4 — — 730.4 Total Transmission Property – Net $ 11,628.9 $ — $ — $ 11,628.9 Notes Receivable - Affiliated $ — $ 4,343.5 $ (4,343.5) (c) $ — Total Assets $ 11,984.7 $ 4,445.3 (d) $ (4,498.9) (e) $ 11,931.1 Total Long-term Debt $ 4,440.0 $ 4,393.4 $ (4,440.0) (c) $ 4,393.4 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	9 Months Ended
	Sep. 30, 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 September 30, 2021 Primary Risk Unit of AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power MWhs 341.9 — 55.4 23.1 2.8 18.7 5.4 Natural Gas MMBtus 28.1 — — — — — 5.2 Heating Oil and Gasoline Gallons 7.8 2.0 1.2 0.7 1.5 0.9 1.1 Interest Rate USD $ 116.5 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt USD $ 1,250.0 $ — $ — $ — $ — $ — $ — 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. The Registrants netted cash collateral received from third parties against short-term and long-term risk management assets and cash collateral paid to third parties against short-term and long-term risk management liabilities as follows: September 30, 2021 December 31, 2020 Cash Collateral Cash Collateral Cash Collateral Cash Collateral Received Paid Received Paid Netted Against Netted Against Netted Against Netted Against Risk Management Risk Management Risk Management Risk Management Company Assets Liabilities Assets Liabilities (in millions) AEP $ 309.7 $ 38.3 $ 3.4 $ 6.8 APCo 0.6 10.7 0.4 — I&M 0.3 17.4 1.7 — Amounts for AEP Texas, OPCo, PSO and SWEPCo are immaterial as of September 30, 2021 and December 31, 2020, respectively. The following tables represent the gross fair value of the Registrants’ derivative activity on the balance sheets: AEP September 30, 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 $ 1,005.5 $ 321.1 $ 8.3 $ 1,334.9 $ (965.7) $ 369.2 Long-term Risk Management Assets 337.3 85.8 — 423.1 (144.8) 278.3 Total Assets 1,342.8 406.9 8.3 1,758.0 (1,110.5) 647.5 Current Risk Management Liabilities 834.5 33.1 — 867.6 (761.1) 106.5 Long-term Risk Management Liabilities 234.6 14.3 28.8 277.7 (78.1) 199.6 Total Liabilities 1,069.1 47.4 28.8 1,145.3 (839.2) 306.1 Total MTM Derivative Contract Net Assets (Liabilities) $ 273.7 $ 359.5 $ (20.5) $ 612.7 $ (271.3) $ 341.4 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 September 30, 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 0.1 (0.1) — Total Assets 0.9 (0.9) — Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — — — Total Liabilities — — — Total MTM Derivative Contract Net Assets (Liabilities) $ 0.9 $ (0.9) $ — 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 September 30, 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 $ 95.7 $ (48.7) $ 47.0 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets 0.2 (0.2) — Total Assets 95.9 (48.9) 47.0 Other Current Liabilities - Current Risk Management Liabilities 60.2 (58.9) 1.3 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities 0.2 (0.2) — Total Liabilities 60.4 (59.1) 1.3 Total MTM Derivative Contract Net Assets $ 35.5 $ 10.2 $ 45.7 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 September 30, 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 $ 37.8 $ (32.3) $ 5.5 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets 0.1 (0.1) — Total Assets 37.9 (32.4) 5.5 Current Risk Management Liabilities 51.9 (49.4) 2.5 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities 0.1 (0.1) — Total Liabilities 52.0 (49.5) 2.5 Total MTM Derivative Contract Net Assets (Liabilities) $ (14.1) $ 17.1 $ 3.0 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 $ 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 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 September 30, 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 0.1 (0.1) — Total Assets 0.7 (0.7) — Current Risk Management Liabilities 3.5 — 3.5 Long-term Risk Management Liabilities 86.9 — 86.9 Total Liabilities 90.4 — 90.4 Total MTM Derivative Contract Net Liabilities $ (89.7) $ (0.7) $ (90.4) 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 $ 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 September 30, 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 $ 19.0 $ (0.5) $ 18.5 Long-term Risk Management Assets — — — Total Assets 19.0 (0.5) 18.5 Current Risk Management Liabilities 0.2 (0.2) — Long-term Risk Management Liabilities — — — Total Liabilities 0.2 (0.2) — Total MTM Derivative Contract Net Assets (Liabilities) $ 18.8 $ (0.3) $ 18.5 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 September 30, 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 $ 18.1 $ (0.6) $ 17.5 Long-term Risk Management Assets 2.1 — 2.1 Total Assets 20.2 (0.6) 19.6 Current Risk Management Liabilities 0.2 (0.2) — Long-term Risk Management Liabilities — — — Total Liabilities 0.2 (0.2) — Total MTM Derivative Contract Net Assets (Liabilities) $ 20.0 $ (0.4) $ 19.6 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 disclosed as gross. These instruments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with the accounting guidance for “Derivatives and Hedging.” (b) Amounts include counterparty netting of risk management and hedging contracts and associated cash collateral in accordance with the accounting guidance for “Derivatives and Hedging.” (c) All derivative contracts subject to a master netting arrangement or similar agreement are offset in the statement of financial position. The tables below present the Registrants’ amount of gain (loss) recognized on risk management contracts: Amount of Gain (Loss) Recognized on Risk Management Contracts Three Months Ended September 30, 2021 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ (0.9) $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 128.8 — — — — — — Electric Generation, Transmission and Distribution Revenues — — (0.9) — — — — Purchased Electricity for Resale 0.2 — 0.1 — — — — Other Operation 0.9 0.3 0.1 0.1 0.1 0.1 0.2 Maintenance 1.1 0.2 0.2 0.1 0.2 0.1 0.1 Regulatory Assets (a) (7.2) — (2.9) (16.9) 14.9 — 0.1 Regulatory Liabilities (a) 46.5 (0.1) 14.2 1.7 0.8 14.0 12.7 Total Gain (Loss) on Risk Management Contracts $ 169.4 $ 0.4 $ 10.8 $ (15.0) $ 16.0 $ 14.2 $ 13.1 Three Months Ended September 30, 2020 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 0.5 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 11.5 — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.3 — — — — Purchased Electricity for Resale 0.3 — 0.2 0.1 — — — Other Operation (0.4) (0.1) (0.1) (0.1) (0.1) (0.1) (0.1) Maintenance (0.8) (0.2) (0.1) (0.1) (0.2) — (0.1) Regulatory Assets (a) 7.9 0.2 0.4 0.2 4.4 (0.4) 2.9 Regulatory Liabilities (a) 17.0 — 3.8 2.6 1.7 3.1 2.0 Total Gain (Loss) on Risk Management Contracts $ 36.0 $ (0.1) $ 4.5 $ 2.7 $ 5.8 $ 2.6 $ 4.7 Nine Months Ended September 30, 2021 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ (0.6) $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 144.9 — — — — — — Electric Generation, Transmission and Distribution Revenues — — (0.6) — — — — Purchased Electricity for Resale 1.2 — 1.0 0.1 — — — Other Operation 1.9 0.6 0.2 0.2 0.3 0.2 0.3 Maintenance 2.4 0.6 0.4 0.2 0.4 0.2 0.3 Regulatory Assets (a) (7.8) — (2.9) (22.9) 20.3 — 1.4 Regulatory Liabilities (a) 123.6 0.5 28.9 1.9 5.9 40.2 38.5 Total Gain (Loss) on Risk Management Contracts $ 265.6 $ 1.7 $ 27.0 $ (20.5) $ 26.9 $ 40.6 $ 40.5 Nine Months Ended September 30, 2020 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 0.8 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 11.1 — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.4 0.1 — — 0.1 Purchased Electricity for Resale 1.2 — 1.0 0.1 — — — Other Operation (1.4) (0.4) (0.2) (0.2) (0.3) (0.2) (0.2) Maintenance (2.2) (0.6) (0.3) (0.2) (0.4) (0.2) (0.3) Regulatory Assets (a) (8.5) (0.3) (0.1) (0.2) (9.9) (0.6) 2.2 Regulatory Liabilities (a) 80.9 — 16.2 8.8 8.4 23.9 14.8 Total Gain (Loss) on Risk Management Contracts $ 81.9 $ (1.3) $ 17.0 $ 8.4 $ (2.2) $ 22.9 $ 16.6 (a) Represents realized and unrealized gains and losses subject to regulatory accounting treatment recorded as either current or noncurrent on the balance sheets. Certain qualifying derivative instruments have been designated as normal purchase or normal sale contracts, as provided in the accounting guidance for “Derivatives and Hedging.” Derivative contracts that have been designated as normal purchases or normal sales under that accounting guidance are not subject to MTM accounting treatment and are recognized on the statements of income on an accrual basis. The accounting for the changes in the fair value of a derivative instrument depends on whether it qualifies for and has been designated as part of a hedging relationship and further, on the type of hedging relationship. Depending on the exposure, management designates a hedging instrument as a fair value hedge or a cash flow hedge. For contracts that have not been designated as part of a hedging relationship, the accounting for changes in fair value depends on whether the derivative instrument is held for trading purposes. Unrealized and realized gains and losses on derivative instruments held for trading purposes are included in revenues on a net basis on the statements of income. Unrealized and realized gains and losses on derivative instruments not held for trading purposes are included in revenues or expenses on the statements of income depending on the relevant facts and circumstances. Certain derivatives that economically hedge future commodity risk are recorded in the same line item on the statements of income as that of the associated risk being hedged. However, unrealized and some realized gains and losses in regulated jurisdictions for both trading and non-trading derivative instruments are recorded as regulatory assets (for losses) or regulatory liabilities (for gains) in accordance with the accounting guidance for “Regulated Operations.” Accounting for Fair Value Hedging Strategies (Applies to AEP) For fair value hedges (i.e. hedging the exposure to changes in the fair value of an asset, liability or an identified portion thereof attributable to a particular risk), the gain or loss on the derivative instrument as well as the offsetting gain or loss on the hedged item associated with the hedged risk impacts net income during the period of change. AEP records realized and unrealized gains or losses on interest rate swaps that are designated and qualify for fair value hedge accounting treatment and any offsetting changes in the fair value of the debt being hedged in Interest Expense on the statements of income. The following table shows the impacts recognized on the balance sheets related to the hedged items in fair value hedging relationships: Carrying Amount of the Hedged Liabilities Cumulative Amount of Fair Value Hedging Adjustment Included in the Carrying Amount of the Hedged Liabilities September 30, 2021 December 31, 2020 September 30, 2021 December 31, 2020 (in millions) Long-term Debt (a) (b) $ (965.6) $ (995.9) $ (22.1) $ (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 $(47) million and $(53) million as of September 30, 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 September 30, Nine Months Ended September 30, 2021 2020 2021 2020 (in millions) Gain (Loss) on Interest Rate Contracts: Fair Value Hedging Instruments (a) $ (0.1) $ — $ (23.8) $ 42.6 Fair Value Portion of Long-term Debt (a) 0.1 — 23.8 (42.6) (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 and nine months ended September 30, 2021 and 2020, AEP applied cash flow hedging to outstanding power derivatives and the Registrant Subsidiaries did not. The Registrants reclassify gains and losses on interest rate derivative hedges related to debt financings from Accumulated Other Comprehensive Income (Loss) on the balance sheets into Interest Expense on the statements of income in those periods in which hedged interest payments occur. During the three months ended September 30, 2021, AEP applied cash flow hedging to outstanding interest rate derivatives and the Registrant Subsidiaries did not. During the three months ended September 30, 2020, AEP and APCo applied cash flow hedging to outstanding interest rate derivatives and the other Registrant Subsidiaries did not. During the nine months ended September 30, 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 September 30, 2021 December 31, 2020 Commodity Interest Rate Commodity Interest Rate (in millions) AOCI Gain (Loss) Net of Tax $ 283.9 $ (26.1) $ (60.6) $ (47.5) Portion Expected to be Reclassed to Net Income During the Next Twelve Months 56.5 (2.6) (27.1) (5.7) As of September 30, 2021 the maximum length of time that AEP is hedging its exposure to variability in future cash flows related to forecasted transactions is 114 months and 111 months for commodity and interest rate hedges, respectively. Impact of Cash Flow Hedges on the Registrant Subsidiaries’ Balance Sheets September 30, 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 $ (1.5) $ (1.1) $ (2.3) $ (1.1) APCo 7.7 0.8 (0.8) 0.4 I&M (7.0) (1.6) (8.3) (1.6) PSO — — 0.1 0.1 SWEPCo 0.8 (0.4) (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 derivative contracts with collateral triggering events in a net liability position as of September 30, 2021, with a total exposure of $25 million. The Registrant Subsidiaries had no derivative contracts with collateral triggering events in a net liability position as of September 30, 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: September 30, 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 $ 128.2 $ — $ 95.8 APCo 1.0 — — I&M 0.6 — — SWEPCo — — — 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 $30 million as of September 30, 2021, and common share warrants. AEP recorded an unrealized gain (loss) of $(16) million and $22 million associated with the common shares for the three and nine months ended September 30, 2021, respectively, presented in Other Income (Expense) on

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 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: September 30, 2021 December 31, 2020 Company Book Value Fair Value Book Value Fair Value (in millions) AEP (a) $ 34,578.3 $ 38,925.1 $ 31,072.5 $ 37,457.0 AEP Texas 5,216.1 5,763.9 4,820.4 5,682.6 AEPTCo 4,393.4 5,074.5 3,948.5 4,984.3 APCo 4,937.8 6,067.0 4,834.1 6,391.8 I&M 3,231.1 3,790.5 3,029.9 3,775.3 OPCo 3,468.1 3,948.6 2,430.2 3,154.9 PSO 1,913.3 2,169.2 1,373.8 1,732.1 SWEPCo 3,129.9 3,534.0 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 September 30, 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: September 30, 2021 Gross Gross Unrealized Unrealized Fair Other Temporary Investments Cost Gains Losses Value (in millions) Restricted Cash and Other Cash Deposits (a) $ 77.3 $ — $ — $ 77.3 Fixed Income Securities – Mutual Funds (b) 141.8 1.8 — 143.6 Equity Securities – Mutual Funds 19.4 32.1 — 51.5 Total Other Temporary Investments $ 238.5 $ 33.9 $ — $ 272.4 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 September 30, Nine Months Ended September 30, 2021 2020 2021 2020 (in millions) Proceeds from Investment Sales $ 6.0 $ 5.1 $ 15.1 $ 35.9 Purchases of Investments 12.9 22.5 26.0 39.5 Gross Realized Gains on Investment Sales 2.4 0.2 3.6 2.4 Gross Realized Losses on Investment Sales — — — 0.2 Fair Value Measurements of Trust Assets for Decommissioning and SNF Disposal (Applies to AEP and I&M) Nuclear decommissioning and SNF trust funds represent funds that regulatory commissions allow I&M to collect through rates to fund future decommissioning and SNF disposal liabilities. By rules or orders, the IURC, the MPSC and the FERC established investment limitations and general risk management guidelines. In general, limitations include: • Acceptable investments (rated investment grade or above when purchased). • Maximum percentage invested in a specific type of investment. • Prohibition of investment in obligations of AEP, I&M or their affiliates. • Withdrawals permitted only for payment of decommissioning costs and trust expenses. I&M maintains trust funds for each regulatory jurisdiction. Regulatory approval is required to withdraw decommissioning funds. These funds are managed by an external investment manager that must comply with the guidelines and rules of the applicable regulatory authorities. The trust assets are invested to optimize the net of tax earnings of the trust giving consideration to liquidity, risk, diversification and other prudent investment objectives. I&M records securities held in these trust funds in Spent Nuclear Fuel and Decommissioning Trusts on its balance sheets. I&M records these securities at fair value. I&M classifies debt securities in the trust funds as available-for-sale due to their long-term purpose. Other-than-temporary impairments for investments in debt securities are considered realized losses as a result of securities being managed by an external investment management firm. The external investment management firm makes specific investment decisions regarding the debt and equity investments held in these trusts and generally intends to sell debt securities in an unrealized loss position as part of a tax optimization strategy. Impairments reduce the cost basis of the securities which will affect any future unrealized gain or realized gain or loss due to the adjusted cost of investment. I&M records unrealized gains, unrealized losses and other-than-temporary impairments from securities in these trust funds as adjustments to the regulatory liability account for the nuclear decommissioning trust funds and to regulatory assets or liabilities for the SNF disposal trust funds in accordance with their treatment in rates. Consequently, changes in fair value of trust assets do not affect earnings or AOCI. The following is a summary of nuclear trust fund investments: September 30, 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 $ 63.9 $ — $ — $ 25.8 $ — $ — Fixed Income Securities: United States Government 1,135.3 66.9 (6.8) 1,025.6 98.5 (7.1) Corporate Debt 86.6 6.9 (2.0) 86.3 9.6 (1.7) State and Local Government 36.8 0.3 (0.2) 114.3 0.9 (0.4) Subtotal Fixed Income Securities 1,258.7 74.1 (9.0) 1,226.2 109.0 (9.2) Equity Securities - Domestic (a) 2,287.2 1,652.8 — 2,054.7 1,400.8 — Spent Nuclear Fuel and Decommissioning Trusts $ 3,609.8 $ 1,726.9 $ (9.0) $ 3,306.7 $ 1,509.8 $ (9.2) (a) Amount reported as Gross Unrealized Gains includes unrealized gains of $1.7 billion and $1.4 billion and unrealized losses of $4 million and $9 million as of September 30, 2021 and December 31, 2020, respectively. The following table provides the securities activity within the decommissioning and SNF trusts: Three Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 (in millions) Proceeds from Investment Sales $ 433.9 $ 316.6 $ 1,556.6 $ 1,257.1 Purchases of Investments 436.6 318.6 1,586.3 1,290.0 Gross Realized Gains on Investment Sales 9.6 3.4 98.3 25.4 Gross Realized Losses on Investment Sales 7.0 0.5 12.5 25.2 The base cost of fixed income securities was $1.2 billion and $1.1 billion as of September 30, 2021 and December 31, 2020, respectively. The base cost of equity securities was $634 million and $654 million as of September 30, 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 September 30, 2021 was as follows: Fair Value of Fixed Income Securities (in millions) Within 1 year $ 292.9 After 1 year through 5 years 433.4 After 5 years through 10 years 251.5 After 10 years 280.9 Total $ 1,258.7 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 September 30, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments Restricted Cash and Other Cash Deposits (a) $ 66.1 $ — $ — $ 11.2 $ 77.3 Fixed Income Securities – Mutual Funds 143.6 — — — 143.6 Equity Securities – Mutual Funds (b) 51.5 — — — 51.5 Total Other Temporary Investments 261.2 — — 11.2 272.4 Risk Management Assets Risk Management Commodity Contracts (c) (d) 16.9 1,090.7 221.9 (1,054.0) 275.5 Cash Flow Hedges: Commodity Hedges (c) — 367.3 31.3 (34.9) 363.7 Interest Rate Hedges — 4.9 — — 4.9 Fair Value Hedges — 3.4 — — 3.4 Total Risk Management Assets 16.9 1,466.3 253.2 (1,088.9) 647.5 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 56.0 — — 7.9 63.9 Fixed Income Securities: United States Government — 1,135.3 — — 1,135.3 Corporate Debt — 86.6 — — 86.6 State and Local Government — 36.8 — — 36.8 Subtotal Fixed Income Securities — 1,258.7 — — 1,258.7 Equity Securities – Domestic (b) 2,287.2 — — — 2,287.2 Total Spent Nuclear Fuel and Decommissioning Trusts 2,343.2 1,258.7 — 7.9 3,609.8 Other Investments (h) 30.3 15.9 — — 46.2 Total Assets $ 2,651.6 $ 2,740.9 $ 253.2 $ (1,069.8) $ 4,575.9 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (d) $ 8.4 $ 923.3 $ 124.1 $ (782.6) $ 273.2 Cash Flow Hedges: Commodity Hedges (c) — 38.9 0.1 (34.9) 4.1 Fair Value Hedges — 28.8 — — 28.8 Total Risk Management Liabilities $ 8.4 $ 991.0 $ 124.2 $ (817.5) $ 306.1 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 September 30, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 43.9 $ — $ — $ — $ 43.9 Risk Management Assets Risk Management Commodity Contracts (c) — 0.9 — (0.9) — Total Assets $ 43.9 $ 0.9 $ — $ (0.9) $ 43.9 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 September 30, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 10.1 $ — $ — $ — $ 10.1 Risk Management Assets Risk Management Commodity Contracts (c) (g) — 48.9 47.0 (48.9) 47.0 Total Assets $ 10.1 $ 48.9 $ 47.0 $ (48.9) $ 57.1 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 59.3 $ 1.1 $ (59.1) $ 1.3 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 September 30, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 30.9 $ 7.0 $ (32.4) $ 5.5 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 56.0 — — 7.9 63.9 Fixed Income Securities: United States Government — 1,135.3 — — 1,135.3 Corporate Debt — 86.6 — — 86.6 State and Local Government — 36.8 — — 36.8 Subtotal Fixed Income Securities — 1,258.7 — — 1,258.7 Equity Securities - Domestic (b) 2,287.2 — — — 2,287.2 Total Spent Nuclear Fuel and Decommissioning Trusts 2,343.2 1,258.7 — 7.9 3,609.8 Total Assets $ 2,343.2 $ 1,289.6 $ 7.0 $ (24.5) $ 3,615.3 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 48.3 $ 3.7 $ (49.5) $ 2.5 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 September 30, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.7 $ — $ (0.7) $ — Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 90.4 $ — $ 90.4 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 September 30, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.3 $ 18.7 $ (0.5) $ 18.5 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 0.2 $ (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) $ — $ 0.2 $ 10.3 $ (0.2) $ 10.3 SWEPCo Assets and Liabilities Measured at Fair Value on a Recurring Basis September 30, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.4 $ 19.8 $ (0.6) $ 19.6 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 0.2 $ (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) $ — $ 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 September 30, 2021 maturity of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $2 million in 2021 and $7 million in periods 2022-2024; Level 2 matures $20 million in 2021, $112 million in periods 2022-2024, $22 million in periods 2025-2026 and $13 million in periods 2027-2033; Level 3 matures $96 million in 2021, $18 million in periods 2022-2024, $5 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 September 30, 2021 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of June 30, 2021 $ 101.2 $ 36.6 $ 7.3 $ (105.4) $ 22.9 $ 14.6 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 27.5 4.0 0.1 0.1 13.5 5.8 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) 2.9 — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 17.8 — — — — — Settlements (54.5) (10.5) (3.8) 0.9 (20.6) (9.8) Transfers into Level 3 (d) (e) (5.8) — — — — — Transfers out of Level 3 (e) (4.1) 0.1 — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 44.0 15.7 (0.3) 14.0 2.7 9.0 Balance as of September 30, 2021 $ 129.0 $ 45.9 $ 3.3 $ (90.4) $ 18.5 $ 19.6 Three Months Ended September 30, 2020 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of June 30, 2020 $ 111.6 $ 36.5 $ 4.5 $ (117.4) $ 23.8 $ 3.3 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 18.7 6.4 3.3 — 3.0 1.5 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) 6.5 — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 2.6 — — — — — Settlements (37.0) (11.1) (5.0) 1.3 (10.3) (3.5) Transfers into Level 3 (d) (e) (1.0) — — — — — Transfers out of Level 3 (e) 1.1 — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 3.6 (2.2) 1.0 2.9 (0.4) 2.4 Balance as of September 30, 2020 $ 106.1 $ 29.6 $ 3.8 $ (113.2) $ 16.1 $ 3.7 Nine Months Ended September 30, 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) 68.9 38.8 0.4 0.4 16.1 9.5 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (64.1) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 35.5 — — — — — Settlements (113.3) (58.2) (2.5) 5.8 (26.4) (13.0) Transfers into Level 3 (d) (e) (0.2) — — — — Transfers out of Level 3 (e) (26.2) — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 115.1 46.0 3.3 13.7 18.5 21.5 Balance as of September 30, 2021 $ 129.0 $ 45.9 $ 3.3 $ (90.4) $ 18.5 $ 19.6 Nine Months Ended September 30, 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) 39.6 13.1 2.4 (1.2) 11.9 2.8 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (2.4) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 21.7 — — — — — Settlements (115.3) (51.4) (8.5) 6.4 (27.6) (6.9) Transfers into Level 3 (d) (e) (1.1) — — — — — Transfers out of Level 3 (e) 5.6 0.7 0.4 — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 48.1 29.5 3.7 (14.8) 16.0 6.4 Balance as of September 30, 2020 $ 106.1 $ 29.6 $ 3.8 $ (113.2) $ 16.1 $ 3.7 (a) Included in revenues on the statements of income. (b) Represents the change in fair value between the beginning of the reporting period and the settlement of the risk management commodity contract. (c) Included in cash flow hedges on the statements of comprehensive income. (d) Represents existing assets or liabilities that were previously categorized as Level 2. (e) Transfers are recognized based on their value at the beginning of the reporting period that the transfer occurred. (f) Relates to the net gains (losses) of those contracts that are not reflected on the statements of income. These 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 September 30, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (in millions) Energy Contracts $ 145.6 $ 117.3 Discounted Cash Flow Forward Market Price (a) (c) $ 0.10 $ 108.40 $ 35.57 Natural Gas Contracts 9.0 — Discounted Cash Flow Forward Market Price (b) (c) 2.92 6.27 4.59 FTRs 98.6 6.9 Discounted Cash Flow Forward Market Price (a) (c) (21.95) 13.46 0.46 Total $ 253.2 $ 124.2 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 September 30, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ 0.2 $ 1.1 Discounted Cash Flow Forward Market Price $ 26.70 $ 87.14 $ 53.61 FTRs 46.8 — Discounted Cash Flow Forward Market Price 0.35 13.46 1.83 Total $ 47.0 $ 1.1 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 September 30, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ 0.2 $ 0.7 Discounted Cash Flow Forward Market Price $ 26.70 $ 87.14 $ 53.61 FTRs 6.8 3.0 Discounted Cash Flow Forward Market Price (1.85) 5.75 0.37 Total $ 7.0 $ 3.7 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 September 30, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ — $ 90.4 Discounted Cash Flow Forward Market Price $ 9.89 $ 81.50 $ 32.40 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 September 30, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) FTRs $ 18.7 $ 0.2 Discounted Cash Flow Forward Market Price $ (18.86) $ 4.10 $ (2.44) 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 September 30, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (c) (in millions) Natural Gas Contracts $ 9.0 $ — Discounted Cash Flow Forward Market Price (b) $ 3.58 $ 6.27 $ 4.44 FTRs 10.8 0.2 Discounted Cash Flow Forward Market Price (a) (18.86) 4.10 (2.44) Total $ 19.8 $ 0.2 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 September 30, 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

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 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 September 30, 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 0.6 % 0.3 % 3.0 % (0.3) % 1.9 % 1.2 % 5.0 % (6.9) % Tax Reform Excess ADIT Reversal (8.5) % (6.3) % 0.3 % (14.2) % (16.1) % (8.9) % (19.8) % (4.2) % Production and Investment Tax Credits (4.7) % (0.3) % — % (0.2) % (2.0) % — % (8.9) % (5.4) % Flow Through — % 0.3 % 0.3 % 0.4 % (2.8) % 0.6 % 0.7 % (0.2) % AFUDC Equity (1.2) % (1.0) % (2.2) % (1.8) % (1.0) % (0.3) % (0.2) % (0.5) % Parent Company Loss Benefit — % (1.1) % (2.3) % (1.2) % (3.6) % — % — % 0.7 % Discrete Tax Adjustments 0.2 % — % — % — % — % — % — % 1.2 % Other 0.7 % (0.1) % 0.1 % 0.3 % 0.8 % — % (0.1) % (0.2) % Effective Income Tax Rate 8.1 % 12.8 % 20.2 % 4.0 % (1.8) % 13.6 % (2.3) % 5.5 % Three Months Ended September 30, 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 2.7 % 2.0 % 2.9 % 3.1 % 3.4 % 0.8 % 4.6 % 2.4 % Tax Reform Excess ADIT Reversal (11.0) % (14.6) % 0.4 % (22.0) % (16.7) % (6.7) % (20.3) % (7.3) % Production and Investment Tax Credits (4.6) % (0.5) % — % — % (1.6) % — % (1.1) % (0.5) % Flow Through 0.5 % 0.2 % 0.5 % 1.6 % 0.2 % 0.9 % 0.2 % (1.2) % AFUDC Equity (1.5) % (3.5) % (2.6) % (1.1) % (0.9) % (0.9) % (0.6) % (0.3) % Parent Company Loss Benefit — % — % (0.9) % (3.1) % (3.7) % (0.3) % (1.7) % (2.0) % Discrete Tax Adjustments (a) (7.4) % (3.6) % (0.2) % (6.6) % 2.3 % 8.4 % (0.6) % (0.6) % Other 0.1 % 0.3 % 0.1 % — % — % 0.3 % 0.1 % (0.6) % Effective Income Tax Rate (0.2) % 1.3 % 21.2 % (7.1) % 4.0 % 23.5 % 1.6 % 10.9 % Nine Months Ended September 30, 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 1.2 % 0.3 % 2.8 % 1.5 % 1.6 % 0.8 % 4.8 % (3.4) % Tax Reform Excess ADIT Reversal (8.9) % (7.2) % 0.3 % (15.2) % (17.7) % (9.1) % (19.8) % (4.3) % Production and Investment Tax Credits (4.9) % (0.3) % — % — % (2.2) % — % (8.1) % (4.6) % Flow Through 0.2 % 0.3 % 0.3 % 1.7 % (3.0) % 0.9 % 0.7 % (0.2) % AFUDC Equity (1.1) % (1.1) % (1.9) % (1.2) % (1.0) % (0.8) % (0.3) % (0.6) % Parent Company Loss Benefit — % (0.7) % (1.9) % (1.3) % (2.8) % — % — % — % Discrete Tax Adjustments 1.1 % — % — % — % — % (1.3) % (0.9) % 0.6 % Other 0.1 % — % — % 0.1 % 0.4 % 0.2 % (0.2) % (0.1) % Effective Income Tax Rate 8.7 % 12.3 % 20.6 % 6.6 % (3.7) % 11.7 % (2.8) % 8.4 % Nine Months Ended September 30, 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 2.6 % 1.8 % 2.9 % 3.1 % 3.4 % 0.7 % 4.6 % 2.3 % Tax Reform Excess ADIT Reversal (12.1) % (23.4) % 0.4 % (20.8) % (16.7) % (8.8) % (20.3) % (11.5) % Production and Investment Tax Credits (4.5) % (0.5) % — % — % (1.6) % — % (1.1) % (0.5) % Flow Through 0.5 % 0.1 % 0.5 % 1.6 % 0.2 % 0.9 % 0.2 % (1.2) % AFUDC Equity (1.5) % (3.2) % (2.6) % (1.1) % (0.9) % (0.9) % (0.6) % (0.3) % Parent Company Loss Benefit — % — % (0.9) % (3.1) % (3.7) % (0.3) % (1.7) % (1.9) % Discrete Tax Adjustments (a) (3.0) % (1.6) % (0.1) % (2.3) % 1.8 % 2.6 % (0.4) % (0.3) % Other 0.2 % 0.4 % (0.1) % (0.1) % (0.1) % 0.2 % 0.1 % (0.4) % Effective Income Tax Rate 3.2 % (5.4) % 21.1 % (1.7) % 3.4 % 15.4 % 1.8 % 7.2 % (a) The discrete tax expense is primarily attributable to the $48 million benefit recognized as a result of the 5-year net operating losses (NOL) carryback provision of the CARES Act. 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 through 2017 federal returns. In the first quarter of 2020, the IRS notified AEP that it was beginning an examination of these amended returns, including the NOL carryback to 2015 that originated in the 2017 return. As of September 30, 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. AEP has agreed to extend the statute of limitations on the 2017 tax return to December 31, 2022 to allow time for the audit to be completed and the Congressional Joint Committee on Taxation to approve the associated refund claim. AEP and subsidiaries file income tax returns in various state and local jurisdictions. These taxing authorities routinely examine the tax returns, and AEP and subsidiaries are currently under examination in several state and local jurisdictions. The Registrants are no longer subject to state or local examinations by tax authorities for years before 2012. In addition, management is monitoring and continues to evaluate the potential impact of federal legislation and corresponding state conformity. 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. State Legislation In April 2021, West Virginia enacted House Bill (H.B.) 2026. H.B. 2026 changes the state income tax apportionment formula from a ratio that includes property, payroll and sales to a single sales factor apportionment regime effective for tax years beginning on or after January 1, 2022. H.B. 2026 also eliminates the “throw out” rule related to sales of tangible personal property for sales factor apportionment calculation purposes and introduces a market-based sourcing for sales of services and intangible property. In the second quarter of 2021, AEP recorded $20 million in Income Tax Expense as a result of remeasuring West Virginia deferred taxes under the new apportionment methodology. The enacted legislation does not impact AEP Texas, PSO or SWEPCo. In May 2021, Oklahoma enacted House Bill (H.B.) 2960. H.B. 2960 reduces the Oklahoma corporate income tax rate from 6% to 4%. In the second quarter of 2021, AEP recorded a $1 million Income Tax Benefit as a result of remeasuring Oklahoma deferred taxes at the lowered statutory tax rate of 4%. The enacted legislation does not impact APCo, I&M or OPCo.

Financing Activities

Financing Activities	9 Months Ended
	Sep. 30, 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. For the nine months ended September 30, 2021, AEP issued 5,421,825 shares of common stock and received net cash proceeds of $461 million under the ATM program. 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 September 30, 2021 December 31, 2020 (in millions) Senior Unsecured Notes $ 28,778.1 $ 25,116.1 Pollution Control Bonds 1,881.0 1,936.7 Notes Payable 235.1 239.1 Securitization Bonds 639.7 716.4 Spent Nuclear Fuel Obligation (a) 281.3 281.2 Junior Subordinated Notes (b) 1,629.9 1,624.1 Other Long-term Debt 1,133.2 1,158.9 Total Long-term Debt Outstanding 34,578.3 31,072.5 Long-term Debt Due Within One Year 2,521.8 2,086.1 Long-term Debt $ 32,056.5 $ 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 $327 million and $324 million as of September 30, 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 nine months of 2021 are shown in the following tables: Principal Interest Company Type of Debt Amount (a) Rate Due Date Issuances: (in millions) (%) AEP Senior Unsecured Notes $ 175.0 1.80 2028 AEP Texas Senior Unsecured Notes 450.0 3.45 2051 AEPTCo Senior Unsecured Notes 450.0 2.75 2051 APCo Senior Unsecured Notes 500.0 2.70 2031 I&M Notes Payable 64.9 0.93 2025 I&M Senior Unsecured Notes 450.0 3.25 2051 OPCo Senior Unsecured Notes 450.0 1.63 2031 OPCo Senior Unsecured Notes 600.0 2.90 2051 PSO Other Long-term Debt 500.0 Variable 2022 PSO Senior Unsecured Notes 400.0 2.20 2031 PSO Senior Unsecured Notes 400.0 3.15 2051 SWEPCo Senior Unsecured Notes 500.0 1.65 2026 Non-Registrant: KPCo Other Long-term Debt 150.0 Variable 2023 Transource Energy Other Long-term Debt 25.9 Variable 2023 Total Issuances $ 5,115.8 (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 $ 29.7 2.85 2024 AEP Texas Securitization Bonds 22.5 2.06 2025 APCo Senior Unsecured Notes 350.0 4.60 2021 APCo Pollution Control Bonds 17.5 4.63 2021 APCo Securitization Bonds 25.4 2.01 2023 APCo Other Long-term Debt 0.1 13.72 2026 I&M Other Long-term Debt 200.0 Variable 2021 I&M Pollution Control Bonds 40.0 2.05 2021 I&M Notes Payable 1.9 Variable 2021 I&M Notes Payable 4.5 Variable 2022 I&M Notes Payable 5.4 Variable 2022 I&M Notes Payable 14.3 Variable 2023 I&M Notes Payable 12.6 Variable 2024 I&M Notes Payable 19.6 Variable 2025 I&M Notes Payable 7.4 0.93 2025 I&M Other Long-term Debt 1.5 6.00 2025 OPCo Other Long-term Debt 0.1 1.15 2028 PSO Senior Unsecured Notes 250.0 4.40 2021 PSO Other Long-term Debt 500.0 Variable 2022 PSO Other Long-term Debt 0.4 3.00 2027 SWEPCo Other Long-term Debt 1.5 4.68 2028 SWEPCo Notes Payable 3.2 4.58 2032 Non-Registrant: KPCo Senior Unsecured Notes 39.8 7.25 2021 Transource Energy Senior Unsecured Notes 1.2 2.75 2050 Transource Energy Senior Unsecured Notes 1.2 2.75 2050 Total Retirements and Principal Payments $ 1,549.8 As of September 30, 2021, trustees held, on behalf of I&M, $40 million of its reacquired Pollution Control Bonds. Long-term Debt Subsequent Event In October 2021, I&M retired $8 million of Notes Payable related to DCC Fuel. In October 2021, OPCo retired $500 million of Senior Unsecured Notes. 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 0.1% of consolidated tangible net assets as of September 30, 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 September 30, 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 nine months ended September 30, 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 September 30, 2021 Limit (in millions) AEP Texas $ 355.5 $ 104.7 $ 234.7 $ 45.2 $ 47.6 $ 500.0 AEPTCo 444.9 117.3 225.1 24.4 73.9 820.0 (a) APCo 27.8 616.9 13.2 134.4 185.2 500.0 I&M 166.5 368.2 117.5 76.3 80.6 500.0 OPCo 259.2 622.9 62.8 182.5 622.9 500.0 PSO 267.7 747.3 142.8 184.9 59.5 300.0 SWEPCo 280.3 156.4 148.0 142.0 (122.9) 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 September 30, 2021 and December 31, 2020 are included in Advances to Affiliates on the subsidiaries’ balance sheets. The Nonutility Money Pool participants’ activity for the nine months ended September 30, 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 September 30, 2021 (in millions) AEP Texas $ 7.1 $ 6.9 $ 7.0 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 September 30, 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 nine months ended September 30, 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 September 30, 2021 September 30, 2021 Borrowing Limit (in millions) $ 14.6 $ 224.2 $ 1.6 $ 139.3 $ 8.6 $ — $ 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: Nine Months Ended September 30, 2021 2020 Maximum Interest Rate 0.40 % 2.70 % Minimum Interest Rate 0.02 % 0.33 % 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 Nine Months Ended September 30, for Nine Months Ended September 30, Company 2021 2020 2021 2020 AEP Texas 0.33 % 1.55 % 0.27 % 0.87 % AEPTCo 0.32 % 1.63 % 0.07 % 2.00 % APCo 0.28 % 2.14 % 0.28 % 0.99 % I&M 0.32 % 1.30 % 0.25 % 1.44 % OPCo 0.27 % 1.32 % 0.15 % 2.06 % PSO 0.34 % 1.24 % 0.06 % 1.95 % SWEPCo 0.28 % 1.55 % 0.38 % — % Maximum, minimum and average interest rates for funds loaned to the Nonutility Money Pool are summarized in the following table: Nine Months Ended September 30, 2021 Nine Months Ended September 30, 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 0.41 % 0.21 % 0.34 % 2.70 % 0.33 % 1.44 % SWEPCo 0.41 % 0.21 % 0.34 % 2.70 % 0.33 % 1.44 % 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 Nine Months for Funds for Funds for Funds for Funds for Funds for Funds Ended Borrowed Borrowed Loaned Loaned Borrowed Loaned September 30, from AEP from AEP to AEP to AEP from AEP to AEP 2021 0.86 % 0.25 % 0.86 % 0.25 % 0.35 % 0.34 % 2020 2.70 % 0.50 % 2.70 % 0.50 % 1.45 % 1.40 % Short-term Debt (Applies to AEP and SWEPCo) Outstanding short-term debt was as follows: September 30, 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) $ 750.0 0.19 % $ 592.0 0.85 % AEP Commercial Paper 1,254.0 0.25 % 1,852.3 0.29 % AEP 364-Day Term Loan 500.0 0.72 % — — % SWEPCo Notes Payable — — % 35.0 2.55 % Total Short-term Debt $ 2,504.0 $ 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 with bank conduits. Under the securitization agreement, AEP Credit receives financing from the bank conduits for the interest in the receivables AEP Credit acquires from affiliated utility subsidiaries. These securitized transactions allow AEP Credit to repay its outstanding debt obligations, continue to purchase the operating companies’ receivables and accelerate AEP Credit’s cash collections. AEP Credit’s receivables securitization agreement provides a commitment of $750 million from bank conduits to purchase receivables and was amended in September 2021 to include a $125 million and a $625 million facility which expire in September 2023 and 2024, respectively. As of September 30, 2021, the affiliated utility subsidiaries are in compliance with all requirements under the agreement. Accounts receivable information for AEP Credit was as follows: Three Months Ended Nine Months Ended September 30, September 30, 2021 2020 2021 2020 (dollars in millions) Effective Interest Rates on Securitization of Accounts Receivable 0.18 % 0.36 % 0.19 % 1.05 % Net Uncollectible Accounts Receivable Written-Off $ 7.5 $ 2.9 $ 22.6 $ 10.5 September 30, 2021 December 31, 2020 (in millions) Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts $ 1,031.3 $ 958.4 Short-term – Securitized Debt of Receivables 750.0 592.0 Delinquent Securitized Accounts Receivable 60.0 62.3 Bad Debt Reserves Related to Securitization 39.8 60.0 Unbilled Receivables Related to Securitization 224.5 296.8 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 September 30, 2021 December 31, 2020 (in millions) APCo $ 131.0 $ 136.0 I&M 173.9 170.5 OPCo 377.3 398.8 PSO 147.1 85.0 SWEPCo 185.6 158.6 The fees paid to AEP Credit for customer accounts receivable sold were: Three Months Ended September 30, Nine Months Ended September 30, Company 2021 (a) 2020 2021 (a) 2020 (in millions) APCo $ 1.3 $ 2.0 $ 3.7 $ 5.0 I&M 2.1 3.9 5.3 9.3 OPCo 4.6 9.8 3.5 19.6 PSO 1.1 1.5 2.4 3.8 SWEPCo 1.3 2.8 4.1 6.8 (a) In 2020, an increase in allowance for doubtful accounts was recognized in response to the anticipated impact of COVID-19 on the collectability of accounts receivable, which caused an increase in fees paid by the registrants. In 2021, due to higher than expected collections of accounts receivables, allowance for doubtful accounts was adjusted resulting in the issuance of credits to offset the higher fees previously paid and to lower subsequent fees paid. The proceeds on the sale of receivables to AEP Credit were: Three Months Ended September 30, Nine Months Ended September 30, Company 2021 2020 2021 2020 (in millions) APCo $ 342.2 $ 323.5 $ 980.6 $ 961.8 I&M 536.8 532.3 1,478.9 1,443.6 OPCo 668.4 666.0 1,867.5 1,793.0 PSO 460.1 369.2 1,068.8 961.4 SWEPCo 488.5 478.3 1,265.5 1,225.3

Property, Plant and Equipment

Property, Plant and Equipment	9 Months Ended
	Sep. 30, 2021
Property, Plant and Equipment	13. PROPERTY, PLANT AND EQUIPMENT The disclosure in this note applies to AEP and APCo. Asset Retirement Obligations The Registrants record ARO in accordance with the accounting guidance for “Asset Retirement and Environmental Obligations” for legal obligations for asbestos removal and for the retirement of certain ash disposal facilities, wind farms, solar farms and certain coal mining facilities. The discussion below summarizes significant changes to the Registrants ARO recorded in 2021 and should be read in conjunction with the Property, Plant and Equipment note within the 2020 Annual Report. In 2020, Virginia’s Governor signed House Bill 443 (HB 443) requiring APCo to close certain ash disposal units at the retired Glen Lyn Station by removal of all coal combustion material. In June 2020, APCo recorded a revision to increase estimated Glen Lyn Station ash disposal ARO liabilities by $199 million due to the enactment of HB 443. In June 2021, management completed fully designed and costed project plans for the Glen Lyn Station site and increased ash disposal ARO liabilities by an additional $79 million. HB 443 provides for the recovery of all costs associated with closure by removal through the Virginia environmental rate adjustment clause. APCo is permitted to record carrying costs on the unrecovered balance of closure costs at a weighted-average cost of capital approved by the Virginia SCC. The following is a reconciliation of the aggregate carrying amounts of ARO for AEP and APCo: Company ARO as of December 31, 2020 Accretion Liabilities Liabilities Revisions in ARO as of September 30, 2021 (in millions) AEP (a)(b)(c)(d) $ 2,516.7 $ 77.6 $ 17.7 $ (27.6) $ 75.1 $ 2,659.5 APCo (a)(d) 313.1 9.9 — (5.8) 84.7 401.9 (a) Includes ARO related to ash disposal facilities. (b) Includes ARO related to nuclear decommissioning costs for the Cook Plant of $1.85 billion and $1.80 billion as of September 30, 2021 and December 31, 2020, respectively. (c) Includes ARO related to Sabine and DHLC. (d) Includes ARO related to asbestos removal.

Revenue from Contracts with Cus

Revenue from Contracts with Customers	9 Months Ended
	Sep. 30, 2020
Revenue from Contract with Customer	14. REVENUE FROM CONTRACTS WITH CUSTOMERS The disclosures in this note apply to all Registrants, unless indicated otherwise. Disaggregated Revenues from Contracts with Customers The tables below represent AEP’s reportable segment revenues from contracts with customers, net of respective provisions for refund, by type of revenue: Three Months Ended September 30, 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 $ 1,144.3 $ 598.0 $ — $ — $ — $ — $ 1,742.3 Commercial Revenues 618.9 279.9 — — — — 898.8 Industrial Revenues 566.0 95.2 — — — (0.1) 661.1 Other Retail Revenues 47.5 11.1 — — — — 58.6 Total Retail Revenues 2,376.7 984.2 — — — (0.1) 3,360.8 Wholesale and Competitive Retail Revenues: Generation Revenues 233.8 — — 47.8 — — 281.6 Transmission Revenues (a) 99.8 150.6 375.8 — — (317.4) 308.8 Renewable Generation Revenues (b) — — — 24.1 — (0.6) 23.5 Retail, Trading and Marketing Revenues (c) — — — 397.1 0.1 (3.1) 394.1 Total Wholesale and Competitive Retail Revenues 333.6 150.6 375.8 469.0 0.1 (321.1) 1,008.0 Other Revenues from Contracts with Customers (b) 49.4 54.2 5.1 1.4 23.5 (40.1) 93.5 Total Revenues from Contracts with Customers 2,759.7 1,189.0 380.9 470.4 23.6 (361.3) 4,462.3 Other Revenues: Alternative Revenues (b) 0.5 6.4 10.7 — — (11.7) 5.9 Other Revenues (b) (d) (0.9) 4.9 — 150.7 3.1 (3.0) 154.8 Total Other Revenues (0.4) 11.3 10.7 150.7 3.1 (14.7) 160.7 Total Revenues $ 2,759.3 $ 1,200.3 $ 391.6 $ 621.1 $ 26.7 $ (376.0) $ 4,623.0 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $286 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 $4 million. The remaining affiliated amounts were immaterial. (d) Generation & Marketing includes economic hedge activity. Three Months Ended September 30, 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 $ 1,053.3 $ 594.8 $ — $ — $ — $ — $ 1,648.1 Commercial Revenues 559.7 259.2 — — — — 818.9 Industrial Revenues 504.5 93.9 — — — (0.1) 598.3 Other Retail Revenues 41.4 10.0 — — — — 51.4 Total Retail Revenues 2,158.9 957.9 — — — (0.1) 3,116.7 Wholesale and Competitive Retail Revenues: Generation Revenues 158.4 — — 30.5 — — 188.9 Transmission Revenues (a) 84.4 119.1 317.7 — — (276.9) 244.3 Renewable Generation Revenues (b) — — — 15.8 — (0.3) 15.5 Retail, Trading and Marketing Revenues (c) — — — 447.5 0.9 (24.8) 423.6 Total Wholesale and Competitive Retail Revenues 242.8 119.1 317.7 493.8 0.9 (302.0) 872.3 Other Revenues from Contracts with Customers (b) 34.1 42.8 2.4 0.7 33.9 (43.7) 70.2 Total Revenues from Contracts with Customers 2,435.8 1,119.8 320.1 494.5 34.8 (345.8) 4,059.2 Other Revenues: Alternative Revenues (b) (1.0) 9.3 (2.2) — — 6.6 12.7 Other Revenues (b) (d) — 36.2 — (4.5) (2.2) (35.0) (5.5) Total Other Revenues (1.0) 45.5 (2.2) (4.5) (2.2) (28.4) 7.2 Total Revenues $ 2,434.8 $ 1,165.3 $ 317.9 $ 490.0 $ 32.6 $ (374.2) $ 4,066.4 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $246 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 $19 million. The remaining affiliated amounts were immaterial. (d) Generation & Marketing includes economic hedge activity. Three Months Ended September 30, 2021 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 172.5 $ — $ 340.1 $ 231.7 $ 425.4 $ 236.8 $ 230.9 Commercial Revenues 89.1 — 146.9 143.9 190.8 120.9 145.4 Industrial Revenues 25.4 — 154.8 146.8 69.8 77.1 85.4 Other Retail Revenues 8.2 — 18.6 1.3 3.1 23.4 2.3 Total Retail Revenues 295.2 — 660.4 523.7 689.1 458.2 464.0 Wholesale Revenues: Generation Revenues (a) — — 83.7 80.2 — 7.2 77.1 Transmission Revenues (b) 131.5 360.1 35.2 8.7 19.1 10.6 37.1 Total Wholesale Revenues 131.5 360.1 118.9 88.9 19.1 17.8 114.2 Other Revenues from Contracts with Customers (c) 6.8 5.0 22.5 24.2 47.3 8.3 6.1 Total Revenues from Contracts with Customers 433.5 365.1 801.8 636.8 755.5 484.3 584.3 Other Revenues: Alternative Revenues (d) (0.9) 11.9 2.2 (1.1) 7.3 (0.5) (0.2) Other Revenues (d) — — — — 4.9 — — Total Other Revenues (0.9) 11.9 2.2 (1.1) 12.2 (0.5) (0.2) Total Revenues $ 432.6 $ 377.0 $ 804.0 $ 635.7 $ 767.7 $ 483.8 $ 584.1 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $30 million primarily relating to the PPA with KGPCo. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $281 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $17 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 September 30, 2020 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 165.3 $ — $ 324.2 $ 222.6 $ 429.4 $ 195.8 $ 219.4 Commercial Revenues 78.0 — 138.4 135.8 181.2 94.4 135.0 Industrial Revenues 24.9 — 139.4 139.7 69.1 55.0 83.8 Other Retail Revenues 6.9 — 17.6 1.6 3.1 18.4 2.3 Total Retail Revenues 275.1 — 619.6 499.7 682.8 363.6 440.5 Wholesale Revenues: Generation Revenues (a) — — 70.3 61.5 — 5.8 42.3 Transmission Revenues (b) 101.8 305.7 30.8 7.4 17.2 8.5 28.7 Total Wholesale Revenues 101.8 305.7 101.1 68.9 17.2 14.3 71.0 Other Revenues from Contracts with Customers (c) 15.2 3.0 16.1 17.7 27.6 4.8 5.6 Total Revenues from Contracts with Customers 392.1 308.7 736.8 586.3 727.6 382.7 517.1 Other Revenues: Alternative Revenues (d) (0.7) (4.6) (1.1) 0.4 10.0 (0.5) 0.2 Other Revenues (d) 40.6 — — — 3.4 — — Total Other Revenues 39.9 (4.6) (1.1) 0.4 13.4 (0.5) 0.2 Total Revenues $ 432.0 $ 304.1 $ 735.7 $ 586.7 $ 741.0 $ 382.2 $ 517.3 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $28 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 $243 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $15 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. Nine Months Ended September 30, 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 $ 3,016.2 $ 1,641.2 $ — $ — $ — $ — $ 4,657.4 Commercial Revenues 1,642.0 804.1 — — — — 2,446.1 Industrial Revenues 1,602.5 283.8 — — — (0.5) 1,885.8 Other Retail Revenues 125.9 32.4 — — — — 158.3 Total Retail Revenues 6,386.6 2,761.5 — — — (0.5) 9,147.6 Wholesale and Competitive Retail Revenues: Generation Revenues 757.1 — — 119.4 — — 876.5 Transmission Revenues (a) 267.3 420.7 1,092.1 — — (901.5) 878.6 Renewable Generation Revenues (b) — — — 66.7 — (1.7) 65.0 Retail, Trading and Marketing Revenues (c) — — — 1,325.6 0.6 (48.5) 1,277.7 Total Wholesale and Competitive Retail Revenues 1,024.4 420.7 1,092.1 1,511.7 0.6 (951.7) 3,097.8 Other Revenues from Contracts with Customers (b) 136.1 149.3 12.5 4.9 46.1 (87.9) 261.0 Total Revenues from Contracts with Customers 7,547.1 3,331.5 1,104.6 1,516.6 46.7 (1,040.1) 12,506.4 Other Revenues: Alternative Revenues (b) 10.7 46.1 42.2 — — (63.5) 35.5 Other Revenues (b) (d) (0.6) 14.2 — 175.3 8.4 (8.6) 188.7 Total Other Revenues 10.1 60.3 42.2 175.3 8.4 (72.1) 224.2 Total Revenues $ 7,557.2 $ 3,391.8 $ 1,146.8 $ 1,691.9 $ 55.1 $ (1,112.2) $ 12,730.6 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $835 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 $49 million. The remaining affiliated amounts were immaterial. (d) Generation & Marketing includes economic hedge activity. Nine Months Ended September 30, 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 $ 2,789.1 $ 1,610.6 $ — $ — $ — $ — $ 4,399.7 Commercial Revenues 1,523.6 792.4 — — — — 2,316.0 Industrial Revenues 1,508.7 290.4 — — — (0.5) 1,798.6 Other Retail Revenues 118.2 32.1 — — — — 150.3 Total Retail Revenues 5,939.6 2,725.5 — — — (0.5) 8,664.6 Wholesale and Competitive Retail Revenues: Generation Revenues 447.4 — — 106.1 — — 553.5 Transmission Revenues (a) 248.4 341.6 937.7 — — (741.7) 786.0 Renewable Generation Revenues (b) — — — 50.7 — (1.2) 49.5 Retail, Trading and Marketing Revenues (c) — — — 1,133.8 (5.7) (80.7) 1,047.4 Total Wholesale and Competitive Retail Revenues 695.8 341.6 937.7 1,290.6 (5.7) (823.6) 2,436.4 Other Revenues from Contracts with Customers (b) 124.1 112.3 17.5 1.7 84.4 (115.7) 224.3 Total Revenues from Contracts with Customers 6,759.5 3,179.4 955.2 1,292.3 78.7 (939.8) 11,325.3 Other Revenues: Alternative Revenues (b) (6.0) 49.2 (77.4) — — 3.5 (30.7) Other Revenues (b) (d) — 78.1 — 13.2 (6.7) (71.3) 13.3 Total Other Revenues (6.0) 127.3 (77.4) 13.2 (6.7) (67.8) (17.4) Total Revenues $ 6,753.5 $ 3,306.7 $ 877.8 $ 1,305.5 $ 72.0 $ (1,007.6) $ 11,307.9 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $725 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 $81 million. The remaining affiliated amounts were immaterial. (d) Generation & Marketing includes economic hedge activity. Nine Months Ended September 30, 2021 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 423.7 $ — $ 1,025.0 $ 624.4 $ 1,217.5 $ 516.4 $ 547.1 Commercial Revenues 265.2 — 409.5 384.5 538.9 286.8 385.4 Industrial Revenues 81.6 — 433.4 418.9 202.2 202.1 247.1 Other Retail Revenues 23.1 — 51.7 3.9 9.4 58.2 7.2 Total Retail Revenues 793.6 — 1,919.6 1,431.7 1,968.0 1,063.5 1,186.8 Wholesale Revenues: Generation Revenues (a) — — 231.2 248.1 — 6.8 326.2 Transmission Revenues (b) 364.5 1,045.2 94.1 25.3 56.2 28.8 94.5 Total Wholesale Revenues 364.5 1,045.2 325.3 273.4 56.2 35.6 420.7 Other Revenues from Contracts with Customers (c) 35.4 12.5 43.6 81.9 113.8 24.8 17.7 Total Revenues from Contracts with Customers 1,193.5 1,057.7 2,288.5 1,787.0 2,138.0 1,123.9 1,625.2 Other Revenues: Alternative Revenues (d) 1.8 46.5 9.5 (3.0) 44.3 0.5 5.1 Other Revenues (d) — — — — 14.2 — — Total Other Revenues 1.8 46.5 9.5 (3.0) 58.5 0.5 5.1 Total Revenues $ 1,195.3 $ 1,104.2 $ 2,298.0 $ 1,784.0 $ 2,196.5 $ 1,124.4 $ 1,630.3 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $90 million primarily relating to the PPA with KGPCo. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $823 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $46 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. Nine Months Ended September 30, 2020 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 447.8 $ — $ 954.4 $ 610.8 $ 1,162.6 $ 463.5 $ 498.7 Commercial Revenues 285.2 — 390.6 376.0 507.3 247.8 351.2 Industrial Revenues 91.4 — 415.0 408.2 199.1 170.8 245.9 Other Retail Revenues 22.3 — 50.9 5.0 9.8 51.2 6.6 Total Retail Revenues 846.7 — 1,810.9 1,400.0 1,878.8 933.3 1,102.4 Wholesale Revenues: Generation Revenues (a) — — 185.3 215.5 — 9.9 106.7 Transmission Revenues (b) 290.4 902.6 91.5 22.1 51.1 20.2 87.5 Total Wholesale Revenues 290.4 902.6 276.8 237.6 51.1 30.1 194.2 Other Revenues from Contracts with Customers (c) 33.4 17.5 46.8 60.6 78.9 23.2 21.1 Total Revenues from Contracts with Customers 1,170.5 920.1 2,134.5 1,698.2 2,008.8 986.6 1,317.7 Other Revenues: Alternative Revenues (d) (0.3) (82.3) (11.9) 5.4 49.6 1.5 0.5 Other Revenues (d) 86.9 — — — 13.3 — — Total Other Revenues 86.6 (82.3) (11.9) 5.4 62.9 1.5 0.5 Total Revenues $ 1,257.1 $ 837.8 $ 2,122.6 $ 1,703.6 $ 2,071.7 $ 988.1 $ 1,318.2 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $85 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $715 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $49 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 September 30, 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 $ 314.9 $ 199.3 $ 160.3 $ 161.5 $ 836.0 AEP Texas 132.7 — — — 132.7 AEPTCo 331.7 — — — 331.7 APCo 44.9 34.5 26.6 11.6 117.6 I&M 10.0 11.5 8.8 4.5 34.8 OPCo 22.2 10.1 — — 32.3 PSO 3.5 — — — 3.5 SWEPCo 10.1 — — — 10.1 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 September 30, 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 September 30, 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 September 30, 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 September 30, 2021 December 31, 2020 (in millions) AEPTCo $ 96.4 $ 81.0 APCo 64.1 52.7 I&M 24.6 34.8 OPCo 44.5 45.9 PSO 17.7 7.8 SWEPCo 19.9 11.2

Subsequent Events

Subsequent Events	9 Months Ended
	Sep. 30, 2021
Subsequent Events [Text Block]	SUBSEQUENT EVENTS The disclosure in this note applies to AEP and AEPTCo. Disposition of KPCo and KTCo In October 2021, AEP entered into a Stock Purchase Agreement to sell KPCo and KTCo to Liberty Utilities Co., a subsidiary of Algonquin Power & Utilities Corp. (Liberty), for approximately a $2.85 billion enterprise value. The sale is subject to regulatory approvals from the FERC, the KPSC, clearance under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, and clearance from the Committee on Foreign Investment in the United States. KPCo currently operates and owns a 50% interest in the 1,560 MW coal-fired Mitchell Power Plant (Mitchell Plant) with the remaining 50% owned by WPCo. The Stock Purchase Agreement is further contingent upon approval by the KPSC, WVPSC and FERC of a new proposed Mitchell Plant Operations and Maintenance Agreement and Mitchell Plant Ownership Agreement between KPCo and WPCo pursuant to which WPCo will replace KPCo as the operator of the Mitchell Plant and KPCo employees at the Mitchell Plant will become employees of WPCo at closing of the transaction. Under the proposed Ownership Agreement, WPCo is obligated to purchase KPCo’s 50% interest in the Mitchell Plant on December 31, 2028 unless KPCo and WPCo have agreed to retire the Mitchell Plant earlier or, absent such agreement, if WPCo elects prior to December 31, 2027 to retire the Mitchell Plant on December 31, 2028. The Ownership Agreement provides that the purchase price for KPCo’s 50% ownership interest in the Mitchell Plant will be determined through the mutual agreement of WPCo and KPCo (subject to approval from the KPSC and WVPSC) or through a fair market valuation determination conducted by independent appraisals if KPCo and WPCo are unable to reach agreement as to the purchase price. The sale is expected to close in the second quarter of 2022 with Liberty acquiring the assets and assuming the liabilities of KPCo and KTCo, excluding pension and other post-retirement benefit plan assets and liabilities. AEP expects to provide customary transition services to Liberty for a period of time after closing of the transaction. AEP expects to receive approximately $1.45 billion in cash, net of taxes and transaction fees. The major classes of KPCo and KTCo’s assets and liabilities as presented on the balance sheets of AEP and AEPTCo as of September 30, 2021 are shown in the table below. September 30, 2021 AEP AEPTCo (in millions) Assets: Accounts Receivable and Accrued Unbilled Revenues $ 24.7 $ 1.6 Fuel, Materials and Supplies 26.5 — Property, Plant and Equipment, Net 2,264.6 164.5 Regulatory Assets 501.7 — Other Classes of Assets that are not Major 43.8 0.3 Total Assets $ 2,861.3 $ 166.4 Liabilities: Accounts Payable $ 51.2 $ 1.5 Long-term Debt Due Within One Year 125.0 — Customer Deposits 31.9 — Deferred Income Taxes 448.3 14.9 Long-term Debt 978.0 — Regulatory Liabilities and Deferred Investment Tax Credits 146.5 7.5 Other Classes of Liabilities that are not Major 93.2 4.2 Total Liabilities $ 1,874.1 $ 28.1

Significant Accounting Matters

Significant Accounting Matters (Policies)	9 Months Ended
	Sep. 30, 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 and nine months ended September 30, 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)	9 Months Ended
	Sep. 30, 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 line item on the statements of income as that of the associated risk being hedged. However, unrealized and some realized gains and losses in regulated jurisdictions for both trading and non-trading derivative instruments are recorded as regulatory assets (for losses) or regulatory liabilities (for gains) in accordance with the accounting guidance for “Regulated Operations.” Accounting for Fair Value Hedging Strategies (Applies to AEP) For fair value hedges (i.e. hedging the exposure to changes in the fair value of an asset, liability or an identified portion thereof attributable to a particular risk), the gain or loss on the derivative instrument as well as the offsetting gain or loss on the hedged item associated with the hedged risk impacts net income during the period of change. AEP records realized and unrealized gains or losses on interest rate swaps that are designated and qualify for fair value hedge accounting treatment and any offsetting changes in the fair value of the debt being hedged in Interest Expense on the statements of income. Accounting for Cash Flow Hedging Strategies 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)	9 Months Ended
	Sep. 30, 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)	9 Months Ended
	Sep. 30, 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.

Property, Plant and Equipment (

Property, Plant and Equipment (Policies)	9 Months Ended
	Sep. 30, 2021
Asset Retirement Obligations	The Registrants record ARO in accordance with the accounting guidance for “Asset Retirement and Environmental Obligations” for legal obligations for asbestos removal and for the retirement of certain ash disposal facilities, wind farms, solar farms and certain coal mining facilities. The discussion below summarizes significant changes to the Registrants ARO recorded in 2021 and should be read in conjunction with the Property, Plant and Equipment note within the 2020 Annual Report.

Significant Accounting Matter_2

Significant Accounting Matters (Tables)	9 Months Ended
	Sep. 30, 2021
Earnings Per Share	Three Months Ended September 30, 2021 2020 (in millions, except per share data) $/share $/share Earnings Attributable to AEP Common Shareholders $ 796.0 $ 748.6 Weighted-Average Number of Basic AEP Common Shares Outstanding 501.2 $ 1.59 496.2 $ 1.51 Weighted-Average Dilutive Effect of Stock-Based Awards 1.4 (0.01) 1.3 (0.01) Weighted-Average Number of Diluted AEP Common Shares Outstanding 502.6 $ 1.58 497.5 $ 1.50 Nine Months Ended September 30, 2021 2020 (in millions, except per share data) $/share $/share Earnings Attributable to AEP Common Shareholders $ 1,949.2 $ 1,764.6 Weighted-Average Number of Basic AEP Common Shares Outstanding 499.4 $ 3.90 495.5 $ 3.56 Weighted-Average Dilutive Effect of Stock-Based Awards 1.2 (0.01) 1.4 (0.01) Weighted-Average Number of Diluted AEP Common Shares Outstanding 500.6 $ 3.89 496.9 $ 3.55
Supplementary Information	September 30, 2021 AEP AEP Texas APCo (in millions) Cash and Cash Equivalents $ 1,372.7 $ 0.1 $ 5.0 Restricted Cash 54.0 43.9 10.1 Total Cash, Cash Equivalents and Restricted Cash $ 1,426.7 $ 44.0 $ 15.1 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)	9 Months Ended
	Sep. 30, 2021
Changes in Accumulated Other Comprehensive Income (Loss) by Component	AEP Cash Flow Hedges Pension Three Months Ended September 30, 2021 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2021 $ 110.3 $ (32.2) $ 18.9 $ 97.0 Change in Fair Value Recognized in AOCI 220.8 4.9 (a) — 225.7 Amount of (Gain) Loss Reclassified from AOCI Purchased Electricity for Resale (b) (59.7) — — (59.7) 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 (59.7) 1.5 (2.5) (60.7) Income Tax (Expense) Benefit (12.5) 0.3 (0.5) (12.7) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (47.2) 1.2 (2.0) (48.0) Net Current Period Other Comprehensive Income (Loss) 173.6 6.1 (2.0) 177.7 Balance in AOCI as of September 30, 2021 $ 283.9 $ (26.1) $ 16.9 $ 274.7 Cash Flow Hedges Pension Three Months Ended September 30, 2020 Commodity Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2020 $ (81.4) $ (55.3) $ (36.2) $ (172.9) Change in Fair Value Recognized in AOCI 10.2 1.9 (a) — 12.1 Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (b) (0.1) — — (0.1) Purchased Electricity for Resale (b) 33.3 — — 33.3 Interest Expense (b) — 1.3 — 1.3 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 33.2 1.3 (2.3) 32.2 Income Tax (Expense) Benefit 7.1 0.2 (0.5) 6.8 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 26.1 1.1 (1.8) 25.4 Net Current Period Other Comprehensive Income (Loss) 36.3 3.0 (1.8) 37.5 Balance in AOCI as of September 30, 2020 $ (45.1) $ (52.3) $ (38.0) $ (135.4) AEP Cash Flow Hedges Pension Nine Months Ended September 30, 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 534.5 17.6 (a) — 552.1 Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (b) 0.7 — — 0.7 Purchased Electricity for Resale (b) (241.2) — — (241.2) Interest Expense (b) — 4.8 — 4.8 Amortization of Prior Service Cost (Credit) — — (14.5) (14.5) Amortization of Actuarial (Gains) Losses — — 6.8 6.8 Reclassifications from AOCI, before Income Tax (Expense) Benefit (240.5) 4.8 (7.7) (243.4) Income Tax (Expense) Benefit (50.5) 1.0 (1.6) (51.1) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (190.0) 3.8 (6.1) (192.3) Net Current Period Other Comprehensive Income (Loss) 344.5 21.4 (6.1) 359.8 Balance in AOCI as of September 30, 2021 $ 283.9 $ (26.1) $ 16.9 $ 274.7 Cash Flow Hedges Pension Nine Months Ended September 30, 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 (48.6) (43.6) (a) — (92.2) Amount of (Gain) Loss Reclassified from AOCI Generation & Marketing Revenues (b) (0.3) — — (0.3) Purchased Electricity for Resale (b) 135.7 — — 135.7 Interest Expense (b) — 3.6 — 3.6 Amortization of Prior Service Cost (Credit) — — (14.4) (14.4) Amortization of Actuarial (Gains) Losses — — 7.7 7.7 Reclassifications from AOCI, before Income Tax (Expense) Benefit 135.4 3.6 (6.7) 132.3 Income Tax (Expense) Benefit 28.4 0.8 (1.4) 27.8 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 107.0 2.8 (5.3) 104.5 Net Current Period Other Comprehensive Income (Loss) 58.4 (40.8) (5.3) 12.3 Balance in AOCI as of September 30, 2020 $ (45.1) $ (52.3) $ (38.0) $ (135.4) AEP Texas Cash Flow Hedge – Pension Three Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2021 $ (1.8) $ (6.5) $ (8.3) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.4 — 0.4 Amortization of Prior Service Cost (Credit) — (0.1) (0.1) Amortization of Actuarial (Gains) Losses — 0.1 0.1 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 September 30, 2021 $ (1.5) $ (6.5) $ (8.0) Cash Flow Hedge – Pension Three Months Ended September 30, 2020 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2020 $ (2.9) $ (9.3) $ (12.2) Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.4 — 0.4 Amortization of Prior Service Cost (Credit) — (0.1) (0.1) Amortization of Actuarial (Gains) Losses — 0.1 0.1 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 September 30, 2020 $ (2.6) $ (9.3) $ (11.9) AEP Texas Cash Flow Hedge – Pension Nine Months Ended September 30, 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 — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 1.0 — 1.0 Amortization of Prior Service Cost (Credit) — (0.1) (0.1) Amortization of Actuarial (Gains) Losses — 0.2 0.2 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.0 0.1 1.1 Income Tax (Expense) Benefit 0.2 — 0.2 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.8 0.1 0.9 Net Current Period Other Comprehensive Income (Loss) 0.8 0.1 0.9 Balance in AOCI as of September 30, 2021 $ (1.5) $ (6.5) $ (8.0) Cash Flow Hedge – Pension Nine Months Ended September 30, 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) 1.0 — 1.0 Amortization of Prior Service Cost (Credit) — (0.1) (0.1) Amortization of Actuarial (Gains) Losses — 0.2 0.2 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.0 0.1 1.1 Income Tax (Expense) Benefit 0.2 — 0.2 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.8 0.1 0.9 Net Current Period Other Comprehensive Income (Loss) 0.8 0.1 0.9 Balance in AOCI as of September 30, 2020 $ (2.6) $ (9.3) $ (11.9) APCo Cash Flow Hedge – Pension Three Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2021 $ 8.0 $ 5.9 $ 13.9 Change in Fair Value Recognized in AOCI 0.2 — 0.2 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (0.6) — (0.6) Amortization of Prior Service Cost (Credit) — (1.2) (1.2) Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.6) (1.2) (1.8) Income Tax (Expense) Benefit (0.1) (0.2) (0.3) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.5) (1.0) (1.5) Net Current Period Other Comprehensive Income (Loss) (0.3) (1.0) (1.3) Balance in AOCI as of September 30, 2021 $ 7.7 $ 4.9 $ 12.6 Cash Flow Hedge – Pension Three Months Ended September 30, 2020 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2020 $ (4.1) $ 2.2 $ (1.9) Change in Fair Value Recognized in AOCI 0.7 — 0.7 Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (0.2) — (0.2) 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 (0.2) (1.2) (1.4) Income Tax (Expense) Benefit (0.1) (0.3) (0.4) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.1) (0.9) (1.0) Net Current Period Other Comprehensive Income (Loss) 0.6 (0.9) (0.3) Balance in AOCI as of September 30, 2020 $ (3.5) $ 1.3 $ (2.2) APCo Cash Flow Hedge – Pension Nine Months Ended September 30, 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) (1.0) — (1.0) Amortization of Prior Service Cost (Credit) — (3.9) (3.9) Reclassifications from AOCI, before Income Tax (Expense) Benefit (1.0) (3.9) (4.9) Income Tax (Expense) Benefit (0.2) (0.8) (1.0) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.8) (3.1) (3.9) Net Current Period Other Comprehensive Income (Loss) 8.5 (3.1) 5.4 Balance in AOCI as of September 30, 2021 $ 7.7 $ 4.9 $ 12.6 Cash Flow Hedge – Pension Nine Months Ended September 30, 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 (3.8) — (3.8) Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) (0.8) — (0.8) Amortization of Prior Service Cost (Credit) — (4.0) (4.0) Amortization of Actuarial (Gains) Losses — 0.4 0.4 Reclassifications from AOCI, before Income Tax (Expense) Benefit (0.8) (3.6) (4.4) Income Tax (Expense) Benefit (0.2) (0.8) (1.0) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.6) (2.8) (3.4) Net Current Period Other Comprehensive Income (Loss) (4.4) (2.8) (7.2) Balance in AOCI as of September 30, 2020 $ (3.5) $ 1.3 $ (2.2) I&M Cash Flow Hedge – Pension Three Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2021 $ (7.4) $ 1.2 $ (6.2) 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 September 30, 2021 $ (7.0) $ 1.2 $ (5.8) Cash Flow Hedge – Pension Three Months Ended September 30, 2020 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2020 $ (9.1) $ (1.7) $ (10.8) 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) — (0.3) (0.3) Amortization of Actuarial (Gains) Losses — 0.2 0.2 Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.5 (0.1) 0.4 Income Tax (Expense) Benefit 0.1 — 0.1 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.4 (0.1) 0.3 Net Current Period Other Comprehensive Income (Loss) 0.4 (0.1) 0.3 Balance in AOCI as of September 30, 2020 $ (8.7) $ (1.8) $ (10.5) I&M Cash Flow Hedge – Pension Nine Months Ended September 30, 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) 1.6 — 1.6 Amortization of Prior Service Cost (Credit) — (0.6) (0.6) Amortization of Actuarial (Gains) Losses — 0.5 0.5 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.6 (0.1) 1.5 Income Tax (Expense) Benefit 0.3 — 0.3 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.3 (0.1) 1.2 Net Current Period Other Comprehensive Income (Loss) 1.3 (0.1) 1.2 Balance in AOCI as of September 30, 2021 $ (7.0) $ 1.2 $ (5.8) Cash Flow Hedge – Pension Nine Months Ended September 30, 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) 1.5 — 1.5 Amortization of Prior Service Cost (Credit) — (0.6) (0.6) Amortization of Actuarial (Gains) Losses — 0.5 0.5 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.5 (0.1) 1.4 Income Tax (Expense) Benefit 0.3 — 0.3 Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.2 (0.1) 1.1 Net Current Period Other Comprehensive Income (Loss) 1.2 (0.1) 1.1 Balance in AOCI as of September 30, 2020 $ (8.7) $ (1.8) $ (10.5) PSO Cash Flow Hedge – Three Months Ended September 30, 2021 Interest Rate (in millions) Balance in AOCI as of June 30, 2021 $ — 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 September 30, 2021 $ — Cash Flow Hedge – Three Months Ended September 30, 2020 Interest Rate (in millions) Balance in AOCI as of June 30, 2020 $ 0.6 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 — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.3) Net Current Period Other Comprehensive Income (Loss) (0.3) Balance in AOCI as of September 30, 2020 $ 0.3 Cash Flow Hedge – Nine Months Ended September 30, 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 September 30, 2021 $ — Cash Flow Hedge – Nine Months Ended September 30, 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) (1.0) Reclassifications from AOCI, before Income Tax (Expense) Benefit (1.0) Income Tax (Expense) Benefit (0.2) Reclassifications from AOCI, Net of Income Tax (Expense) Benefit (0.8) Net Current Period Other Comprehensive Income (Loss) (0.8) Balance in AOCI as of September 30, 2020 $ 0.3 SWEPCo Cash Flow Hedge – Pension Three Months Ended September 30, 2021 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2021 $ 0.5 $ 1.4 $ 1.9 Change in Fair Value Recognized in AOCI — — — Amount of (Gain) Loss Reclassified from AOCI Interest Expense (b) 0.4 — 0.4 Amortization of Prior Service Cost (Credit) — (0.5) (0.5) Reclassifications from AOCI, before Income Tax (Expense) Benefit 0.4 (0.5) (0.1) Income Tax (Expense) Benefit 0.1 (0.1) — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 0.3 (0.4) (0.1) Net Current Period Other Comprehensive Income (Loss) 0.3 (0.4) (0.1) Balance in AOCI as of September 30, 2021 $ 0.8 $ 1.0 $ 1.8 Cash Flow Hedge – Pension Three Months Ended September 30, 2020 Interest Rate and OPEB Total (in millions) Balance in AOCI as of June 30, 2020 $ (1.1) $ (0.2) $ (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) Amortization of Actuarial (Gains) Losses — — — 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 September 30, 2020 $ (0.7) $ (0.6) $ (1.3) SWEPCo Cash Flow Hedge – Pension Nine Months Ended September 30, 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) 1.4 — 1.4 Amortization of Prior Service Cost (Credit) — (1.5) (1.5) Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.4 (1.5) (0.1) Income Tax (Expense) Benefit 0.3 (0.3) — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.1 (1.2) (0.1) Net Current Period Other Comprehensive Income (Loss) 1.1 (1.2) (0.1) Balance in AOCI as of September 30, 2021 $ 0.8 $ 1.0 $ 1.8 Cash Flow Hedge – Pension Nine Months Ended September 30, 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) 1.4 — 1.4 Amortization of Prior Service Cost (Credit) — (1.5) (1.5) Amortization of Actuarial (Gains) Losses — 0.1 0.1 Reclassifications from AOCI, before Income Tax (Expense) Benefit 1.4 (1.4) — Income Tax (Expense) Benefit 0.3 (0.3) — Reclassifications from AOCI, Net of Income Tax (Expense) Benefit 1.1 (1.1) — Net Current Period Other Comprehensive Income (Loss) 1.1 (1.1) — Balance in AOCI as of September 30, 2020 $ (0.7) $ (0.6) $ (1.3) (a) The change in fair value includes $(1) million and $(1) million, respectively, for the three months ended September 30, 2021 and 2020 and $(5) million and $6 million, respectively, for the nine months ended September 30, 2021 and 2020 related to AEP's investment in joint venture wind farms acquired as part of the purchase of Sempra Renewables LLC. (b) Amounts reclassified to the referenced line item on the statements of income.

Rate Matters (Tables)

Rate Matters (Tables)	9 Months Ended
	Sep. 30, 2021
Regulated Generating Units to be Retired	Plant Net Book Value Accelerated Depreciation Regulatory Asset Cost of Removal Projected Current Authorized Annual (dollars in millions) Northeastern Plant, Unit 3 $ 175.1 $ 123.6 $ 20.0 (b) 2026 (c) $ 14.9 Dolet Hills Power Station 13.0 126.8 24.4 2021 (d) 7.8 Pirkey Power Plant 135.4 68.0 39.2 2023 (e) 13.5 Welsh Plant, Units 1 and 3 493.7 35.6 58.2 (f) 2028 (g) 33.1 (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 September 30, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Unrecovered Winter Storm Fuel Costs (a) $ 1,106.3 $ — Dolet Hills Power Station Accelerated Depreciation 126.8 71.2 Pirkey Power Plant Accelerated Depreciation 68.0 12.2 Kentucky Deferred Purchase Power Expenses 45.9 41.3 Welsh Plant, Units 1 and 3 Accelerated Depreciation 35.6 3.6 Plant Retirement Costs – Unrecovered Plant, Louisiana 35.2 35.2 Oklaunion Power Station Accelerated Depreciation 33.0 34.4 Dolet Hills Power Station Fuel Costs - Louisiana 20.3 — Other Regulatory Assets Pending Final Regulatory Approval 25.5 22.8 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 325.8 134.2 Plant Retirement Costs – Asset Retirement Obligation Costs 25.9 25.9 COVID-19 14.0 24.9 Asset Retirement Obligation - Louisiana 10.0 9.1 Other Regulatory Assets Pending Final Regulatory Approval 32.6 27.4 Total Regulatory Assets Pending Final Regulatory Approval $ 1,904.9 $ 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 September 30, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Advanced Metering System $ 16.6 $ 16.3 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 22.7 0.8 Vegetation Management Program 5.2 3.8 Texas Retail Electric Provider Bad Debt Expense 4.1 — COVID-19 3.9 10.5 Other Regulatory Assets Pending Final Regulatory Approval 5.3 1.5 Total Regulatory Assets Pending Final Regulatory Approval $ 57.8 $ 32.9 APCo September 30, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return COVID-19 – Virginia $ 6.6 $ 3.7 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 59.8 3.4 Plant Retirement Costs – Asset Retirement Obligation Costs 25.9 25.9 COVID-19 – West Virginia 0.4 1.5 Environmental Expense Deferral - Virginia — 9.3 Other Regulatory Assets Pending Final Regulatory Approval 1.2 — Total Regulatory Assets Pending Final Regulatory Approval $ 93.9 $ 43.8 I&M September 30, 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 1.7 3.8 Other Regulatory Assets Pending Final Regulatory Approval 1.7 — Total Regulatory Assets Pending Final Regulatory Approval $ 3.4 $ 4.3 OPCo September 30, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Not Earning a Return Storm-Related Costs $ 5.5 $ 4.0 COVID-19 1.9 4.4 Other Regulatory Assets Pending Final Regulatory Approval 0.1 — Total Regulatory Assets Pending Final Regulatory Approval $ 7.5 $ 8.4 PSO September 30, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Unrecovered Winter Storm Fuel Costs (a) $ 673.2 $ — Oklaunion Power Station Accelerated Depreciation 33.0 34.4 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 29.3 15.8 Other Regulatory Assets Pending Final Regulatory Approval 0.9 0.3 Total Regulatory Assets Pending Final Regulatory Approval $ 736.4 $ 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 September 30, December 31, 2021 2020 Noncurrent Regulatory Assets (in millions) Regulatory Assets Currently Earning a Return Unrecovered Winter Storm Fuel Costs (a) $ 433.1 $ — Dolet Hills Power Station Accelerated Depreciation 126.8 71.2 Pirkey Power Plant Accelerated Depreciation 68.0 12.2 Welsh Plant, Units 1 and 3 Accelerated Depreciation 35.6 3.6 Plant Retirement Costs – Unrecovered Plant, Louisiana 35.2 35.2 Dolet Hills Power Station Fuel Costs- Louisiana 20.3 — Other Regulatory Assets Pending Final Regulatory Approval 2.3 2.2 Regulatory Assets Currently Not Earning a Return Storm-Related Costs 155.4 99.3 Asset Retirement Obligation - Louisiana 10.0 9.1 Other Regulatory Assets Pending Final Regulatory Approval 19.3 14.5 Total Regulatory Assets Pending Final Regulatory Approval $ 906.0 $ 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	September 30, 2021 Company Jurisdiction Capital O&M Regulatory Asset Total (in millions) APCo Virginia $ 8.1 $ 2.2 $ 6.6 $ 16.9 APCo West Virginia 23.5 — 47.0 70.5 SWEPCo Louisiana 6.0 — 45.4 51.4 KPCo Kentucky 29.0 5.0 42.6 76.6 Total $ 66.6 $ 7.2 $ 141.6 $ 215.4
February 2021 Winter Storm Fuel Costs	PSO SWEPCo Total (in millions) Retail Customers (a) $ 673.2 $ 433.1 (b) $ 1,106.3 Wholesale Customers — 55.8 55.8 Total $ 673.2 $ 488.9 $ 1,162.1 (a) These costs were deferred as regulatory assets as of September 30, 2021.

Commitments, Guarantees and C_2

Commitments, Guarantees and Contingencies (Tables)	9 Months Ended
	Sep. 30, 2021
Maximum Future Payments for Letters of Credit Uncommitted Facilities	Company Amount Maturity (in millions) AEP $ 179.5 October 2021 to August 2022 AEP Texas 2.2 July 2022
Max Potential Loss on Master Lease Agreements	Company Maximum (in millions) AEP $ 47.8 AEP Texas 11.1 APCo 6.2 I&M 4.1 OPCo 7.6 PSO 4.7 SWEPCo 5.2
Future Minimum Lease Payments for Sale and Leaseback	Future Minimum Lease Payments AEP (a) I&M (in millions) 2021 $ 74.0 $ 37.0 2022 147.6 73.8 Total Future Minimum Lease Payments $ 221.6 $ 110.8 (a) AEP’s future minimum lease payments include equal shares from AEGCo and I&M.

Benefit Plans (Tables)

Benefit Plans (Tables)	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
Components of Net Periodic Benefit Cost	AEP Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 32.3 $ 28.0 $ 2.4 $ 2.5 Interest Cost 34.3 42.0 7.7 10.0 Expected Return on Plan Assets (57.4) (66.3) (22.8) (23.9) Amortization of Prior Service Credit — — (17.8) (17.4) Amortization of Net Actuarial Loss 25.3 23.5 — 1.4 Net Periodic Benefit Cost (Credit) $ 34.5 $ 27.2 $ (30.5) $ (27.4) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 96.9 $ 84.0 $ 7.2 $ 7.5 Interest Cost 102.9 125.9 22.9 29.9 Expected Return on Plan Assets (172.3) (198.7) (68.4) (71.8) Amortization of Prior Service Credit — — (53.2) (52.3) Amortization of Net Actuarial Loss 76.1 70.3 — 4.4 Net Periodic Benefit Cost (Credit) $ 103.6 $ 81.5 $ (91.5) $ (82.3) AEP Texas Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 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) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 8.9 $ 7.6 $ 0.5 $ 0.6 Interest Cost 8.4 10.5 1.8 2.4 Expected Return on Plan Assets (14.6) (17.1) (5.6) (6.0) Amortization of Prior Service Credit — — (4.5) (4.4) Amortization of Net Actuarial Loss 6.2 5.8 — 0.4 Net Periodic Benefit Cost (Credit) $ 8.9 $ 6.8 $ (7.8) $ (7.0) APCo Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 3.0 $ 2.7 $ 0.3 $ 0.3 Interest Cost 4.1 5.0 1.3 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 $ (4.4) $ (4.0) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 8.9 $ 7.9 $ 0.8 $ 0.8 Interest Cost 12.3 15.2 3.7 4.9 Expected Return on Plan Assets (21.8) (25.2) (10.1) (10.9) Amortization of Prior Service Credit — — (7.8) (7.6) Amortization of Net Actuarial Loss 9.0 8.4 — 0.7 Net Periodic Benefit Cost (Credit) $ 8.4 $ 6.3 $ (13.4) $ (12.1) I&M Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 4.4 $ 3.9 $ 0.4 $ 0.4 Interest Cost 4.0 4.9 0.8 1.2 Expected Return on Plan Assets (7.2) (8.3) (2.7) (3.0) Amortization of Prior Service Credit — — (2.5) (2.3) Amortization of Net Actuarial Loss 2.9 2.7 — 0.1 Net Periodic Benefit Cost (Credit) $ 4.1 $ 3.2 $ (4.0) $ (3.6) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 13.1 $ 11.6 $ 1.0 $ 1.1 Interest Cost 12.1 14.7 2.6 3.5 Expected Return on Plan Assets (21.6) (24.9) (8.3) (8.8) Amortization of Prior Service Credit — — (7.3) (7.1) Amortization of Net Actuarial Loss 8.8 8.1 — 0.5 Net Periodic Benefit Cost (Credit) $ 12.4 $ 9.5 $ (12.0) $ (10.8) OPCo Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 2.9 $ 2.4 $ 0.2 $ 0.2 Interest Cost 3.1 3.9 0.7 1.0 Expected Return on Plan Assets (5.7) (6.6) (2.4) (2.6) Amortization of Prior Service Credit — — (1.7) (1.8) Amortization of Net Actuarial Loss 2.3 2.1 — 0.2 Net Periodic Benefit Cost (Credit) $ 2.6 $ 1.8 $ (3.2) $ (3.0) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 8.6 $ 7.2 $ 0.6 $ 0.7 Interest Cost 9.3 11.6 2.3 3.1 Expected Return on Plan Assets (16.8) (19.7) (7.3) (7.9) Amortization of Prior Service Credit — — (5.3) (5.3) Amortization of Net Actuarial Loss 6.8 6.4 — 0.5 Net Periodic Benefit Cost (Credit) $ 7.9 $ 5.5 $ (9.7) $ (8.9) PSO Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 2.0 $ 1.9 $ 0.1 $ 0.1 Interest Cost 1.7 2.1 0.4 0.6 Expected Return on Plan Assets (3.0) (3.6) (1.3) (1.3) Amortization of Prior Service Credit — — (1.1) (1.0) Amortization of Net Actuarial Loss 1.2 1.1 — — Net Periodic Benefit Cost (Credit) $ 1.9 $ 1.5 $ (1.9) $ (1.6) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 6.0 $ 5.5 $ 0.4 $ 0.4 Interest Cost 5.0 6.4 1.2 1.6 Expected Return on Plan Assets (9.2) (10.9) (3.8) (3.9) Amortization of Prior Service Credit — — (3.3) (3.2) Amortization of Net Actuarial Loss 3.7 3.5 — 0.2 Net Periodic Benefit Cost (Credit) $ 5.5 $ 4.5 $ (5.5) $ (4.9) SWEPCo Pension Plans OPEB Three Months Ended September 30, Three Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 2.7 $ 2.6 $ 0.3 $ 0.2 Interest Cost 2.2 2.5 0.4 0.6 Expected Return on Plan Assets (3.3) (3.9) (1.5) (1.5) Amortization of Prior Service Credit — — (1.4) (1.3) Amortization of Net Actuarial Loss 1.5 1.4 — 0.1 Net Periodic Benefit Cost (Credit) $ 3.1 $ 2.6 $ (2.2) $ (1.9) Pension Plans OPEB Nine Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 (in millions) Service Cost $ 8.4 $ 7.5 $ 0.6 $ 0.6 Interest Cost 6.4 7.6 1.4 1.9 Expected Return on Plan Assets (10.1) (11.7) (4.5) (4.7) Amortization of Prior Service Credit — — (4.0) (3.9) Amortization of Net Actuarial Loss 4.6 4.2 — 0.3 Net Periodic Benefit Cost (Credit) $ 9.3 $ 7.6 $ (6.5) $ (5.8)
Qualified Pension Contribution		Company Qualified Pension Plan (in millions) AEP $ 110.3 AEP Texas 11.3 APCo 7.0 I&M 6.4 OPCo 0.1 SWEPCo 8.9

Business Segments (Tables)

Business Segments (Tables)	9 Months Ended
	Sep. 30, 2021
Segment Reporting Information [Line Items]
Reportable Segment Information	Three Months Ended September 30, 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 $ 2,716.8 $ 1,195.0 $ 90.3 $ 617.4 $ 3.5 $ — $ 4,623.0 Other Operating Segments 42.5 5.3 301.3 3.7 23.2 (376.0) — Total Revenues $ 2,759.3 $ 1,200.3 $ 391.6 $ 621.1 $ 26.7 $ (376.0) $ 4,623.0 Net Income (Loss) $ 438.7 $ 155.9 $ 167.9 $ 99.5 $ (65.1) $ — $ 796.9 Three Months Ended September 30, 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 $ 2,400.1 $ 1,124.1 $ 73.4 $ 464.8 $ 4.0 $ — $ 4,066.4 Other Operating Segments 34.7 41.2 244.5 25.2 28.6 (374.2) — Total Revenues $ 2,434.8 $ 1,165.3 $ 317.9 $ 490.0 $ 32.6 $ (374.2) $ 4,066.4 Net Income (Loss) $ 394.2 $ 147.4 $ 139.3 $ 114.6 $ (47.3) $ — $ 748.2 Nine Months Ended September 30, 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 $ 7,445.9 $ 3,366.9 $ 264.6 $ 1,641.6 $ 11.6 $ — $ 12,730.6 Other Operating Segments 111.3 24.9 882.2 50.3 43.5 (1,112.2) — Total Revenues $ 7,557.2 $ 3,391.8 $ 1,146.8 $ 1,691.9 $ 55.1 $ (1,112.2) $ 12,730.6 Net Income (Loss) $ 938.9 $ 424.0 $ 510.7 $ 184.2 $ (108.3) $ — $ 1,949.5 Nine Months Ended September 30, 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 $ 6,655.4 $ 3,208.7 $ 215.7 $ 1,223.4 $ 4.7 $ — $ 11,307.9 Other Operating Segments 98.1 98.0 662.1 82.1 67.3 (1,007.6) — Total Revenues $ 6,753.5 $ 3,306.7 $ 877.8 $ 1,305.5 $ 72.0 $ (1,007.6) $ 11,307.9 Net Income (Loss) $ 896.8 $ 403.1 $ 373.1 $ 203.6 $ (114.6) $ — $ 1,762.0 September 30, 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 $ 50,990.6 $ 22,171.7 $ 12,865.6 $ 2,125.8 $ 414.5 $ — $ 88,568.2 Accumulated Depreciation and Amortization 16,647.1 4,059.9 758.1 222.8 189.1 — 21,877.0 Total Property Plant and Equipment - Net $ 34,343.5 $ 18,111.8 $ 12,107.5 $ 1,903.0 $ 225.4 $ — $ 66,691.2 Total Assets $ 45,775.5 $ 21,053.1 $ 13,287.6 $ 4,387.6 $ 6,421.4 (b) $ (4,588.1) (c) $ 86,337.1 Long-term Debt Due Within One Year: Nonaffiliated $ 1,243.0 $ 815.2 $ 52.4 $ — $ 411.2 (d) $ — $ 2,521.8 Long-term Debt: Affiliated 65.0 — — — — (65.0) — Nonaffiliated 13,616.0 7,869.0 4,544.2 — 6,027.3 (d) — 32,056.5 Total Long-term Debt $ 14,924.0 $ 8,684.2 $ 4,596.6 $ — $ 6,438.5 (d) $ (65.0) $ 34,578.3 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 September 30, 2021 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Revenues from: External Customers $ 79.2 $ — $ — $ 79.2 Sales to AEP Affiliates 297.6 — — 297.6 Other Revenues 0.2 — — 0.2 Total Revenues $ 377.0 $ — $ — $ 377.0 Interest Income $ 0.1 $ 40.3 $ (40.2) (a) $ 0.2 Interest Expense 36.1 40.2 (40.2) (a) 36.1 Income Tax Expense 36.7 — — 36.7 Net Income $ 145.3 $ 0.1 (b) $ — $ 145.4 Three Months Ended September 30, 2020 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Revenues from: External Customers $ 62.9 $ — $ — $ 62.9 Sales to AEP Affiliates 241.2 — — 241.2 Total Revenues $ 304.1 $ — $ — $ 304.1 Interest Income $ — $ 38.4 $ (38.2) (a) $ 0.2 Interest Expense 32.7 38.2 (38.2) (a) 32.7 Income Tax Expense 31.7 — — 31.7 Net Income $ 117.5 $ 0.1 (b) $ — $ 117.6 Nine Months Ended September 30, 2021 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo Consolidated (in millions) Revenues from: External Customers $ 239.3 $ — $ — $ 239.3 Sales to AEP Affiliates 864.6 — — 864.6 Other Revenues 0.3 — — 0.3 Total Revenues $ 1,104.2 $ — $ — $ 1,104.2 Interest Income $ 0.1 $ 117.0 $ (116.7) (a) $ 0.4 Interest Expense 104.5 116.6 (116.6) (a) 104.5 Income Tax Expense 115.4 — — 115.4 Net Income $ 445.5 $ 0.2 (b) $ — $ 445.7 Nine Months Ended September 30, 2020 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo Consolidated (in millions) Revenues from: External Customers $ 184.6 $ — $ — $ 184.6 Sales to AEP Affiliates 652.6 — — 652.6 Other Revenues 0.6 — — 0.6 Total Revenues $ 837.8 $ — $ — $ 837.8 Interest Income $ 0.9 $ 111.3 $ (109.9) (a) $ 2.3 Interest Expense 95.1 109.9 (109.9) (a) 95.1 Income Tax Expense 82.7 0.1 — 82.8 Net Income $ 308.0 $ 1.1 (b) $ — $ 309.1 September 30, 2021 State Transcos AEPTCo Parent Reconciling Adjustments AEPTCo (in millions) Total Transmission Property $ 12,359.3 $ — $ — $ 12,359.3 Accumulated Depreciation and Amortization 730.4 — — 730.4 Total Transmission Property – Net $ 11,628.9 $ — $ — $ 11,628.9 Notes Receivable - Affiliated $ — $ 4,343.5 $ (4,343.5) (c) $ — Total Assets $ 11,984.7 $ 4,445.3 (d) $ (4,498.9) (e) $ 11,931.1 Total Long-term Debt $ 4,440.0 $ 4,393.4 $ (4,440.0) (c) $ 4,393.4 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)	9 Months Ended
	Sep. 30, 2021
Notional Volume of Derivative Instruments	Notional Volume of Derivative Instruments September 30, 2021 Primary Risk Unit of AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Commodity: Power MWhs 341.9 — 55.4 23.1 2.8 18.7 5.4 Natural Gas MMBtus 28.1 — — — — — 5.2 Heating Oil and Gasoline Gallons 7.8 2.0 1.2 0.7 1.5 0.9 1.1 Interest Rate USD $ 116.5 $ — $ — $ — $ — $ — $ — Interest Rate on Long-term Debt USD $ 1,250.0 $ — $ — $ — $ — $ — $ — 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 $ — $ — $ — $ —
CashCollateralNettingTableTextBlock	September 30, 2021 December 31, 2020 Cash Collateral Cash Collateral Cash Collateral Cash Collateral Received Paid Received Paid Netted Against Netted Against Netted Against Netted Against Risk Management Risk Management Risk Management Risk Management Company Assets Liabilities Assets Liabilities (in millions) AEP $ 309.7 $ 38.3 $ 3.4 $ 6.8 APCo 0.6 10.7 0.4 — I&M 0.3 17.4 1.7 —
Fair Value of Derivative Instruments	AEP September 30, 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 $ 1,005.5 $ 321.1 $ 8.3 $ 1,334.9 $ (965.7) $ 369.2 Long-term Risk Management Assets 337.3 85.8 — 423.1 (144.8) 278.3 Total Assets 1,342.8 406.9 8.3 1,758.0 (1,110.5) 647.5 Current Risk Management Liabilities 834.5 33.1 — 867.6 (761.1) 106.5 Long-term Risk Management Liabilities 234.6 14.3 28.8 277.7 (78.1) 199.6 Total Liabilities 1,069.1 47.4 28.8 1,145.3 (839.2) 306.1 Total MTM Derivative Contract Net Assets (Liabilities) $ 273.7 $ 359.5 $ (20.5) $ 612.7 $ (271.3) $ 341.4 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 September 30, 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 0.1 (0.1) — Total Assets 0.9 (0.9) — Current Risk Management Liabilities — — — Long-term Risk Management Liabilities — — — Total Liabilities — — — Total MTM Derivative Contract Net Assets (Liabilities) $ 0.9 $ (0.9) $ — 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 September 30, 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 $ 95.7 $ (48.7) $ 47.0 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets 0.2 (0.2) — Total Assets 95.9 (48.9) 47.0 Other Current Liabilities - Current Risk Management Liabilities 60.2 (58.9) 1.3 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities 0.2 (0.2) — Total Liabilities 60.4 (59.1) 1.3 Total MTM Derivative Contract Net Assets $ 35.5 $ 10.2 $ 45.7 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 September 30, 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 $ 37.8 $ (32.3) $ 5.5 Deferred Charges and Other Noncurrent Assets - Long-term Risk Management Assets 0.1 (0.1) — Total Assets 37.9 (32.4) 5.5 Current Risk Management Liabilities 51.9 (49.4) 2.5 Deferred Credits and Other Noncurrent Liabilities - Long-term Risk Management Liabilities 0.1 (0.1) — Total Liabilities 52.0 (49.5) 2.5 Total MTM Derivative Contract Net Assets (Liabilities) $ (14.1) $ 17.1 $ 3.0 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 $ 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 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 September 30, 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 0.1 (0.1) — Total Assets 0.7 (0.7) — Current Risk Management Liabilities 3.5 — 3.5 Long-term Risk Management Liabilities 86.9 — 86.9 Total Liabilities 90.4 — 90.4 Total MTM Derivative Contract Net Liabilities $ (89.7) $ (0.7) $ (90.4) 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 $ 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 September 30, 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 $ 19.0 $ (0.5) $ 18.5 Long-term Risk Management Assets — — — Total Assets 19.0 (0.5) 18.5 Current Risk Management Liabilities 0.2 (0.2) — Long-term Risk Management Liabilities — — — Total Liabilities 0.2 (0.2) — Total MTM Derivative Contract Net Assets (Liabilities) $ 18.8 $ (0.3) $ 18.5 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 September 30, 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 $ 18.1 $ (0.6) $ 17.5 Long-term Risk Management Assets 2.1 — 2.1 Total Assets 20.2 (0.6) 19.6 Current Risk Management Liabilities 0.2 (0.2) — Long-term Risk Management Liabilities — — — Total Liabilities 0.2 (0.2) — Total MTM Derivative Contract Net Assets (Liabilities) $ 20.0 $ (0.4) $ 19.6 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 disclosed as gross. These instruments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with the accounting guidance for “Derivatives and Hedging.” (b) Amounts include counterparty netting of risk management and hedging contracts and associated cash collateral in accordance with the accounting guidance for “Derivatives and Hedging.” (c) All derivative contracts subject to a master netting arrangement or similar agreement are offset in the statement of financial position.
Amount of Gain (Loss) Recognized on Risk Management Contracts	Amount of Gain (Loss) Recognized on Risk Management Contracts Three Months Ended September 30, 2021 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ (0.9) $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 128.8 — — — — — — Electric Generation, Transmission and Distribution Revenues — — (0.9) — — — — Purchased Electricity for Resale 0.2 — 0.1 — — — — Other Operation 0.9 0.3 0.1 0.1 0.1 0.1 0.2 Maintenance 1.1 0.2 0.2 0.1 0.2 0.1 0.1 Regulatory Assets (a) (7.2) — (2.9) (16.9) 14.9 — 0.1 Regulatory Liabilities (a) 46.5 (0.1) 14.2 1.7 0.8 14.0 12.7 Total Gain (Loss) on Risk Management Contracts $ 169.4 $ 0.4 $ 10.8 $ (15.0) $ 16.0 $ 14.2 $ 13.1 Three Months Ended September 30, 2020 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 0.5 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 11.5 — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.3 — — — — Purchased Electricity for Resale 0.3 — 0.2 0.1 — — — Other Operation (0.4) (0.1) (0.1) (0.1) (0.1) (0.1) (0.1) Maintenance (0.8) (0.2) (0.1) (0.1) (0.2) — (0.1) Regulatory Assets (a) 7.9 0.2 0.4 0.2 4.4 (0.4) 2.9 Regulatory Liabilities (a) 17.0 — 3.8 2.6 1.7 3.1 2.0 Total Gain (Loss) on Risk Management Contracts $ 36.0 $ (0.1) $ 4.5 $ 2.7 $ 5.8 $ 2.6 $ 4.7 Nine Months Ended September 30, 2021 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ (0.6) $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 144.9 — — — — — — Electric Generation, Transmission and Distribution Revenues — — (0.6) — — — — Purchased Electricity for Resale 1.2 — 1.0 0.1 — — — Other Operation 1.9 0.6 0.2 0.2 0.3 0.2 0.3 Maintenance 2.4 0.6 0.4 0.2 0.4 0.2 0.3 Regulatory Assets (a) (7.8) — (2.9) (22.9) 20.3 — 1.4 Regulatory Liabilities (a) 123.6 0.5 28.9 1.9 5.9 40.2 38.5 Total Gain (Loss) on Risk Management Contracts $ 265.6 $ 1.7 $ 27.0 $ (20.5) $ 26.9 $ 40.6 $ 40.5 Nine Months Ended September 30, 2020 Location of Gain (Loss) AEP AEP Texas APCo I&M OPCo PSO SWEPCo (in millions) Vertically Integrated Utilities Revenues $ 0.8 $ — $ — $ — $ — $ — $ — Generation & Marketing Revenues 11.1 — — — — — — Electric Generation, Transmission and Distribution Revenues — — 0.4 0.1 — — 0.1 Purchased Electricity for Resale 1.2 — 1.0 0.1 — — — Other Operation (1.4) (0.4) (0.2) (0.2) (0.3) (0.2) (0.2) Maintenance (2.2) (0.6) (0.3) (0.2) (0.4) (0.2) (0.3) Regulatory Assets (a) (8.5) (0.3) (0.1) (0.2) (9.9) (0.6) 2.2 Regulatory Liabilities (a) 80.9 — 16.2 8.8 8.4 23.9 14.8 Total Gain (Loss) on Risk Management Contracts $ 81.9 $ (1.3) $ 17.0 $ 8.4 $ (2.2) $ 22.9 $ 16.6 (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 September 30, 2021 December 31, 2020 September 30, 2021 December 31, 2020 (in millions) Long-term Debt (a) (b) $ (965.6) $ (995.9) $ (22.1) $ (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 September 30, Nine Months Ended September 30, 2021 2020 2021 2020 (in millions) Gain (Loss) on Interest Rate Contracts: Fair Value Hedging Instruments (a) $ (0.1) $ — $ (23.8) $ 42.6 Fair Value Portion of Long-term Debt (a) 0.1 — 23.8 (42.6) (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 September 30, 2021 December 31, 2020 Commodity Interest Rate Commodity Interest Rate (in millions) AOCI Gain (Loss) Net of Tax $ 283.9 $ (26.1) $ (60.6) $ (47.5) Portion Expected to be Reclassed to Net Income During the Next Twelve Months 56.5 (2.6) (27.1) (5.7) Impact of Cash Flow Hedges on the Registrant Subsidiaries’ Balance Sheets September 30, 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 $ (1.5) $ (1.1) $ (2.3) $ (1.1) APCo 7.7 0.8 (0.8) 0.4 I&M (7.0) (1.6) (8.3) (1.6) PSO — — 0.1 0.1 SWEPCo 0.8 (0.4) (0.3) (1.5)
Liabilities Subject to Cross Default Provisions	September 30, 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 $ 128.2 $ — $ 95.8 APCo 1.0 — — I&M 0.6 — — SWEPCo — — — 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)	9 Months Ended
	Sep. 30, 2021
Book Values and Fair Values of Long-term Debt	September 30, 2021 December 31, 2020 Company Book Value Fair Value Book Value Fair Value (in millions) AEP (a) $ 34,578.3 $ 38,925.1 $ 31,072.5 $ 37,457.0 AEP Texas 5,216.1 5,763.9 4,820.4 5,682.6 AEPTCo 4,393.4 5,074.5 3,948.5 4,984.3 APCo 4,937.8 6,067.0 4,834.1 6,391.8 I&M 3,231.1 3,790.5 3,029.9 3,775.3 OPCo 3,468.1 3,948.6 2,430.2 3,154.9 PSO 1,913.3 2,169.2 1,373.8 1,732.1 SWEPCo 3,129.9 3,534.0 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 September 30, 2021 and December 31, 2020, respectively. See “Equity Units” section of Note 12 for additional information.
Other Temporary Investments	September 30, 2021 Gross Gross Unrealized Unrealized Fair Other Temporary Investments Cost Gains Losses Value (in millions) Restricted Cash and Other Cash Deposits (a) $ 77.3 $ — $ — $ 77.3 Fixed Income Securities – Mutual Funds (b) 141.8 1.8 — 143.6 Equity Securities – Mutual Funds 19.4 32.1 — 51.5 Total Other Temporary Investments $ 238.5 $ 33.9 $ — $ 272.4 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 September 30, Nine Months Ended September 30, 2021 2020 2021 2020 (in millions) Proceeds from Investment Sales $ 6.0 $ 5.1 $ 15.1 $ 35.9 Purchases of Investments 12.9 22.5 26.0 39.5 Gross Realized Gains on Investment Sales 2.4 0.2 3.6 2.4 Gross Realized Losses on Investment Sales — — — 0.2
Nuclear Trust Fund Investments	September 30, 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 $ 63.9 $ — $ — $ 25.8 $ — $ — Fixed Income Securities: United States Government 1,135.3 66.9 (6.8) 1,025.6 98.5 (7.1) Corporate Debt 86.6 6.9 (2.0) 86.3 9.6 (1.7) State and Local Government 36.8 0.3 (0.2) 114.3 0.9 (0.4) Subtotal Fixed Income Securities 1,258.7 74.1 (9.0) 1,226.2 109.0 (9.2) Equity Securities - Domestic (a) 2,287.2 1,652.8 — 2,054.7 1,400.8 — Spent Nuclear Fuel and Decommissioning Trusts $ 3,609.8 $ 1,726.9 $ (9.0) $ 3,306.7 $ 1,509.8 $ (9.2)
Securities Activity Within the Decommissioning and SNF Trusts	Three Months Ended September 30, Nine Months Ended September 30, 2021 2020 2021 2020 (in millions) Proceeds from Investment Sales $ 433.9 $ 316.6 $ 1,556.6 $ 1,257.1 Purchases of Investments 436.6 318.6 1,586.3 1,290.0 Gross Realized Gains on Investment Sales 9.6 3.4 98.3 25.4 Gross Realized Losses on Investment Sales 7.0 0.5 12.5 25.2
Contractual Maturities, Fair Value of Debt Securities in Nuclear Trusts	Fair Value of Fixed Income Securities (in millions) Within 1 year $ 292.9 After 1 year through 5 years 433.4 After 5 years through 10 years 251.5 After 10 years 280.9 Total $ 1,258.7
Fair Value, Assets and Liabilities Measured on Recurring Basis	AEP Assets and Liabilities Measured at Fair Value on a Recurring Basis September 30, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Other Temporary Investments Restricted Cash and Other Cash Deposits (a) $ 66.1 $ — $ — $ 11.2 $ 77.3 Fixed Income Securities – Mutual Funds 143.6 — — — 143.6 Equity Securities – Mutual Funds (b) 51.5 — — — 51.5 Total Other Temporary Investments 261.2 — — 11.2 272.4 Risk Management Assets Risk Management Commodity Contracts (c) (d) 16.9 1,090.7 221.9 (1,054.0) 275.5 Cash Flow Hedges: Commodity Hedges (c) — 367.3 31.3 (34.9) 363.7 Interest Rate Hedges — 4.9 — — 4.9 Fair Value Hedges — 3.4 — — 3.4 Total Risk Management Assets 16.9 1,466.3 253.2 (1,088.9) 647.5 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 56.0 — — 7.9 63.9 Fixed Income Securities: United States Government — 1,135.3 — — 1,135.3 Corporate Debt — 86.6 — — 86.6 State and Local Government — 36.8 — — 36.8 Subtotal Fixed Income Securities — 1,258.7 — — 1,258.7 Equity Securities – Domestic (b) 2,287.2 — — — 2,287.2 Total Spent Nuclear Fuel and Decommissioning Trusts 2,343.2 1,258.7 — 7.9 3,609.8 Other Investments (h) 30.3 15.9 — — 46.2 Total Assets $ 2,651.6 $ 2,740.9 $ 253.2 $ (1,069.8) $ 4,575.9 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (d) $ 8.4 $ 923.3 $ 124.1 $ (782.6) $ 273.2 Cash Flow Hedges: Commodity Hedges (c) — 38.9 0.1 (34.9) 4.1 Fair Value Hedges — 28.8 — — 28.8 Total Risk Management Liabilities $ 8.4 $ 991.0 $ 124.2 $ (817.5) $ 306.1 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 September 30, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 43.9 $ — $ — $ — $ 43.9 Risk Management Assets Risk Management Commodity Contracts (c) — 0.9 — (0.9) — Total Assets $ 43.9 $ 0.9 $ — $ (0.9) $ 43.9 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 September 30, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Restricted Cash for Securitized Funding $ 10.1 $ — $ — $ — $ 10.1 Risk Management Assets Risk Management Commodity Contracts (c) (g) — 48.9 47.0 (48.9) 47.0 Total Assets $ 10.1 $ 48.9 $ 47.0 $ (48.9) $ 57.1 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 59.3 $ 1.1 $ (59.1) $ 1.3 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 September 30, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 30.9 $ 7.0 $ (32.4) $ 5.5 Spent Nuclear Fuel and Decommissioning Trusts Cash and Cash Equivalents (e) 56.0 — — 7.9 63.9 Fixed Income Securities: United States Government — 1,135.3 — — 1,135.3 Corporate Debt — 86.6 — — 86.6 State and Local Government — 36.8 — — 36.8 Subtotal Fixed Income Securities — 1,258.7 — — 1,258.7 Equity Securities - Domestic (b) 2,287.2 — — — 2,287.2 Total Spent Nuclear Fuel and Decommissioning Trusts 2,343.2 1,258.7 — 7.9 3,609.8 Total Assets $ 2,343.2 $ 1,289.6 $ 7.0 $ (24.5) $ 3,615.3 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ 48.3 $ 3.7 $ (49.5) $ 2.5 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 September 30, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.7 $ — $ (0.7) $ — Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 90.4 $ — $ 90.4 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 September 30, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.3 $ 18.7 $ (0.5) $ 18.5 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 0.2 $ (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) $ — $ 0.2 $ 10.3 $ (0.2) $ 10.3 SWEPCo Assets and Liabilities Measured at Fair Value on a Recurring Basis September 30, 2021 Level 1 Level 2 Level 3 Other Total Assets: (in millions) Risk Management Assets Risk Management Commodity Contracts (c) (g) $ — $ 0.4 $ 19.8 $ (0.6) $ 19.6 Liabilities: Risk Management Liabilities Risk Management Commodity Contracts (c) (g) $ — $ — $ 0.2 $ (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) $ — $ 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 September 30, 2021 maturity of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $2 million in 2021 and $7 million in periods 2022-2024; Level 2 matures $20 million in 2021, $112 million in periods 2022-2024, $22 million in periods 2025-2026 and $13 million in periods 2027-2033; Level 3 matures $96 million in 2021, $18 million in periods 2022-2024, $5 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 September 30, 2021 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of June 30, 2021 $ 101.2 $ 36.6 $ 7.3 $ (105.4) $ 22.9 $ 14.6 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 27.5 4.0 0.1 0.1 13.5 5.8 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) 2.9 — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 17.8 — — — — — Settlements (54.5) (10.5) (3.8) 0.9 (20.6) (9.8) Transfers into Level 3 (d) (e) (5.8) — — — — — Transfers out of Level 3 (e) (4.1) 0.1 — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 44.0 15.7 (0.3) 14.0 2.7 9.0 Balance as of September 30, 2021 $ 129.0 $ 45.9 $ 3.3 $ (90.4) $ 18.5 $ 19.6 Three Months Ended September 30, 2020 AEP APCo I&M OPCo PSO SWEPCo (in millions) Balance as of June 30, 2020 $ 111.6 $ 36.5 $ 4.5 $ (117.4) $ 23.8 $ 3.3 Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b) 18.7 6.4 3.3 — 3.0 1.5 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) 6.5 — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 2.6 — — — — — Settlements (37.0) (11.1) (5.0) 1.3 (10.3) (3.5) Transfers into Level 3 (d) (e) (1.0) — — — — — Transfers out of Level 3 (e) 1.1 — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 3.6 (2.2) 1.0 2.9 (0.4) 2.4 Balance as of September 30, 2020 $ 106.1 $ 29.6 $ 3.8 $ (113.2) $ 16.1 $ 3.7 Nine Months Ended September 30, 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) 68.9 38.8 0.4 0.4 16.1 9.5 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (64.1) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 35.5 — — — — — Settlements (113.3) (58.2) (2.5) 5.8 (26.4) (13.0) Transfers into Level 3 (d) (e) (0.2) — — — — Transfers out of Level 3 (e) (26.2) — — — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 115.1 46.0 3.3 13.7 18.5 21.5 Balance as of September 30, 2021 $ 129.0 $ 45.9 $ 3.3 $ (90.4) $ 18.5 $ 19.6 Nine Months Ended September 30, 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) 39.6 13.1 2.4 (1.2) 11.9 2.8 Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date (a) (2.4) — — — — — Realized and Unrealized Gains (Losses) Included in Other Comprehensive Income (c) 21.7 — — — — — Settlements (115.3) (51.4) (8.5) 6.4 (27.6) (6.9) Transfers into Level 3 (d) (e) (1.1) — — — — — Transfers out of Level 3 (e) 5.6 0.7 0.4 — — — Changes in Fair Value Allocated to Regulated Jurisdictions (f) 48.1 29.5 3.7 (14.8) 16.0 6.4 Balance as of September 30, 2020 $ 106.1 $ 29.6 $ 3.8 $ (113.2) $ 16.1 $ 3.7 (a) Included in revenues on the statements of income. (b) Represents the change in fair value between the beginning of the reporting period and the settlement of the risk management commodity contract. (c) Included in cash flow hedges on the statements of comprehensive income. (d) Represents existing assets or liabilities that were previously categorized as Level 2. (e) Transfers are recognized based on their value at the beginning of the reporting period that the transfer occurred. (f) Relates to the net gains (losses) of those contracts that are not reflected on the statements of income. These net gains (losses) are recorded as regulatory assets/liabilities or accounts payable.
Significant Unobservable Inputs for Level 3	AEP Significant Unobservable Inputs September 30, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (in millions) Energy Contracts $ 145.6 $ 117.3 Discounted Cash Flow Forward Market Price (a) (c) $ 0.10 $ 108.40 $ 35.57 Natural Gas Contracts 9.0 — Discounted Cash Flow Forward Market Price (b) (c) 2.92 6.27 4.59 FTRs 98.6 6.9 Discounted Cash Flow Forward Market Price (a) (c) (21.95) 13.46 0.46 Total $ 253.2 $ 124.2 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 September 30, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ 0.2 $ 1.1 Discounted Cash Flow Forward Market Price $ 26.70 $ 87.14 $ 53.61 FTRs 46.8 — Discounted Cash Flow Forward Market Price 0.35 13.46 1.83 Total $ 47.0 $ 1.1 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 September 30, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ 0.2 $ 0.7 Discounted Cash Flow Forward Market Price $ 26.70 $ 87.14 $ 53.61 FTRs 6.8 3.0 Discounted Cash Flow Forward Market Price (1.85) 5.75 0.37 Total $ 7.0 $ 3.7 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 September 30, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) Energy Contracts $ — $ 90.4 Discounted Cash Flow Forward Market Price $ 9.89 $ 81.50 $ 32.40 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 September 30, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input (a) Low High Average (c) (in millions) FTRs $ 18.7 $ 0.2 Discounted Cash Flow Forward Market Price $ (18.86) $ 4.10 $ (2.44) 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 September 30, 2021 Significant Input/Range Fair Value Valuation Unobservable Weighted Assets Liabilities Technique Input Low High Average (c) (in millions) Natural Gas Contracts $ 9.0 $ — Discounted Cash Flow Forward Market Price (b) $ 3.58 $ 6.27 $ 4.44 FTRs 10.8 0.2 Discounted Cash Flow Forward Market Price (a) (18.86) 4.10 (2.44) Total $ 19.8 $ 0.2 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)	9 Months Ended
	Sep. 30, 2021
Schedule of Effective Income Tax Rate Reconciliation	Three Months Ended September 30, 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 0.6 % 0.3 % 3.0 % (0.3) % 1.9 % 1.2 % 5.0 % (6.9) % Tax Reform Excess ADIT Reversal (8.5) % (6.3) % 0.3 % (14.2) % (16.1) % (8.9) % (19.8) % (4.2) % Production and Investment Tax Credits (4.7) % (0.3) % — % (0.2) % (2.0) % — % (8.9) % (5.4) % Flow Through — % 0.3 % 0.3 % 0.4 % (2.8) % 0.6 % 0.7 % (0.2) % AFUDC Equity (1.2) % (1.0) % (2.2) % (1.8) % (1.0) % (0.3) % (0.2) % (0.5) % Parent Company Loss Benefit — % (1.1) % (2.3) % (1.2) % (3.6) % — % — % 0.7 % Discrete Tax Adjustments 0.2 % — % — % — % — % — % — % 1.2 % Other 0.7 % (0.1) % 0.1 % 0.3 % 0.8 % — % (0.1) % (0.2) % Effective Income Tax Rate 8.1 % 12.8 % 20.2 % 4.0 % (1.8) % 13.6 % (2.3) % 5.5 % Three Months Ended September 30, 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 2.7 % 2.0 % 2.9 % 3.1 % 3.4 % 0.8 % 4.6 % 2.4 % Tax Reform Excess ADIT Reversal (11.0) % (14.6) % 0.4 % (22.0) % (16.7) % (6.7) % (20.3) % (7.3) % Production and Investment Tax Credits (4.6) % (0.5) % — % — % (1.6) % — % (1.1) % (0.5) % Flow Through 0.5 % 0.2 % 0.5 % 1.6 % 0.2 % 0.9 % 0.2 % (1.2) % AFUDC Equity (1.5) % (3.5) % (2.6) % (1.1) % (0.9) % (0.9) % (0.6) % (0.3) % Parent Company Loss Benefit — % — % (0.9) % (3.1) % (3.7) % (0.3) % (1.7) % (2.0) % Discrete Tax Adjustments (a) (7.4) % (3.6) % (0.2) % (6.6) % 2.3 % 8.4 % (0.6) % (0.6) % Other 0.1 % 0.3 % 0.1 % — % — % 0.3 % 0.1 % (0.6) % Effective Income Tax Rate (0.2) % 1.3 % 21.2 % (7.1) % 4.0 % 23.5 % 1.6 % 10.9 % Nine Months Ended September 30, 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 1.2 % 0.3 % 2.8 % 1.5 % 1.6 % 0.8 % 4.8 % (3.4) % Tax Reform Excess ADIT Reversal (8.9) % (7.2) % 0.3 % (15.2) % (17.7) % (9.1) % (19.8) % (4.3) % Production and Investment Tax Credits (4.9) % (0.3) % — % — % (2.2) % — % (8.1) % (4.6) % Flow Through 0.2 % 0.3 % 0.3 % 1.7 % (3.0) % 0.9 % 0.7 % (0.2) % AFUDC Equity (1.1) % (1.1) % (1.9) % (1.2) % (1.0) % (0.8) % (0.3) % (0.6) % Parent Company Loss Benefit — % (0.7) % (1.9) % (1.3) % (2.8) % — % — % — % Discrete Tax Adjustments 1.1 % — % — % — % — % (1.3) % (0.9) % 0.6 % Other 0.1 % — % — % 0.1 % 0.4 % 0.2 % (0.2) % (0.1) % Effective Income Tax Rate 8.7 % 12.3 % 20.6 % 6.6 % (3.7) % 11.7 % (2.8) % 8.4 % Nine Months Ended September 30, 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 2.6 % 1.8 % 2.9 % 3.1 % 3.4 % 0.7 % 4.6 % 2.3 % Tax Reform Excess ADIT Reversal (12.1) % (23.4) % 0.4 % (20.8) % (16.7) % (8.8) % (20.3) % (11.5) % Production and Investment Tax Credits (4.5) % (0.5) % — % — % (1.6) % — % (1.1) % (0.5) % Flow Through 0.5 % 0.1 % 0.5 % 1.6 % 0.2 % 0.9 % 0.2 % (1.2) % AFUDC Equity (1.5) % (3.2) % (2.6) % (1.1) % (0.9) % (0.9) % (0.6) % (0.3) % Parent Company Loss Benefit — % — % (0.9) % (3.1) % (3.7) % (0.3) % (1.7) % (1.9) % Discrete Tax Adjustments (a) (3.0) % (1.6) % (0.1) % (2.3) % 1.8 % 2.6 % (0.4) % (0.3) % Other 0.2 % 0.4 % (0.1) % (0.1) % (0.1) % 0.2 % 0.1 % (0.4) % Effective Income Tax Rate 3.2 % (5.4) % 21.1 % (1.7) % 3.4 % 15.4 % 1.8 % 7.2 %

Financing Activities (Tables)

Financing Activities (Tables)	9 Months Ended
	Sep. 30, 2021
Long-term Debt	Type of Debt September 30, 2021 December 31, 2020 (in millions) Senior Unsecured Notes $ 28,778.1 $ 25,116.1 Pollution Control Bonds 1,881.0 1,936.7 Notes Payable 235.1 239.1 Securitization Bonds 639.7 716.4 Spent Nuclear Fuel Obligation (a) 281.3 281.2 Junior Subordinated Notes (b) 1,629.9 1,624.1 Other Long-term Debt 1,133.2 1,158.9 Total Long-term Debt Outstanding 34,578.3 31,072.5 Long-term Debt Due Within One Year 2,521.8 2,086.1 Long-term Debt $ 32,056.5 $ 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 $327 million and $324 million as of September 30, 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) (%) AEP Senior Unsecured Notes $ 175.0 1.80 2028 AEP Texas Senior Unsecured Notes 450.0 3.45 2051 AEPTCo Senior Unsecured Notes 450.0 2.75 2051 APCo Senior Unsecured Notes 500.0 2.70 2031 I&M Notes Payable 64.9 0.93 2025 I&M Senior Unsecured Notes 450.0 3.25 2051 OPCo Senior Unsecured Notes 450.0 1.63 2031 OPCo Senior Unsecured Notes 600.0 2.90 2051 PSO Other Long-term Debt 500.0 Variable 2022 PSO Senior Unsecured Notes 400.0 2.20 2031 PSO Senior Unsecured Notes 400.0 3.15 2051 SWEPCo Senior Unsecured Notes 500.0 1.65 2026 Non-Registrant: KPCo Other Long-term Debt 150.0 Variable 2023 Transource Energy Other Long-term Debt 25.9 Variable 2023 Total Issuances $ 5,115.8 (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 $ 29.7 2.85 2024 AEP Texas Securitization Bonds 22.5 2.06 2025 APCo Senior Unsecured Notes 350.0 4.60 2021 APCo Pollution Control Bonds 17.5 4.63 2021 APCo Securitization Bonds 25.4 2.01 2023 APCo Other Long-term Debt 0.1 13.72 2026 I&M Other Long-term Debt 200.0 Variable 2021 I&M Pollution Control Bonds 40.0 2.05 2021 I&M Notes Payable 1.9 Variable 2021 I&M Notes Payable 4.5 Variable 2022 I&M Notes Payable 5.4 Variable 2022 I&M Notes Payable 14.3 Variable 2023 I&M Notes Payable 12.6 Variable 2024 I&M Notes Payable 19.6 Variable 2025 I&M Notes Payable 7.4 0.93 2025 I&M Other Long-term Debt 1.5 6.00 2025 OPCo Other Long-term Debt 0.1 1.15 2028 PSO Senior Unsecured Notes 250.0 4.40 2021 PSO Other Long-term Debt 500.0 Variable 2022 PSO Other Long-term Debt 0.4 3.00 2027 SWEPCo Other Long-term Debt 1.5 4.68 2028 SWEPCo Notes Payable 3.2 4.58 2032 Non-Registrant: KPCo Senior Unsecured Notes 39.8 7.25 2021 Transource Energy Senior Unsecured Notes 1.2 2.75 2050 Transource Energy Senior Unsecured Notes 1.2 2.75 2050 Total Retirements and Principal Payments $ 1,549.8
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 September 30, 2021 Limit (in millions) AEP Texas $ 355.5 $ 104.7 $ 234.7 $ 45.2 $ 47.6 $ 500.0 AEPTCo 444.9 117.3 225.1 24.4 73.9 820.0 (a) APCo 27.8 616.9 13.2 134.4 185.2 500.0 I&M 166.5 368.2 117.5 76.3 80.6 500.0 OPCo 259.2 622.9 62.8 182.5 622.9 500.0 PSO 267.7 747.3 142.8 184.9 59.5 300.0 SWEPCo 280.3 156.4 148.0 142.0 (122.9) 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 September 30, 2021 (in millions) AEP Texas $ 7.1 $ 6.9 $ 7.0 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 September 30, 2021 September 30, 2021 Borrowing Limit (in millions) $ 14.6 $ 224.2 $ 1.6 $ 139.3 $ 8.6 $ — $ 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	Nine Months Ended September 30, 2021 2020 Maximum Interest Rate 0.40 % 2.70 % Minimum Interest Rate 0.02 % 0.33 %
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 Nine Months Ended September 30, for Nine Months Ended September 30, Company 2021 2020 2021 2020 AEP Texas 0.33 % 1.55 % 0.27 % 0.87 % AEPTCo 0.32 % 1.63 % 0.07 % 2.00 % APCo 0.28 % 2.14 % 0.28 % 0.99 % I&M 0.32 % 1.30 % 0.25 % 1.44 % OPCo 0.27 % 1.32 % 0.15 % 2.06 % PSO 0.34 % 1.24 % 0.06 % 1.95 % SWEPCo 0.28 % 1.55 % 0.38 % — %
Maximum Minimum Average Interest Rates for Funds Borrowed from Loaned to Nonutility Money Pool	Nine Months Ended September 30, 2021 Nine Months Ended September 30, 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 0.41 % 0.21 % 0.34 % 2.70 % 0.33 % 1.44 % SWEPCo 0.41 % 0.21 % 0.34 % 2.70 % 0.33 % 1.44 %
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 Nine Months for Funds for Funds for Funds for Funds for Funds for Funds Ended Borrowed Borrowed Loaned Loaned Borrowed Loaned September 30, from AEP from AEP to AEP to AEP from AEP to AEP 2021 0.86 % 0.25 % 0.86 % 0.25 % 0.35 % 0.34 % 2020 2.70 % 0.50 % 2.70 % 0.50 % 1.45 % 1.40 %
Short Term Debt	September 30, 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) $ 750.0 0.19 % $ 592.0 0.85 % AEP Commercial Paper 1,254.0 0.25 % 1,852.3 0.29 % AEP 364-Day Term Loan 500.0 0.72 % — — % SWEPCo Notes Payable — — % 35.0 2.55 % Total Short-term Debt $ 2,504.0 $ 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 Nine Months Ended September 30, September 30, 2021 2020 2021 2020 (dollars in millions) Effective Interest Rates on Securitization of Accounts Receivable 0.18 % 0.36 % 0.19 % 1.05 % Net Uncollectible Accounts Receivable Written-Off $ 7.5 $ 2.9 $ 22.6 $ 10.5
Customer Accounts Receivable Managed Portfolio	September 30, 2021 December 31, 2020 (in millions) Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts $ 1,031.3 $ 958.4 Short-term – Securitized Debt of Receivables 750.0 592.0 Delinquent Securitized Accounts Receivable 60.0 62.3 Bad Debt Reserves Related to Securitization 39.8 60.0 Unbilled Receivables Related to Securitization 224.5 296.8
Accounts Receivable and Accrued Unbilled Revenues	Company September 30, 2021 December 31, 2020 (in millions) APCo $ 131.0 $ 136.0 I&M 173.9 170.5 OPCo 377.3 398.8 PSO 147.1 85.0 SWEPCo 185.6 158.6
Fees Paid to AEP Credit for Customer Accounts Receivable Sold	Three Months Ended September 30, Nine Months Ended September 30, Company 2021 (a) 2020 2021 (a) 2020 (in millions) APCo $ 1.3 $ 2.0 $ 3.7 $ 5.0 I&M 2.1 3.9 5.3 9.3 OPCo 4.6 9.8 3.5 19.6 PSO 1.1 1.5 2.4 3.8 SWEPCo 1.3 2.8 4.1 6.8 (a) In 2020, an increase in allowance for doubtful accounts was recognized in response to the anticipated impact of COVID-19 on the collectability of accounts receivable, which caused an increase in fees paid by the registrants. In 2021, due to higher than expected collections of accounts receivables, allowance for doubtful accounts was adjusted resulting in the issuance of credits to offset the higher fees previously paid and to lower subsequent fees paid.
Proceeds on Sale of Receivables to AEP Credit	Three Months Ended September 30, Nine Months Ended September 30, Company 2021 2020 2021 2020 (in millions) APCo $ 342.2 $ 323.5 $ 980.6 $ 961.8 I&M 536.8 532.3 1,478.9 1,443.6 OPCo 668.4 666.0 1,867.5 1,793.0 PSO 460.1 369.2 1,068.8 961.4 SWEPCo 488.5 478.3 1,265.5 1,225.3

Property, Plant and Equipment_2

Property, Plant and Equipment (Tables)	9 Months Ended
	Sep. 30, 2021
Asset Retirement Obligation (ARO)	Company ARO as of December 31, 2020 Accretion Liabilities Liabilities Revisions in ARO as of September 30, 2021 (in millions) AEP (a)(b)(c)(d) $ 2,516.7 $ 77.6 $ 17.7 $ (27.6) $ 75.1 $ 2,659.5 APCo (a)(d) 313.1 9.9 — (5.8) 84.7 401.9 (a) Includes ARO related to ash disposal facilities. (b) Includes ARO related to nuclear decommissioning costs for the Cook Plant of $1.85 billion and $1.80 billion as of September 30, 2021 and December 31, 2020, respectively. (c) Includes ARO related to Sabine and DHLC. (d) Includes ARO related to asbestos removal.

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	9 Months Ended
	Sep. 30, 2021
Disaggregated Revenues from Contracts with Customers	Three Months Ended September 30, 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 $ 1,144.3 $ 598.0 $ — $ — $ — $ — $ 1,742.3 Commercial Revenues 618.9 279.9 — — — — 898.8 Industrial Revenues 566.0 95.2 — — — (0.1) 661.1 Other Retail Revenues 47.5 11.1 — — — — 58.6 Total Retail Revenues 2,376.7 984.2 — — — (0.1) 3,360.8 Wholesale and Competitive Retail Revenues: Generation Revenues 233.8 — — 47.8 — — 281.6 Transmission Revenues (a) 99.8 150.6 375.8 — — (317.4) 308.8 Renewable Generation Revenues (b) — — — 24.1 — (0.6) 23.5 Retail, Trading and Marketing Revenues (c) — — — 397.1 0.1 (3.1) 394.1 Total Wholesale and Competitive Retail Revenues 333.6 150.6 375.8 469.0 0.1 (321.1) 1,008.0 Other Revenues from Contracts with Customers (b) 49.4 54.2 5.1 1.4 23.5 (40.1) 93.5 Total Revenues from Contracts with Customers 2,759.7 1,189.0 380.9 470.4 23.6 (361.3) 4,462.3 Other Revenues: Alternative Revenues (b) 0.5 6.4 10.7 — — (11.7) 5.9 Other Revenues (b) (d) (0.9) 4.9 — 150.7 3.1 (3.0) 154.8 Total Other Revenues (0.4) 11.3 10.7 150.7 3.1 (14.7) 160.7 Total Revenues $ 2,759.3 $ 1,200.3 $ 391.6 $ 621.1 $ 26.7 $ (376.0) $ 4,623.0 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $286 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 $4 million. The remaining affiliated amounts were immaterial. (d) Generation & Marketing includes economic hedge activity. Three Months Ended September 30, 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 $ 1,053.3 $ 594.8 $ — $ — $ — $ — $ 1,648.1 Commercial Revenues 559.7 259.2 — — — — 818.9 Industrial Revenues 504.5 93.9 — — — (0.1) 598.3 Other Retail Revenues 41.4 10.0 — — — — 51.4 Total Retail Revenues 2,158.9 957.9 — — — (0.1) 3,116.7 Wholesale and Competitive Retail Revenues: Generation Revenues 158.4 — — 30.5 — — 188.9 Transmission Revenues (a) 84.4 119.1 317.7 — — (276.9) 244.3 Renewable Generation Revenues (b) — — — 15.8 — (0.3) 15.5 Retail, Trading and Marketing Revenues (c) — — — 447.5 0.9 (24.8) 423.6 Total Wholesale and Competitive Retail Revenues 242.8 119.1 317.7 493.8 0.9 (302.0) 872.3 Other Revenues from Contracts with Customers (b) 34.1 42.8 2.4 0.7 33.9 (43.7) 70.2 Total Revenues from Contracts with Customers 2,435.8 1,119.8 320.1 494.5 34.8 (345.8) 4,059.2 Other Revenues: Alternative Revenues (b) (1.0) 9.3 (2.2) — — 6.6 12.7 Other Revenues (b) (d) — 36.2 — (4.5) (2.2) (35.0) (5.5) Total Other Revenues (1.0) 45.5 (2.2) (4.5) (2.2) (28.4) 7.2 Total Revenues $ 2,434.8 $ 1,165.3 $ 317.9 $ 490.0 $ 32.6 $ (374.2) $ 4,066.4 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $246 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 $19 million. The remaining affiliated amounts were immaterial. (d) Generation & Marketing includes economic hedge activity. Three Months Ended September 30, 2021 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 172.5 $ — $ 340.1 $ 231.7 $ 425.4 $ 236.8 $ 230.9 Commercial Revenues 89.1 — 146.9 143.9 190.8 120.9 145.4 Industrial Revenues 25.4 — 154.8 146.8 69.8 77.1 85.4 Other Retail Revenues 8.2 — 18.6 1.3 3.1 23.4 2.3 Total Retail Revenues 295.2 — 660.4 523.7 689.1 458.2 464.0 Wholesale Revenues: Generation Revenues (a) — — 83.7 80.2 — 7.2 77.1 Transmission Revenues (b) 131.5 360.1 35.2 8.7 19.1 10.6 37.1 Total Wholesale Revenues 131.5 360.1 118.9 88.9 19.1 17.8 114.2 Other Revenues from Contracts with Customers (c) 6.8 5.0 22.5 24.2 47.3 8.3 6.1 Total Revenues from Contracts with Customers 433.5 365.1 801.8 636.8 755.5 484.3 584.3 Other Revenues: Alternative Revenues (d) (0.9) 11.9 2.2 (1.1) 7.3 (0.5) (0.2) Other Revenues (d) — — — — 4.9 — — Total Other Revenues (0.9) 11.9 2.2 (1.1) 12.2 (0.5) (0.2) Total Revenues $ 432.6 $ 377.0 $ 804.0 $ 635.7 $ 767.7 $ 483.8 $ 584.1 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $30 million primarily relating to the PPA with KGPCo. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $281 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $17 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 September 30, 2020 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 165.3 $ — $ 324.2 $ 222.6 $ 429.4 $ 195.8 $ 219.4 Commercial Revenues 78.0 — 138.4 135.8 181.2 94.4 135.0 Industrial Revenues 24.9 — 139.4 139.7 69.1 55.0 83.8 Other Retail Revenues 6.9 — 17.6 1.6 3.1 18.4 2.3 Total Retail Revenues 275.1 — 619.6 499.7 682.8 363.6 440.5 Wholesale Revenues: Generation Revenues (a) — — 70.3 61.5 — 5.8 42.3 Transmission Revenues (b) 101.8 305.7 30.8 7.4 17.2 8.5 28.7 Total Wholesale Revenues 101.8 305.7 101.1 68.9 17.2 14.3 71.0 Other Revenues from Contracts with Customers (c) 15.2 3.0 16.1 17.7 27.6 4.8 5.6 Total Revenues from Contracts with Customers 392.1 308.7 736.8 586.3 727.6 382.7 517.1 Other Revenues: Alternative Revenues (d) (0.7) (4.6) (1.1) 0.4 10.0 (0.5) 0.2 Other Revenues (d) 40.6 — — — 3.4 — — Total Other Revenues 39.9 (4.6) (1.1) 0.4 13.4 (0.5) 0.2 Total Revenues $ 432.0 $ 304.1 $ 735.7 $ 586.7 $ 741.0 $ 382.2 $ 517.3 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $28 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 $243 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $15 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. Nine Months Ended September 30, 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 $ 3,016.2 $ 1,641.2 $ — $ — $ — $ — $ 4,657.4 Commercial Revenues 1,642.0 804.1 — — — — 2,446.1 Industrial Revenues 1,602.5 283.8 — — — (0.5) 1,885.8 Other Retail Revenues 125.9 32.4 — — — — 158.3 Total Retail Revenues 6,386.6 2,761.5 — — — (0.5) 9,147.6 Wholesale and Competitive Retail Revenues: Generation Revenues 757.1 — — 119.4 — — 876.5 Transmission Revenues (a) 267.3 420.7 1,092.1 — — (901.5) 878.6 Renewable Generation Revenues (b) — — — 66.7 — (1.7) 65.0 Retail, Trading and Marketing Revenues (c) — — — 1,325.6 0.6 (48.5) 1,277.7 Total Wholesale and Competitive Retail Revenues 1,024.4 420.7 1,092.1 1,511.7 0.6 (951.7) 3,097.8 Other Revenues from Contracts with Customers (b) 136.1 149.3 12.5 4.9 46.1 (87.9) 261.0 Total Revenues from Contracts with Customers 7,547.1 3,331.5 1,104.6 1,516.6 46.7 (1,040.1) 12,506.4 Other Revenues: Alternative Revenues (b) 10.7 46.1 42.2 — — (63.5) 35.5 Other Revenues (b) (d) (0.6) 14.2 — 175.3 8.4 (8.6) 188.7 Total Other Revenues 10.1 60.3 42.2 175.3 8.4 (72.1) 224.2 Total Revenues $ 7,557.2 $ 3,391.8 $ 1,146.8 $ 1,691.9 $ 55.1 $ (1,112.2) $ 12,730.6 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $835 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 $49 million. The remaining affiliated amounts were immaterial. (d) Generation & Marketing includes economic hedge activity. Nine Months Ended September 30, 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 $ 2,789.1 $ 1,610.6 $ — $ — $ — $ — $ 4,399.7 Commercial Revenues 1,523.6 792.4 — — — — 2,316.0 Industrial Revenues 1,508.7 290.4 — — — (0.5) 1,798.6 Other Retail Revenues 118.2 32.1 — — — — 150.3 Total Retail Revenues 5,939.6 2,725.5 — — — (0.5) 8,664.6 Wholesale and Competitive Retail Revenues: Generation Revenues 447.4 — — 106.1 — — 553.5 Transmission Revenues (a) 248.4 341.6 937.7 — — (741.7) 786.0 Renewable Generation Revenues (b) — — — 50.7 — (1.2) 49.5 Retail, Trading and Marketing Revenues (c) — — — 1,133.8 (5.7) (80.7) 1,047.4 Total Wholesale and Competitive Retail Revenues 695.8 341.6 937.7 1,290.6 (5.7) (823.6) 2,436.4 Other Revenues from Contracts with Customers (b) 124.1 112.3 17.5 1.7 84.4 (115.7) 224.3 Total Revenues from Contracts with Customers 6,759.5 3,179.4 955.2 1,292.3 78.7 (939.8) 11,325.3 Other Revenues: Alternative Revenues (b) (6.0) 49.2 (77.4) — — 3.5 (30.7) Other Revenues (b) (d) — 78.1 — 13.2 (6.7) (71.3) 13.3 Total Other Revenues (6.0) 127.3 (77.4) 13.2 (6.7) (67.8) (17.4) Total Revenues $ 6,753.5 $ 3,306.7 $ 877.8 $ 1,305.5 $ 72.0 $ (1,007.6) $ 11,307.9 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $725 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 $81 million. The remaining affiliated amounts were immaterial. (d) Generation & Marketing includes economic hedge activity. Nine Months Ended September 30, 2021 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 423.7 $ — $ 1,025.0 $ 624.4 $ 1,217.5 $ 516.4 $ 547.1 Commercial Revenues 265.2 — 409.5 384.5 538.9 286.8 385.4 Industrial Revenues 81.6 — 433.4 418.9 202.2 202.1 247.1 Other Retail Revenues 23.1 — 51.7 3.9 9.4 58.2 7.2 Total Retail Revenues 793.6 — 1,919.6 1,431.7 1,968.0 1,063.5 1,186.8 Wholesale Revenues: Generation Revenues (a) — — 231.2 248.1 — 6.8 326.2 Transmission Revenues (b) 364.5 1,045.2 94.1 25.3 56.2 28.8 94.5 Total Wholesale Revenues 364.5 1,045.2 325.3 273.4 56.2 35.6 420.7 Other Revenues from Contracts with Customers (c) 35.4 12.5 43.6 81.9 113.8 24.8 17.7 Total Revenues from Contracts with Customers 1,193.5 1,057.7 2,288.5 1,787.0 2,138.0 1,123.9 1,625.2 Other Revenues: Alternative Revenues (d) 1.8 46.5 9.5 (3.0) 44.3 0.5 5.1 Other Revenues (d) — — — — 14.2 — — Total Other Revenues 1.8 46.5 9.5 (3.0) 58.5 0.5 5.1 Total Revenues $ 1,195.3 $ 1,104.2 $ 2,298.0 $ 1,784.0 $ 2,196.5 $ 1,124.4 $ 1,630.3 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $90 million primarily relating to the PPA with KGPCo. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $823 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $46 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial. (d) Amounts include affiliated and nonaffiliated revenues. Nine Months Ended September 30, 2020 AEP Texas AEPTCo APCo I&M OPCo PSO SWEPCo (in millions) Retail Revenues: Residential Revenues $ 447.8 $ — $ 954.4 $ 610.8 $ 1,162.6 $ 463.5 $ 498.7 Commercial Revenues 285.2 — 390.6 376.0 507.3 247.8 351.2 Industrial Revenues 91.4 — 415.0 408.2 199.1 170.8 245.9 Other Retail Revenues 22.3 — 50.9 5.0 9.8 51.2 6.6 Total Retail Revenues 846.7 — 1,810.9 1,400.0 1,878.8 933.3 1,102.4 Wholesale Revenues: Generation Revenues (a) — — 185.3 215.5 — 9.9 106.7 Transmission Revenues (b) 290.4 902.6 91.5 22.1 51.1 20.2 87.5 Total Wholesale Revenues 290.4 902.6 276.8 237.6 51.1 30.1 194.2 Other Revenues from Contracts with Customers (c) 33.4 17.5 46.8 60.6 78.9 23.2 21.1 Total Revenues from Contracts with Customers 1,170.5 920.1 2,134.5 1,698.2 2,008.8 986.6 1,317.7 Other Revenues: Alternative Revenues (d) (0.3) (82.3) (11.9) 5.4 49.6 1.5 0.5 Other Revenues (d) 86.9 — — — 13.3 — — Total Other Revenues 86.6 (82.3) (11.9) 5.4 62.9 1.5 0.5 Total Revenues $ 1,257.1 $ 837.8 $ 2,122.6 $ 1,703.6 $ 2,071.7 $ 988.1 $ 1,318.2 (a) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $85 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial. (b) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $715 million. The remaining affiliated amounts were immaterial. (c) Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $49 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 $ 314.9 $ 199.3 $ 160.3 $ 161.5 $ 836.0 AEP Texas 132.7 — — — 132.7 AEPTCo 331.7 — — — 331.7 APCo 44.9 34.5 26.6 11.6 117.6 I&M 10.0 11.5 8.8 4.5 34.8 OPCo 22.2 10.1 — — 32.3 PSO 3.5 — — — 3.5 SWEPCo 10.1 — — — 10.1
Affiliated Accounts Receivable Contracts with Customers	Company September 30, 2021 December 31, 2020 (in millions) AEPTCo $ 96.4 $ 81.0 APCo 64.1 52.7 I&M 24.6 34.8 OPCo 44.5 45.9 PSO 17.7 7.8 SWEPCo 19.9 11.2

Subsequent Events (Tables)

Subsequent Events (Tables)	9 Months Ended
	Sep. 30, 2021
Major Classes of Assets and Liabilities as presented on balance sheets	September 30, 2021 AEP AEPTCo (in millions) Assets: Accounts Receivable and Accrued Unbilled Revenues $ 24.7 $ 1.6 Fuel, Materials and Supplies 26.5 — Property, Plant and Equipment, Net 2,264.6 164.5 Regulatory Assets 501.7 — Other Classes of Assets that are not Major 43.8 0.3 Total Assets $ 2,861.3 $ 166.4 Liabilities: Accounts Payable $ 51.2 $ 1.5 Long-term Debt Due Within One Year 125.0 — Customer Deposits 31.9 — Deferred Income Taxes 448.3 14.9 Long-term Debt 978.0 — Regulatory Liabilities and Deferred Investment Tax Credits 146.5 7.5 Other Classes of Liabilities that are not Major 93.2 4.2 Total Liabilities $ 1,874.1 $ 28.1

Significant Accounting Matter_3

Significant Accounting Matters (Details) - USD ($) $ / shares in Units, $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020	Dec. 31, 2020	Dec. 31, 2019
Amounts Attributable to AEP Common Shareholders
Earnings Attributable to Common Shareholders		$ 796,000	$ 748,600	$ 1,949,200	$ 1,764,600
Total Basic Earnings Per Share Attributable to AEP Common Shareholders		$ 1.59	$ 1.51	$ 3.90	$ 3.56
Weighted Average Dilutive Effect of:
Total Diluted Earnings Per Share Attributable to AEP Common Shareholders		$ 1.58	$ 1.50	$ 3.89	$ 3.55
Organization and Summary of Significant Accounting Policies (Textuals)
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount				377,000	0
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		$ 1,372,700		$ 1,372,700		$ 392,700
Restricted Cash		54,000		54,000		45,600
Total Cash, Cash Equivalents and Restricted Cash		1,426,700	$ 463,800	1,426,700	$ 463,800	438,300	$ 432,600
Proceeds from Issuance of Debt	[1]			5,115,800
Securities Received as Collateral		309,700		309,700		3,400
Obligation to Return Securities Received as Collateral		$ 38,300		$ 38,300		6,800
Weighted Average Number of Diluted AEP Common Shares Outstanding		502,606,836	497,458,523	500,600,237	496,916,187
Weighted Average Number of Basic AEP Common Shares Outstanding		501,233,680	496,177,968	499,418,278	495,479,190
AEP Texas Inc. [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		$ 100		$ 100		100
Restricted Cash		43,900		43,900		28,700
Total Cash, Cash Equivalents and Restricted Cash		44,000	$ 44,900	44,000	$ 44,900	28,800	157,800
AEP Transmission Co [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		0	0	0	0	0	0
Appalachian Power Co [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		5,000		5,000		5,800
Restricted Cash		10,100		10,100		16,900
Total Cash, Cash Equivalents and Restricted Cash		15,100	13,200	15,100	13,200	22,700	26,800
Securities Received as Collateral		600		600		400
Obligation to Return Securities Received as Collateral		10,700		10,700		0
Indiana Michigan Power Co [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		3,200	2,800	3,200	2,800	3,300	2,000
Securities Received as Collateral		300		300		1,700
Obligation to Return Securities Received as Collateral		17,400		17,400		0
Ohio Power Co [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		6,800		6,800		7,400
Total Cash, Cash Equivalents and Restricted Cash		6,800	6,600	6,800	6,600	7,400	3,700
Public Service Co Of Oklahoma [Member]
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		3,600	3,000	3,600	3,000	2,600	1,500
Southwestern Electric Power Co [Member]
Amounts Attributable to AEP Common Shareholders
Earnings Attributable to Common Shareholders		108,900	87,900	208,100	161,800
Cash, Cash Equivalents and Restricted Cash
Cash and Cash Equivalents		$ 45,000	$ 25,600	$ 45,000	$ 25,600	$ 13,200	$ 1,600
Restricted Stock Units and Performance Share Units [Member]
Weighted Average Dilutive Effect of:
Weighted Average Dilutive Effect of Shares		1,400,000	1,300,000	1,200,000	1,400,000
Dilutive Securities, Effect on Basic Earnings Per Share		$ (0.01)	$ (0.01)	$ (0.01)	$ (0.01)
[1]	Amounts indicated on the statements of cash flows are net of issuance costs and premium or discount and will not tie to the issuance amounts.

Comprehensive Income (Details)

Comprehensive Income (Details) - USD ($) $ in Millions		3 Months Ended						9 Months Ended
		Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Sep. 30, 2021	Sep. 30, 2020
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		$ 97		$ (85.1)	$ (172.9)		$ (147.7)	$ (85.1)	$ (147.7)
Change in Fair Value Recognized in AOCI		225.7			12.1			552.1	(92.2)
Commodity
Generation & Marketing Revenues		4,623			4,066.4			12,730.6	11,307.9
Interest Rate
Interest Expense		303.7			291.3			895.5	877.4
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(60.7)			32.2			(243.4)	132.3
Income Tax (Expense) Benefit		69.8			(1.2)			185.5	57.9
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(48)			25.4			(192.3)	104.5
Net Current Period Other Comprehensive Income (Loss)		177.7	$ 127.8	54.3	37.5	$ 43.6	(68.8)	359.8	12.3
Ending Balance in AOCI		274.7	97		(135.4)	(172.9)		274.7	(135.4)
Pension and OPEB [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		18.9		23	(36.2)		(32.7)	23	(32.7)
Change in Fair Value Recognized in AOCI		0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(2.5)			(2.3)			(7.7)	(6.7)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(2)			(1.8)			(6.1)	(5.3)
Net Current Period Other Comprehensive Income (Loss)		(2)			(1.8)			(6.1)	(5.3)
Ending Balance in AOCI		16.9	18.9		(38)	(36.2)		16.9	(38)
Accumulated Other Comprehensive Income [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Net Current Period Other Comprehensive Income (Loss)		177.7	127.8	54.3	37.5	43.6	(68.8)
Commodity [Member] | Cash Flow Hedges [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		110.3		(60.6)	(81.4)		(103.5)	(60.6)	(103.5)
Change in Fair Value Recognized in AOCI		220.8			10.2			534.5	(48.6)
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(59.7)			33.2			(240.5)	135.4
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(47.2)			26.1			(190)	107
Net Current Period Other Comprehensive Income (Loss)		173.6			36.3			344.5	58.4
Ending Balance in AOCI		283.9	110.3		(45.1)	(81.4)		283.9	(45.1)
Interest Rate [Member] | Cash Flow Hedges [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(32.2)		(47.5)	(55.3)		(11.5)	(47.5)	(11.5)
Change in Fair Value Recognized in AOCI	[1]	4.9			1.9			17.6	(43.6)
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		1.5			1.3			4.8	3.6
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		1.2			1.1			3.8	2.8
Net Current Period Other Comprehensive Income (Loss)		6.1			3			21.4	(40.8)
Ending Balance in AOCI		(26.1)	(32.2)		(52.3)	(55.3)		(26.1)	(52.3)
Generation and Marketing [Member]
Commodity
Generation & Marketing Revenues		617.4			464.8			1,641.6	1,223.4
Reclassifications from Accumulated Other Comprehensive Income [Member]
Interest Rate
Interest Expense	[2]	1.5			1.3			4.8	3.6
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(4.8)			(4.9)			(14.5)	(14.4)
Amortization of Actuarial (Gains) Losses		2.3			2.6			6.8	7.7
Income Tax (Expense) Benefit		(12.7)			6.8			(51.1)	27.8
Reclassifications from Accumulated Other Comprehensive Income [Member] | Pension and OPEB [Member]
Interest Rate
Interest Expense	[2]	0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(4.8)			(4.9)			(14.5)	(14.4)
Amortization of Actuarial (Gains) Losses		2.3			2.6			6.8	7.7
Income Tax (Expense) Benefit		(0.5)			(0.5)			(1.6)	(1.4)
Reclassifications from Accumulated Other Comprehensive Income [Member] | Commodity [Member] | Cash Flow Hedges [Member]
Interest Rate
Interest Expense	[2]	0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		0			0			0	0
Amortization of Actuarial (Gains) Losses		0			0			0	0
Income Tax (Expense) Benefit		(12.5)			7.1			(50.5)	28.4
Reclassifications from Accumulated Other Comprehensive Income [Member] | Interest Rate [Member] | Cash Flow Hedges [Member]
Interest Rate
Interest Expense	[2]	1.5			1.3			4.8	3.6
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		0			0			0	0
Amortization of Actuarial (Gains) Losses		0			0			0	0
Income Tax (Expense) Benefit		0.3			0.2			1	0.8
Reclassifications from Accumulated Other Comprehensive Income [Member] | Generation and Marketing [Member]
Commodity
Generation & Marketing Revenues	[2]				(0.1)			0.7	(0.3)
Reclassifications from Accumulated Other Comprehensive Income [Member] | Generation and Marketing [Member] | Pension and OPEB [Member]
Commodity
Generation & Marketing Revenues	[2]				0			0	0
Reclassifications from Accumulated Other Comprehensive Income [Member] | Generation and Marketing [Member] | Commodity [Member] | Cash Flow Hedges [Member]
Commodity
Generation & Marketing Revenues	[2]				(0.1)			0.7	(0.3)
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	0
Reclassifications from Accumulated Other Comprehensive Income [Member] | Purchased Electricity for Resale [Member]
Commodity
Purchased Electricity for Resale	[2]	(59.7)			33.3			(241.2)	135.7
Reclassifications from Accumulated Other Comprehensive Income [Member] | Purchased Electricity for Resale [Member] | Pension and OPEB [Member]
Commodity
Purchased Electricity for Resale	[2]	0			0			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]	(59.7)			33.3			(241.2)	135.7
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			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		(1)			(1)			(5)	6
AEP Texas Inc. [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(8.3)		(8.9)	(12.2)		(12.8)	(8.9)	(12.8)
Change in Fair Value Recognized in AOCI		0			0			0	0
Interest Rate
Interest Expense		44.2			44.5			132.5	129.2
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0.4			0.4			1.1	1.1
Income Tax (Expense) Benefit		14.6			1.1			31.6	(10.1)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0.3			0.3			0.9	0.9
Net Current Period Other Comprehensive Income (Loss)		0.3	0.3	0.3	0.3	0.3	0.3	0.9	0.9
Ending Balance in AOCI		(8)	(8.3)		(11.9)	(12.2)		(8)	(11.9)
AEP Texas Inc. [Member] | Pension and OPEB [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(6.5)		(6.6)	(9.3)		(9.4)	(6.6)	(9.4)
Change in Fair Value Recognized in AOCI		0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0			0			0.1	0.1
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0			0			0.1	0.1
Net Current Period Other Comprehensive Income (Loss)		0			0			0.1	0.1
Ending Balance in AOCI		(6.5)	(6.5)		(9.3)	(9.3)		(6.5)	(9.3)
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	0.3	0.3	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		(1.8)		(2.3)	(2.9)		(3.4)	(2.3)	(3.4)
Change in Fair Value Recognized in AOCI		0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0.4			0.4			1	1
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0.3			0.3			0.8	0.8
Net Current Period Other Comprehensive Income (Loss)		0.3			0.3			0.8	0.8
Ending Balance in AOCI		(1.5)	(1.8)		(2.6)	(2.9)		(1.5)	(2.6)
AEP Texas Inc. [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member]
Interest Rate
Interest Expense	[2]	0.4			0.4			1	1
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(0.1)			(0.1)			(0.1)	(0.1)
Amortization of Actuarial (Gains) Losses		0.1			0.1			0.2	0.2
Income Tax (Expense) Benefit		0.1			0.1			0.2	0.2
AEP Texas Inc. [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member] | Pension and OPEB [Member]
Interest Rate
Interest Expense	[2]	0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(0.1)			(0.1)			(0.1)	(0.1)
Amortization of Actuarial (Gains) Losses		0.1			0.1			0.2	0.2
Income Tax (Expense) Benefit		0			0			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]	0.4			0.4			1	1
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		0			0			0	0
Amortization of Actuarial (Gains) Losses		0			0			0	0
Income Tax (Expense) Benefit		0.1			0.1			0.2	0.2
Appalachian Power Co [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		13.9		7.2	(1.9)		5	7.2	5
Change in Fair Value Recognized in AOCI		0.2			0.7			9.3	(3.8)
Interest Rate
Interest Expense		52.8			55			160.6	162.2
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(1.8)			(1.4)			(4.9)	(4.4)
Income Tax (Expense) Benefit		3.6			(7.7)			19.3	(5.2)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(1.5)			(1)			(3.9)	(3.4)
Net Current Period Other Comprehensive Income (Loss)		(1.3)	(1.2)	7.9	(0.3)	(1.8)	(5.1)	5.4	(7.2)
Ending Balance in AOCI		12.6	13.9		(2.2)	(1.9)		12.6	(2.2)
Appalachian Power Co [Member] | Pension and OPEB [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		5.9		8	2.2		4.1	8	4.1
Change in Fair Value Recognized in AOCI		0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(1.2)			(1.2)			(3.9)	(3.6)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(1)			(0.9)			(3.1)	(2.8)
Net Current Period Other Comprehensive Income (Loss)		(1)			(0.9)			(3.1)	(2.8)
Ending Balance in AOCI		4.9	5.9		1.3	2.2		4.9	1.3
Appalachian Power Co [Member] | Accumulated Other Comprehensive Income [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Net Current Period Other Comprehensive Income (Loss)		(1.3)	(1.2)	7.9	(0.3)	(1.8)	(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		8		(0.8)	(4.1)		0.9	(0.8)	0.9
Change in Fair Value Recognized in AOCI		0.2			0.7			9.3	(3.8)
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(0.6)			(0.2)			(1)	(0.8)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(0.5)			(0.1)			(0.8)	(0.6)
Net Current Period Other Comprehensive Income (Loss)		(0.3)			0.6			8.5	(4.4)
Ending Balance in AOCI		7.7	8		(3.5)	(4.1)		7.7	(3.5)
Appalachian Power Co [Member] | Purchased Electricity for Resale [Member]
Commodity
Purchased Electricity for Resale		82.4			67.5			248.4	240.5
Appalachian Power Co [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member]
Interest Rate
Interest Expense	[2]	(0.6)			(0.2)			(1)	(0.8)
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(1.2)			(1.3)			(3.9)	(4)
Amortization of Actuarial (Gains) Losses					0.1				0.4
Income Tax (Expense) Benefit		(0.3)			(0.4)			(1)	(1)
Appalachian Power Co [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member] | Pension and OPEB [Member]
Interest Rate
Interest Expense	[2]	0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(1.2)			(1.3)			(3.9)	(4)
Amortization of Actuarial (Gains) Losses					0.1				0.4
Income Tax (Expense) Benefit		(0.2)			(0.3)			(0.8)	(0.8)
Appalachian Power Co [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member] | Interest Rate [Member] | Cash Flow Hedges [Member]
Interest Rate
Interest Expense	[2]	(0.6)			(0.2)			(1)	(0.8)
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		0			0			0	0
Amortization of Actuarial (Gains) Losses					0				0
Income Tax (Expense) Benefit		(0.1)			(0.1)			(0.2)	(0.2)
Indiana Michigan Power Co [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		(6.2)		(7)	(10.8)		(11.6)	(7)	(11.6)
Change in Fair Value Recognized in AOCI		0			0			0	0
Interest Rate
Interest Expense		30.2			26.9			86.6	85.7
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0.5			0.4			1.5	1.4
Income Tax (Expense) Benefit		(1.8)			3.2			(8.3)	8.3
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0.4			0.3			1.2	1.1
Net Current Period Other Comprehensive Income (Loss)		0.4	0.3	0.5	0.3	0.4	0.4	1.2	1.1
Ending Balance in AOCI		(5.8)	(6.2)		(10.5)	(10.8)		(5.8)	(10.5)
Indiana Michigan Power Co [Member] | Pension and OPEB [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		1.2		1.3	(1.7)		(1.7)	1.3	(1.7)
Change in Fair Value Recognized in AOCI		0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0			(0.1)			(0.1)	(0.1)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0			(0.1)			(0.1)	(0.1)
Net Current Period Other Comprehensive Income (Loss)		0			(0.1)			(0.1)	(0.1)
Ending Balance in AOCI		1.2	1.2		(1.8)	(1.7)		1.2	(1.8)
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)		0.4	0.3	0.5	0.3	0.4	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		(7.4)		(8.3)	(9.1)		(9.9)	(8.3)	(9.9)
Change in Fair Value Recognized in AOCI		0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0.5			0.5			1.6	1.5
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0.4			0.4			1.3	1.2
Net Current Period Other Comprehensive Income (Loss)		0.4			0.4			1.3	1.2
Ending Balance in AOCI		(7)	(7.4)		(8.7)	(9.1)		(7)	(8.7)
Indiana Michigan Power Co [Member] | Purchased Electricity for Resale [Member]
Commodity
Purchased Electricity for Resale		44.9			37.5			131.9	128.1
Indiana Michigan Power Co [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member]
Interest Rate
Interest Expense	[2]	0.5			0.5			1.6	1.5
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(0.2)			(0.3)			(0.6)	(0.6)
Amortization of Actuarial (Gains) Losses		0.2			0.2			0.5	0.5
Income Tax (Expense) Benefit		0.1			0.1			0.3	0.3
Indiana Michigan Power Co [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member] | Pension and OPEB [Member]
Interest Rate
Interest Expense	[2]	0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(0.2)			(0.3)			(0.6)	(0.6)
Amortization of Actuarial (Gains) Losses		0.2			0.2			0.5	0.5
Income Tax (Expense) Benefit		0			0			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]	0.5			0.5			1.6	1.5
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		0			0			0	0
Amortization of Actuarial (Gains) Losses		0			0			0	0
Income Tax (Expense) Benefit		0.1			0.1			0.3	0.3
Ohio Power Co [Member]
Interest Rate
Interest Expense		32.9			29.4			96.2	88.4
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit		8.9			18.1			26.2	39
Ohio Power Co [Member] | Purchased Electricity for Resale [Member]
Commodity
Purchased Electricity for Resale		184.7			149.3			513.6	412.3
Public Service Co Of Oklahoma [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI				0.1				0.1
Interest Rate
Interest Expense		16.2			14.6			44.7	45.9
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit		(2.1)			1.3			(3.7)	2.1
Net Current Period Other Comprehensive Income (Loss)				(0.1)	(0.3)	(0.3)	(0.2)
Ending Balance in AOCI		0						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)	(0.3)	(0.3)	(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		0.1	0.6		1.1	0.1	1.1
Change in Fair Value Recognized in AOCI		0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0			(0.3)			(0.1)	(1)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0			(0.3)			(0.1)	(0.8)
Net Current Period Other Comprehensive Income (Loss)		0			(0.3)			(0.1)	(0.8)
Ending Balance in AOCI		0	0		0.3	0.6		0	0.3
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			(0.3)			(0.1)	(1)
Amortization Of Pension And Other Postretirement Benefit Plans
Income Tax (Expense) Benefit		0			0			0	(0.2)
Southwestern Electric Power Co [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		1.9		1.9	(1.3)		(1.3)	1.9	(1.3)
Change in Fair Value Recognized in AOCI		0			0			0	0
Interest Rate
Interest Expense		31.7			29.3			92.4	89.1
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(0.1)			0			(0.1)	0
Income Tax (Expense) Benefit		6.3			10.8			19	12.5
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(0.1)			0			(0.1)	0
Net Current Period Other Comprehensive Income (Loss)		(0.1)			0			(0.1)	0
Ending Balance in AOCI		1.8	1.9		(1.3)	(1.3)		1.8	(1.3)
Southwestern Electric Power Co [Member] | Pension and OPEB [Member]
Changes in Accumulated Other Comprehensive Income (Loss) by Component
Beginning Balance in AOCI		1.4		2.2	(0.2)		0.5	2.2	0.5
Change in Fair Value Recognized in AOCI		0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		(0.5)			(0.5)			(1.5)	(1.4)
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		(0.4)			(0.4)			(1.2)	(1.1)
Net Current Period Other Comprehensive Income (Loss)		(0.4)			(0.4)			(1.2)	(1.1)
Ending Balance in AOCI		1	1.4		(0.6)	(0.2)		1	(0.6)
Southwestern Electric Power Co [Member] | Accumulated Other Comprehensive Income [Member]
Amortization Of Pension And Other Postretirement Benefit Plans
Net Current Period Other Comprehensive Income (Loss)		(0.1)
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		0.5		$ (0.3)	(1.1)		$ (1.8)	(0.3)	(1.8)
Change in Fair Value Recognized in AOCI		0			0			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Reclassification from AOCI, before Income Tax (Expense) Benefit		0.4			0.5			1.4	1.4
Reclassification from AOCI, Net of Income Tax (Expense) Benefit		0.3			0.4			1.1	1.1
Net Current Period Other Comprehensive Income (Loss)		0.3			0.4			1.1	1.1
Ending Balance in AOCI		0.8	$ 0.5		(0.7)	$ (1.1)		0.8	(0.7)
Southwestern Electric Power Co [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member]
Interest Rate
Interest Expense	[2]	0.4			0.5			1.4	1.4
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(0.5)			(0.5)			(1.5)	(1.5)
Amortization of Actuarial (Gains) Losses					0				0.1
Income Tax (Expense) Benefit		0			0			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			0	0
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		(0.5)			(0.5)			(1.5)	(1.5)
Amortization of Actuarial (Gains) Losses					0				0.1
Income Tax (Expense) Benefit		(0.1)			(0.1)			(0.3)	(0.3)
Southwestern Electric Power Co [Member] | Reclassifications from Accumulated Other Comprehensive Income [Member] | Interest Rate [Member] | Cash Flow Hedges [Member]
Interest Rate
Interest Expense	[2]	0.4			0.5			1.4	1.4
Amortization Of Pension And Other Postretirement Benefit Plans
Amortization of Prior Service Cost (Credit)		0			0			0	0
Amortization of Actuarial (Gains) Losses					0				0
Income Tax (Expense) Benefit		$ 0.1			$ 0.1			$ 0.3	$ 0.3
[1]	The change in fair value includes $(1) million and $(1) million, respectively, for the three months ended September 30, 2021 and 2020 and $(5) million and $6 million, respectively, for the nine months ended September 30, 2021 and 2020 related to AEP's investment in joint venture wind farms acquired as part of the purchase of Sempra Renewables LLC.
[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		3 Months Ended				9 Months Ended
		Sep. 30, 2021	Jun. 30, 2021	Mar. 31, 2021	Mar. 31, 2020	Sep. 30, 2021	Sep. 30, 2020	Dec. 31, 2020
Public Utilities, General Disclosures [Line Items]
Property, Plant and Equipment		$ 24,135.9				$ 24,135.9		$ 23,133.9
Accumulated Depreciation		21,877				21,877		20,411.4
Net Investment		66,691.2				66,691.2		63,901.6
Materials and Supplies		688.4				688.4		680.6
Asset Retirement Obligation, Revision of Estimate	[1],[2],[3],[4]					75.1
Regulatory Assets, Noncurrent		5,031.5				5,031.5		3,527
Customers		701.2				701.2		613.6
Proceeds from Issuance of Debt	[5]					5,115.8
Fuel Over Under Recovery Net						1,356.8	$ (27.4)
Senior Unsecured Notes [Member]
Public Utilities, General Disclosures [Line Items]
Proceeds from Issuance of Debt	[5]					175
February 2021 Storm Event
Public Utilities, General Disclosures [Line Items]
Capitalized Storm Costs						66.6
Incremental Other Operation and Maintenance Expenses						7.2
Deferred Storm Costs as a Regulated Asset						141.6
Total Estimated February 2021 Storm Restoration Expenditures						215.4
February 2021 Severe Storm Fuel Costs
Public Utilities, General Disclosures [Line Items]
Customers		55.8				55.8
Total Estimated 2021 February Winter Storm Fuel Costs		1,162.1				1,162.1
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		1,621.1				1,621.1		1,529.3
Net Investment		10,313.4				10,313.4		9,813.6
Materials and Supplies		72.5				72.5		70
Regulatory Assets, Noncurrent		290.4				290.4		266.8
Customers		142.1				142.1		112.8
AEP Texas Inc. [Member] | Senior Unsecured Notes [Member]
Public Utilities, General Disclosures [Line Items]
Proceeds from Issuance of Debt	[5]					450
AEP Transmission Co [Member]
Public Utilities, General Disclosures [Line Items]
Accumulated Depreciation		730.4				730.4		572.8
Net Investment		11,628.9				11,628.9		10,772.8
Materials and Supplies		9				9		8.5
Regulatory Assets, Noncurrent		10.1				10.1		15.1
Customers		31				31		22.9
Capital Contribution from Member			$ 60	$ 124	$ 185
AEP Transmission Co [Member] | Additional Paid-in Capital [Member]
Public Utilities, General Disclosures [Line Items]
Capital Contribution from Member			60	124	$ 185
AEP Transmission Co [Member] | Senior Unsecured Notes [Member]
Public Utilities, General Disclosures [Line Items]
Proceeds from Issuance of Debt	[5]					450
Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Property, Plant and Equipment		6,670.8				6,670.8		6,633.7
Accumulated Depreciation		4,973.1				4,973.1		4,716.2
Net Investment		11,621.8				11,621.8		11,394.1
Materials and Supplies		100.3				100.3		99.6
Asset Retirement Obligation, Revision of Estimate	[2],[3]					84.7
Regulatory Assets, Noncurrent		818.6				818.6		686.3
Customers		119.3				119.3		142.8
Fuel Over Under Recovery Net						43.9	(38.8)
Appalachian Power Co [Member] | Senior Unsecured Notes [Member]
Public Utilities, General Disclosures [Line Items]
Proceeds from Issuance of Debt						500
Appalachian Power Co [Member] | February 2021 Storm Event | Virginia
Public Utilities, General Disclosures [Line Items]
Capitalized Storm Costs						8.1
Incremental Other Operation and Maintenance Expenses						2.2
Deferred Storm Costs as a Regulated Asset						6.6
Total Estimated February 2021 Storm Restoration Expenditures						16.9
Appalachian Power Co [Member] | February 2021 Storm Event | West Virginia
Public Utilities, General Disclosures [Line Items]
Capitalized Storm Costs						23.5
Incremental Other Operation and Maintenance Expenses						0
Deferred Storm Costs as a Regulated Asset						47
Total Estimated February 2021 Storm Restoration Expenditures						70.5
Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Property, Plant and Equipment		5,329.6				5,329.6		5,264.7
Accumulated Depreciation		3,811.9				3,811.9		3,552.5
Net Investment		7,063.8				7,063.8		7,052.3
Materials and Supplies		172.2				172.2		175.8
Regulatory Assets, Noncurrent		436.1				436.1		404.8
Customers		39.8				39.8		44
Fuel Over Under Recovery Net						18	(23.4)
Indiana Michigan Power Co [Member] | Senior Unsecured Notes [Member]
Public Utilities, General Disclosures [Line Items]
Proceeds from Issuance of Debt	[5]					450
Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Accumulated Depreciation		2,438.7				2,438.7		2,350
Net Investment		7,798.4				7,798.4		7,452.1
Materials and Supplies		70.9				70.9		66.9
Regulatory Assets, Noncurrent		343.8				343.8		385.8
Customers		31				31		50
Ohio Power Co [Member] | Senior Unsecured Notes [Member]
Public Utilities, General Disclosures [Line Items]
Proceeds from Issuance of Debt	[5]					450
Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Property, Plant and Equipment		1,795.2				1,795.2		1,480.7
Accumulated Depreciation		1,682.6				1,682.6		1,605.6
Net Investment		4,723.7				4,723.7		4,320
Materials and Supplies		54.4				54.4		54
Regulatory Assets, Noncurrent		1,052.3				1,052.3		375
Customers		29.7				29.7		30.8
Capital Contribution from Member			200	425
Fuel Over Under Recovery Net						776.4	46.6
Public Service Co Of Oklahoma [Member] | Additional Paid-in Capital [Member]
Public Utilities, General Disclosures [Line Items]
Capital Contribution from Member			200	425
Public Service Co Of Oklahoma [Member] | Senior Unsecured Notes [Member]
Public Utilities, General Disclosures [Line Items]
Proceeds from Issuance of Debt	[5]					400
Public Service Co Of Oklahoma [Member] | February 2021 Severe Storm Fuel Costs
Public Utilities, General Disclosures [Line Items]
Recommended Disallowance from Staff or Intervenors						40
Customers		0				0
Total Estimated 2021 February Winter Storm Fuel Costs		673.2				$ 673.2
Interim WACC						0.75%
Public Service Co Of Oklahoma [Member] | February 2021 Severe Storm Fuel Costs | Minimum [Member]
Public Utilities, General Disclosures [Line Items]
Intervenor Recommended WACC						0.75%
Public Service Co Of Oklahoma [Member] | February 2021 Severe Storm Fuel Costs | Maximum [Member]
Public Utilities, General Disclosures [Line Items]
Intervenor Recommended WACC						2.32%
Public Service Co Of Oklahoma [Member] | Northeastern Plant, Unit 3 | Generating Units Probable of Abandonment [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		175.1				$ 175.1
Accelerated Depreciation Regulatory Asset		123.6				123.6
Cost of Removal Regulatory Liability	[6]	20				$ 20
Expected Retirement Date	[7]					2026
Depreciation	[8]					$ 14.9
Public Service Co Of Oklahoma [Member] | February 2021 Severe Storm Fuel Costs
Public Utilities, General Disclosures [Line Items]
Capital Contribution from Member			125	425
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]
Property, Plant and Equipment		5,065.5				5,065.5		4,681.4
Accumulated Depreciation		3,478.5				3,478.5		3,158.5
Net Investment		7,363.9				7,363.9		7,088.2
Materials and Supplies		86.8				86.8		95.8
Regulatory Assets, Noncurrent		1,068				1,068		403.1
Customers		76.2				76.2		27.1
Capital Contribution from Member		105	75	100
Fuel Over Under Recovery Net						506.8	$ (16.3)
Net Under-Recovered Fuel Costs		39				39
Southwestern Electric Power Co [Member] | Additional Paid-in Capital [Member]
Public Utilities, General Disclosures [Line Items]
Capital Contribution from Member		105	$ 75	100
Southwestern Electric Power Co [Member] | Senior Unsecured Notes [Member]
Public Utilities, General Disclosures [Line Items]
Proceeds from Issuance of Debt	[5]					500
Southwestern Electric Power Co [Member] | 2020 Texas Fuel Reconciliation
Public Utilities, General Disclosures [Line Items]
Amount of Fuel Costs Under Review		1,700				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				616
Recommended Disallowance from Staff or Intervenors						125
Reduction in Recoverable Fuel Costs						10
Southwestern Electric Power Co [Member] | February 2021 Storm Event
Public Utilities, General Disclosures [Line Items]
Capitalized Storm Costs						6
Incremental Other Operation and Maintenance Expenses						0
Deferred Storm Costs as a Regulated Asset						45.4
Total Estimated February 2021 Storm Restoration Expenditures						51.4
Southwestern Electric Power Co [Member] | February 2021 Severe Storm Fuel Costs
Public Utilities, General Disclosures [Line Items]
Customers		55.8				55.8
Total Estimated 2021 February Winter Storm Fuel Costs		488.9				488.9
Amount Billed to Wholesale Customers						$ 104
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%
Intervenor Recommended WACC						1.65%
Interim WACC						0.80%
Southwestern Electric Power Co [Member] | February 2021 Severe Storm Fuel Costs | Louisiana Jurisdiction [Member]
Public Utilities, General Disclosures [Line Items]
Interim WACC						3.25%
Southwestern Electric Power Co [Member] | February 2021 Severe Storm Fuel Costs | Texas
Public Utilities, General Disclosures [Line Items]
Requested Weighted Average Cost of Capital						7.18%
Southwestern Electric Power Co [Member] | February 2021 Severe Storm Fuel Costs | Texas | Minimum [Member]
Public Utilities, General Disclosures [Line Items]
Intervenor Recommended WACC						0.082%
Southwestern Electric Power Co [Member] | February 2021 Severe Storm Fuel Costs | Texas | Maximum [Member]
Public Utilities, General Disclosures [Line Items]
Intervenor Recommended WACC						1.625%
Southwestern Electric Power Co [Member] | Dolet Hills Power Station [Member] | Generating Units Probable of Abandonment [Member]
Public Utilities, General Disclosures [Line Items]
Net Investment		13				$ 13
Accelerated Depreciation Regulatory Asset		126.8				126.8
Cost of Removal Regulatory Liability		24.4				$ 24.4
Expected Retirement Date	[9]					2021
Depreciation	[8]					$ 7.8
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%
Share of Net Investment in Dolet Hills Power Station		146				$ 146
Dolet Hills Lignite Company Unbilled Fixed Costs		44				44
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		203				203
Pirkey Power Plant and Sabine Unbilled Fixed Costs		108				108
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		135.4				135.4
Accelerated Depreciation Regulatory Asset		68				68
Cost of Removal Regulatory Liability		39.2				$ 39.2
Expected Retirement Date	[10]					2023
Depreciation	[8]					$ 13.5
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		493.7				493.7
Accelerated Depreciation Regulatory Asset		35.6				35.6
Cost of Removal Regulatory Liability	[11]	58.2				$ 58.2
Expected Retirement Date	[12]					2028
Depreciation	[8]					$ 33.1
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] | Other Long Term Debt [Member]
Public Utilities, General Disclosures [Line Items]
Proceeds from Issuance of Debt	[5]					150
Kentucky Power Co [Member] | February 2021 Storm Event
Public Utilities, General Disclosures [Line Items]
Capitalized Storm Costs						29
Incremental Other Operation and Maintenance Expenses						5
Deferred Storm Costs as a Regulated Asset						42.6
Total Estimated February 2021 Storm Restoration Expenditures						76.6
Regulatory Assets Pending Final Regulatory Approval [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		1,904.9				1,904.9		442.2
Regulatory Assets Pending Final Regulatory Approval [Member] | AEP Texas Inc. [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		57.8				57.8		32.9
Regulatory Assets Pending Final Regulatory Approval [Member] | Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		93.9				93.9		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				3.4		4.3
Regulatory Assets Pending Final Regulatory Approval [Member] | Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		7.5				7.5		8.4
Regulatory Assets Pending Final Regulatory Approval [Member] | Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		736.4				736.4		50.5
Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		906				906		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	[13]	1,106.3				1,106.3
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		33				33		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		45.9				45.9		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		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		126.8				126.8		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		25.5				25.5		22.8
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | February 2021 Severe Storm Fuel Costs
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent	[14]	1,106.3				1,106.3		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		68				68		12.2
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Welsh Unit 1 and 3 Accelerated Depreciation
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		35.6				35.6		3.6
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Dolet Hills Power Station Fuel Costs
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		20.3				20.3		0
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		16.6				16.6		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		6.6				6.6		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		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	[13]	673.2				673.2
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		33				33		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	[15]	673.2				673.2		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	[13],[16]	433.1				433.1
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member] | February 2021 Severe Storm Fuel Costs | Arkansas
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		107				107
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member] | February 2021 Severe Storm Fuel Costs | Louisiana Jurisdiction [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		151				151
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member] | February 2021 Severe Storm Fuel Costs | Texas
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		175				175
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		126.8				126.8		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		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		2.3				2.3		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	[17]	433.1				433.1		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		68				68		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		35.6				35.6		3.6
Regulatory Assets Currently Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Southwestern Electric Power Co [Member] | Dolet Hills Power Station Fuel Costs
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		20.3				20.3		0
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		14				14		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		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		325.8				325.8		134.2
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Asset Retirement Obligation - Louisiana [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		10				10		9.1
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		32.6				32.6		27.4
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		3.9				3.9		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		22.7				22.7		0.8
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		5.3				5.3		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				4.1		0
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | AEP Texas Inc. [Member] | Vegetation Management Programs
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		5.2				5.2		3.8
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		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		59.8				59.8		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		0.4				0.4		1.5
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Appalachian Power Co [Member] | Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		1.2				1.2		0
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		0				0		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		1.7				1.7		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		1.7				1.7		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		1.9				1.9		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		5.5				5.5		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				0.1		0
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Public Service Co Of Oklahoma [Member] | Storm Related Costs [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		29.3				29.3		15.8
Regulatory Assets Currently Not Earning Return [Member] | Regulatory Assets Pending Final Regulatory Approval [Member] | Public Service Co Of Oklahoma [Member] | Other Regulatory Assets Not Yet Being Recovered [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory Assets, Noncurrent		0.9				0.9		0.3
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		10				10		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		19.3				19.3		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		$ 155.4				$ 155.4		$ 99.3
[1]	Includes ARO related to Sabine and DHLC.
[2]	Includes ARO related to asbestos removal.
[3]	Includes ARO related to ash disposal facilities.
[4]	Includes ARO related to nuclear decommissioning costs for the Cook Plant of $1.85 billion and $1.80 billion as of September 30, 2021 and December 31, 2020, respectively.
[5]	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.
[6]	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.
[7]	Northeastern Plant, Unit 3 is currently being recovered through 2040.
[8]	Represents the amount of annual depreciation that has been collected from customers over the prior 12-month period
[9]	Dolet Hills Power Station is currently being recovered through 2026 in the Louisiana jurisdiction and through 2046 in the Arkansas and Texas jurisdictions.
[10]	Pirkey Power Plant is currently being recovered through 2025 in the Louisiana jurisdiction and through 2045 in the Arkansas and Texas jurisdictions.
[11]	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.
[12]	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.
[13]	These costs were deferred as regulatory assets as of September 30, 2021.
[14]	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.
[15]	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.
[16]	SWEPCo’s balance consists of $107 million, $151 million and $175 million related to the Arkansas, Louisiana and Texas jurisdictions, respectively.
[17]	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	9 Months Ended
	Sep. 30, 2021	Dec. 31, 2020
Public Utilities, General Disclosures [Line Items]
Property, Plant and Equipment, Net	$ 66,691.2	$ 63,901.6
AEP Transmission Co [Member]
Public Utilities, General Disclosures [Line Items]
Property, Plant and Equipment, Net	11,628.9	10,772.8
Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Property, Plant and Equipment, Net	11,621.8	11,394.1
Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Property, Plant and Equipment, Net	7,063.8	7,052.3
Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Property, Plant and Equipment, Net	$ 7,798.4	$ 7,452.1
Kentucky Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Ownership Interest in Mitchell Power Plant	50.00%
Wheeling Power Company
Public Utilities, General Disclosures [Line Items]
Ownership Interest in Mitchell Power Plant	50.00%
2017-2019 Virginia Triennial Review [Member] | Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
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] | Ohio Power Co [Member]
Public Utilities, General Disclosures [Line Items]
DIR Revenue Amount above 2019 Authorized Limit	17
Adjusted Dir Revenue Amount above 2019 Authorized Limit	3
CCR/ELG Filings | Mitchell Power Plant
Public Utilities, General Disclosures [Line Items]
Investment in CCR/ELG	132
Alternative CCR/ELG Investment	25
CCR/ELG Filings | Appalachian Power Co [Member]
Public Utilities, General Disclosures [Line Items]
ELG Investment	19
Net Book Value of Amos and Mountaineer Plants - Virginia	1,500
Estimated ELG Costs	177
CCR/ELG Filings | Kentucky Power Co [Member] | Mitchell Power Plant
Public Utilities, General Disclosures [Line Items]
ELG Investment	2
Property, Plant and Equipment, Net	587
2021 Indiana Base Rate Case | Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Annual Increase	$ 104
Requested Return on Equity	10.00%
Phased In Annual Increase 2022	$ 73
Phased in Annual Increase 2023	31
Amount of Increase Related to Annual Depreciation Expense	7
Indiana Earnings Test Filings | Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
FAC Credit to Customers	$ 9
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
Minimum [Member] | 2021 Indiana Base Rate Case | Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Intervenor Recommended Return on Common Equity	9.10%
Intervenor Recommended Annual Increase	$ 13
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
Maximum [Member] | 2021 Indiana Base Rate Case | Indiana Michigan Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Intervenor Recommended Return on Common Equity	9.30%
Intervenor Recommended Annual Increase	$ 68

Rate Matters West Companies (De

Rate Matters West Companies (Details) $ in Millions	9 Months Ended
	Sep. 30, 2021USD ($)customer	Dec. 31, 2020USD ($)
Public Utilities, General Disclosures [Line Items]
Construction Work in Progress	$ 4,151	$ 4,025.7
AEP Share of Independence Energy Connection Capital Costs	79
AEP Texas Inc. [Member]
Public Utilities, General Disclosures [Line Items]
Construction Work in Progress	539.4	614.1
Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Construction Work in Progress	127.7	128.7
Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Construction Work in Progress	195.5	$ 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	$ 229
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	$ 1,300
2012 Texas Base Rate Case [Member] | Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
2013 Reversal Of Previously Recorded Regulatory Disallowances	114
Estimated Reduced Annual Revenues	15
2012 Texas Base Rate Case [Member] | Southwestern Electric Power Co [Member] | Minimum [Member]
Public Utilities, General Disclosures [Line Items]
Estimated Turk AFUDC Disallowance	80
Estimated Turk AFUDC Refunds	0
2012 Texas Base Rate Case [Member] | Southwestern Electric Power Co [Member] | Maximum [Member]
Public Utilities, General Disclosures [Line Items]
Estimated Turk AFUDC Disallowance	100
Estimated Turk AFUDC Refunds	$ 160
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	89
Capitalized Storm Costs	$ 18
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	$ 92
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	$ 18
Capitalized Storm Costs	2
2020 Texas Base Rate Case [Member] | Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Annual Increase	$ 105
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
Revised Requested Annual Increase	100
Revised Requested Net Annual Increase	85
Proposal for Decision Rate Increase	$ 41
Proposal for Decision Return on Equity	9.45%
2020 Texas Base Rate Case [Member] | Southwestern Electric Power Co [Member] | Capitalized Vegetation Management Expenses [Member]
Public Utilities, General Disclosures [Line Items]
Proposal for Decision Disallowance	$ 5
2020 Texas Base Rate Case [Member] | Southwestern Electric Power Co [Member] | Catastrophe Storm Reserve
Public Utilities, General Disclosures [Line Items]
Proposal for Decision Disallowance	2
2020 Louisiana Base Rate Case | Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Annual Increase	134
Staff Recommended Annual Rate Increase	$ 6
Requested Return on Equity	10.35%
Amount of Increase Related to Annual Depreciation Expense	$ 32
Staff Recommended Return on Common Equity	9.10%
Storm Expenses to be Requested in Separate Filing	$ 152
Revised Requested Annual Increase	114
Requested Annual Increase in Rebuttal	$ 95
2020 Louisiana Base Rate Case | Southwestern Electric Power Co [Member] | Minimum [Member]
Public Utilities, General Disclosures [Line Items]
Intervenor Recommended Return on Common Equity	9.35%
2020 Louisiana Base Rate Case | Southwestern Electric Power Co [Member] | Maximum [Member]
Public Utilities, General Disclosures [Line Items]
Intervenor Recommended Return on Common Equity	9.80%
2021 Oklahoma Base Rate Case | Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Requested Annual Increase	$ 172
Requested Return on Equity	10.00%
Amount of Increase Related to Annual Depreciation Expense	$ 57
Amount of Increase Related to SPP Expenses	31
Proposed Grid Transformation Plan	100
Revised Requested Annual Increase	128
Proposed Settlement Annual Rate Increase	$ 51
Proposed Settlement Agreement ROE	9.40%
Recommended Disallowance from Staff or Intervenors	$ 41
2021 Oklahoma Base Rate Case | Public Service Co Of Oklahoma [Member] | Minimum [Member]
Public Utilities, General Disclosures [Line Items]
Staff and Intervenor Recommended Base Rate Increase/Decrease	$ 44
Staff and Intervenor Recommended Return on Equity	9.00%
2021 Oklahoma Base Rate Case | Public Service Co Of Oklahoma [Member] | Maximum [Member]
Public Utilities, General Disclosures [Line Items]
Staff and Intervenor Recommended Base Rate Increase/Decrease	$ 74
Staff and Intervenor Recommended Return on Equity	9.40%
2021 Oklahoma Base Rate Case | Oklaunion Power Station Accelerated Depreciation [Member] | Public Service Co Of Oklahoma [Member]
Public Utilities, General Disclosures [Line Items]
Amount of Increase Related to Annual Depreciation Expense	$ 45
2021 Arkansas Rate Case | Southwestern Electric Power Co [Member]
Public Utilities, General Disclosures [Line Items]
Requested Annual Increase	$ 85
Requested Return on Equity	10.35%
Amount of Increase Related to Annual Depreciation Expense	$ 14
Amount of Increase Related to SPP Expenses	6
Amount of Increase Related to North Central Wind Facilities	$ 41

Commitments, Guarantees and C_3

Commitments, Guarantees and Contingencies (Details) $ in Millions	9 Months Ended
	Sep. 30, 2021USD ($)
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	$ 47.8
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	148
Guarantor Obligations, Current Carrying Value	29
Guarantor Obligations, Current Carrying Value, Contingent Portion	2
AEP Texas Inc. [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	11.1
Appalachian Power Co [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	6.2
Indiana Michigan Power Co [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	4.1
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Rockport Plant, Unit 2 Acquisition Price	115.5
Ohio Power Co [Member]
Maximum Potential Loss [Abstract]
Max Potential Loss on Master Lease Agreements	7.6
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	5.2
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	74	[1]
Minimum Lease Payments, Sale Leaseback Transactions, within Two Years	147.6	[1]
Minimum Lease Payments, Sale Leaseback Transactions	221.6	[1]
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	37
Minimum Lease Payments, Sale Leaseback Transactions, within Two Years	73.8
Minimum Lease Payments, Sale Leaseback Transactions	110.8
Boat and Barge Leases [Member]
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Guarantor Obligations, Current Carrying Value	2
Maximum Potential Lease Payments, AEPRO Barge and Boat Leases	43
Guarantee Obligations Current Carrying Value Other Liabilities Current	1
Guarantee Obligations Current Carrying Value Other Liabilities Noncurrent	1
Letters of Credit [Member]
Maximum Future Payments for Letters of Credit [Abstract]
Maximum Future Payments for Letters of Credit Issued Under the Uncommitted Facility	179.5
Commitments, Guarantees and Contingencies (Textuals) [Abstract]
Letters of Credit Limit	1,200
Uncommitted Facility	375
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		1 Months Ended		3 Months Ended				9 Months Ended	10 Months Ended
		May 31, 2021USD ($)	Jun. 30, 2020USD ($)	Sep. 30, 2021USD ($)MW	Jun. 30, 2021USD ($)	Mar. 31, 2021USD ($)	Sep. 30, 2020USD ($)	Sep. 30, 2021USD ($)	Jul. 31, 2022USD ($)	Jul. 31, 2021USD ($)	Dec. 31, 2020USD ($)
Obligations Under Operating Leases				$ 586.8				$ 586.8			$ 638.4
Asset Retirement Obligation, Liabilities Settled	[1],[2],[3],[4]							27.6
Additional Paid in Capital				7,075.9				7,075.9			6,588.9
Property, Plant and Equipment				24,135.9				24,135.9			23,133.9
Noncontrolling Interests				$ 249.1				$ 249.1			223.6
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] | Conesville Generating Station [Member]
Payments for (Proceeds from) Removal Costs			$ 26				$ 98		$ 34	$ 38
Asset Retirement Obligation, Liabilities Settled							106
Generation And Marketing [Member] | Dry Lake Solar Project
Percentage of an Asset Acquired				75.00%				75.00%
Wind Generation MWs | MW				100
Noncash or Part Noncash Acquisition, Value of Assets Acquired				$ 114
Payments to Acquire Businesses, Gross		$ 11				$ 103
Property, Plant and Equipment				146				$ 146
Noncontrolling Interests				$ 35				35
Generation And Marketing [Member] | Dry Lake Solar Project | Noncontrolling Interest [Member]
Noncash or Part Noncash Acquisition, Other Assets Acquired								16
Generation And Marketing [Member] | Trent and Desert Sky Wind Farms [Member]
Payments to Acquire Businesses, Gross							57
Redeemable Noncontrolling Interest							63
Additional Paid in Capital							$ 6
Vertically Integrated Utilities [Member] | North Central Wind Energy Facilities
Wind Generation MWs | MW				1,485
Noncash or Part Noncash Acquisition, Value of Assets Acquired				$ 2,000
Vertically Integrated Utilities [Member] | North Central Wind Energy Facilities | Sundance [Member]
Wind Generation MWs | MW				199
Payments to Acquire Businesses, Gross					$ 270
Vertically Integrated Utilities [Member] | North Central Wind Energy Facilities | Maverick [Member]
Wind Generation MWs | MW				287
Payments to Acquire Businesses, Gross				$ 383
Vertically Integrated Utilities [Member] | North Central Wind Energy Facilities | Traverse [Member]
Wind Generation MWs | MW				999
Public Service Co Of Oklahoma [Member]
Obligations Under Operating Leases				$ 63.7				63.7			36.2
Additional Paid in Capital				1,039				1,039			414
Property, Plant and Equipment				$ 1,795.2				$ 1,795.2			1,480.7
Public Service Co Of Oklahoma [Member] | Vertically Integrated Utilities [Member] | North Central Wind Energy Facilities
Percentage of an Asset Acquired				45.50%				45.50%
Property, Plant and Equipment				$ 314				$ 314
Public Service Co Of Oklahoma [Member] | Vertically Integrated Utilities [Member] | North Central Wind Energy Facilities | Sundance [Member]
Obligations Under Operating Leases				13				13
Public Service Co Of Oklahoma [Member] | Vertically Integrated Utilities [Member] | North Central Wind Energy Facilities | Maverick [Member]
Obligations Under Operating Leases				18				18
Southwestern Electric Power Co [Member]
Obligations Under Operating Leases				79.2				79.2			44.1
Additional Paid in Capital				1,092.2				1,092.2			812.2
Property, Plant and Equipment				5,065.5				5,065.5			4,681.4
Noncontrolling Interests				$ 0.4				$ 0.4			$ 1.6
Southwestern Electric Power Co [Member] | Vertically Integrated Utilities [Member] | North Central Wind Energy Facilities
Percentage of an Asset Acquired				54.50%				54.50%
Property, Plant and Equipment				$ 376				$ 376
Southwestern Electric Power Co [Member] | Vertically Integrated Utilities [Member] | North Central Wind Energy Facilities | Sundance [Member]
Obligations Under Operating Leases				15				15
Southwestern Electric Power Co [Member] | Vertically Integrated Utilities [Member] | North Central Wind Energy Facilities | Maverick [Member]
Obligations Under Operating Leases				$ 22				$ 22
[1]	Includes ARO related to Sabine and DHLC.
[2]	Includes ARO related to asbestos removal.
[3]	Includes ARO related to ash disposal facilities.
[4]	Includes ARO related to nuclear decommissioning costs for the Cook Plant of $1.85 billion and $1.80 billion as of September 30, 2021 and December 31, 2020, respectively.

Benefit Plans (Details)

Benefit Plans (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Components of Net Periodic Benefit Cost
Qualified Pension Contribution			$ 0	$ 110.3
AEP Texas Inc. [Member]
Components of Net Periodic Benefit Cost
Qualified Pension Contribution			0	11.3
Appalachian Power Co [Member]
Components of Net Periodic Benefit Cost
Qualified Pension Contribution			0	7
Indiana Michigan Power Co [Member]
Components of Net Periodic Benefit Cost
Qualified Pension Contribution			0	6.4
Ohio Power Co [Member]
Components of Net Periodic Benefit Cost
Qualified Pension Contribution				0.1
Southwestern Electric Power Co [Member]
Components of Net Periodic Benefit Cost
Qualified Pension Contribution			0	8.9
Pension Plans [Member]
Components of Net Periodic Benefit Cost
Service Cost	$ 32.3	$ 28	96.9	84
Interest Cost	34.3	42	102.9	125.9
Expected Return on Plan Assets	(57.4)	(66.3)	(172.3)	(198.7)
Amortization of Prior Service Cost (Credit)	0	0	0	0
Amortization of Net Actuarial Loss	25.3	23.5	76.1	70.3
Net Periodic Benefit Cost (Credit)	34.5	27.2	103.6	81.5
Pension Plans [Member] | AEP Texas Inc. [Member]
Components of Net Periodic Benefit Cost
Service Cost	3	2.6	8.9	7.6
Interest Cost	2.8	3.5	8.4	10.5
Expected Return on Plan Assets	(4.9)	(5.7)	(14.6)	(17.1)
Amortization of Prior Service Cost (Credit)	0	0	0	0
Amortization of Net Actuarial Loss	2.1	1.9	6.2	5.8
Net Periodic Benefit Cost (Credit)	3	2.3	8.9	6.8
Pension Plans [Member] | Appalachian Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	3	2.7	8.9	7.9
Interest Cost	4.1	5	12.3	15.2
Expected Return on Plan Assets	(7.3)	(8.4)	(21.8)	(25.2)
Amortization of Prior Service Cost (Credit)	0	0	0	0
Amortization of Net Actuarial Loss	3	2.8	9	8.4
Net Periodic Benefit Cost (Credit)	2.8	2.1	8.4	6.3
Pension Plans [Member] | Indiana Michigan Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	4.4	3.9	13.1	11.6
Interest Cost	4	4.9	12.1	14.7
Expected Return on Plan Assets	(7.2)	(8.3)	(21.6)	(24.9)
Amortization of Prior Service Cost (Credit)	0	0	0	0
Amortization of Net Actuarial Loss	2.9	2.7	8.8	8.1
Net Periodic Benefit Cost (Credit)	4.1	3.2	12.4	9.5
Pension Plans [Member] | Ohio Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	2.9	2.4	8.6	7.2
Interest Cost	3.1	3.9	9.3	11.6
Expected Return on Plan Assets	(5.7)	(6.6)	(16.8)	(19.7)
Amortization of Prior Service Cost (Credit)	0	0	0	0
Amortization of Net Actuarial Loss	2.3	2.1	6.8	6.4
Net Periodic Benefit Cost (Credit)	2.6	1.8	7.9	5.5
Pension Plans [Member] | Public Service Co Of Oklahoma [Member]
Components of Net Periodic Benefit Cost
Service Cost	2	1.9	6	5.5
Interest Cost	1.7	2.1	5	6.4
Expected Return on Plan Assets	(3)	(3.6)	(9.2)	(10.9)
Amortization of Prior Service Cost (Credit)	0	0	0	0
Amortization of Net Actuarial Loss	1.2	1.1	3.7	3.5
Net Periodic Benefit Cost (Credit)	1.9	1.5	5.5	4.5
Pension Plans [Member] | Southwestern Electric Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	2.7	2.6	8.4	7.5
Interest Cost	2.2	2.5	6.4	7.6
Expected Return on Plan Assets	(3.3)	(3.9)	(10.1)	(11.7)
Amortization of Prior Service Cost (Credit)	0	0	0	0
Amortization of Net Actuarial Loss	1.5	1.4	4.6	4.2
Net Periodic Benefit Cost (Credit)	3.1	2.6	9.3	7.6
Other Postretirement Benefit Plans [Member]
Components of Net Periodic Benefit Cost
Service Cost	2.4	2.5	7.2	7.5
Interest Cost	7.7	10	22.9	29.9
Expected Return on Plan Assets	(22.8)	(23.9)	(68.4)	(71.8)
Amortization of Prior Service Cost (Credit)	(17.8)	(17.4)	(53.2)	(52.3)
Amortization of Net Actuarial Loss	0	1.4	0	4.4
Net Periodic Benefit Cost (Credit)	(30.5)	(27.4)	(91.5)	(82.3)
Other Postretirement Benefit Plans [Member] | AEP Texas Inc. [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.2	0.2	0.5	0.6
Interest Cost	0.6	0.8	1.8	2.4
Expected Return on Plan Assets	(1.9)	(2)	(5.6)	(6)
Amortization of Prior Service Cost (Credit)	(1.5)	(1.4)	(4.5)	(4.4)
Amortization of Net Actuarial Loss	0	0.1	0	0.4
Net Periodic Benefit Cost (Credit)	(2.6)	(2.3)	(7.8)	(7)
Other Postretirement Benefit Plans [Member] | Appalachian Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.3	0.3	0.8	0.8
Interest Cost	1.3	1.6	3.7	4.9
Expected Return on Plan Assets	(3.4)	(3.6)	(10.1)	(10.9)
Amortization of Prior Service Cost (Credit)	(2.6)	(2.5)	(7.8)	(7.6)
Amortization of Net Actuarial Loss	0	0.2	0	0.7
Net Periodic Benefit Cost (Credit)	(4.4)	(4)	(13.4)	(12.1)
Other Postretirement Benefit Plans [Member] | Indiana Michigan Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.4	0.4	1	1.1
Interest Cost	0.8	1.2	2.6	3.5
Expected Return on Plan Assets	(2.7)	(3)	(8.3)	(8.8)
Amortization of Prior Service Cost (Credit)	(2.5)	(2.3)	(7.3)	(7.1)
Amortization of Net Actuarial Loss	0	0.1	0	0.5
Net Periodic Benefit Cost (Credit)	(4)	(3.6)	(12)	(10.8)
Other Postretirement Benefit Plans [Member] | Ohio Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.2	0.2	0.6	0.7
Interest Cost	0.7	1	2.3	3.1
Expected Return on Plan Assets	(2.4)	(2.6)	(7.3)	(7.9)
Amortization of Prior Service Cost (Credit)	(1.7)	(1.8)	(5.3)	(5.3)
Amortization of Net Actuarial Loss	0	0.2	0	0.5
Net Periodic Benefit Cost (Credit)	(3.2)	(3)	(9.7)	(8.9)
Other Postretirement Benefit Plans [Member] | Public Service Co Of Oklahoma [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.1	0.1	0.4	0.4
Interest Cost	0.4	0.6	1.2	1.6
Expected Return on Plan Assets	(1.3)	(1.3)	(3.8)	(3.9)
Amortization of Prior Service Cost (Credit)	(1.1)	(1)	(3.3)	(3.2)
Amortization of Net Actuarial Loss	0	0	0	0.2
Net Periodic Benefit Cost (Credit)	(1.9)	(1.6)	(5.5)	(4.9)
Other Postretirement Benefit Plans [Member] | Southwestern Electric Power Co [Member]
Components of Net Periodic Benefit Cost
Service Cost	0.3	0.2	0.6	0.6
Interest Cost	0.4	0.6	1.4	1.9
Expected Return on Plan Assets	(1.5)	(1.5)	(4.5)	(4.7)
Amortization of Prior Service Cost (Credit)	(1.4)	(1.3)	(4)	(3.9)
Amortization of Net Actuarial Loss	0	0.1	0	0.3
Net Periodic Benefit Cost (Credit)	$ (2.2)	$ (1.9)	$ (6.5)	$ (5.8)

Business Segments (Details)

Business Segments (Details) - USD ($) $ in Millions		3 Months Ended								9 Months Ended
		Sep. 30, 2021		Jun. 30, 2021	Mar. 31, 2021	Sep. 30, 2020		Jun. 30, 2020	Mar. 31, 2020	Sep. 30, 2021		Sep. 30, 2020		Dec. 31, 2020
Reportable Segment Information
Revenue from Contracts with Customers		$ 4,623				$ 4,066.4				$ 12,730.6		$ 11,307.9
Revenue from Related Parties		0				0				0		0
Revenues		4,623				4,066.4				12,730.6		11,307.9
Net Income (Loss)		796.9		$ 573.8	$ 578.8	748.2		$ 514.5	$ 499.3	1,949.5		1,762
Balance Sheet Information
Total Property, Plant and Equipment		88,568.2								88,568.2				$ 84,313
Accumulated Depreciation and Amortization		21,877								21,877				20,411.4
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		66,691.2								66,691.2				63,901.6
Total Assets		86,337.1								86,337.1				80,757.2
Long-term Debt Due Within One Year		2,521.8								2,521.8				2,086.1
Long-term Debt - Affiliated		0								0				0
Long-term Debt		32,056.5								32,056.5				28,986.4
Total Long-term Debt Outstanding		34,578.3								34,578.3				31,072.5
Income Tax (Expense) Benefit		69.8				(1.2)				185.5		57.9
Interest Expense		303.7				291.3				895.5		877.4
Reclassification out of Accumulated Other Comprehensive Income [Member]
Balance Sheet Information
Income Tax (Expense) Benefit		(12.7)				6.8				(51.1)		27.8
Interest Expense	[1]	1.5				1.3				4.8		3.6
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		0.3				0.2				1		0.8
Interest Expense	[1]	1.5				1.3				4.8		3.6
Vertically Integrated Utilities [Member]
Reportable Segment Information
Revenue from Contracts with Customers		2,716.8				2,400.1				7,445.9		6,655.4
Transmission and Distribution Utilities Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		1,195				1,124.1				3,366.9		3,208.7
Generation and Marketing Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		617.4				464.8				1,641.6		1,223.4
Generation and Marketing Revenues [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reportable Segment Information
Revenue from Contracts with Customers	[1]					(0.1)				0.7		(0.3)
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		0
Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		93.8				77.4				276.2		220.4
Revenues		154.8	[2]			(5.5)	[3]			188.7	[4]	13.3	[5]
AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Related Parties		297.6				241.2				864.6		652.6
Revenues		377				304.1				1,104.2		837.8
Net Income (Loss)		145.4		$ 148.6	$ 151.7	117.6		$ 73.7	$ 117.8	445.7		309.1
Balance Sheet Information
Total Property, Plant and Equipment		12,359.3								12,359.3				11,345.6
Accumulated Depreciation and Amortization		730.4								730.4				572.8
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		11,628.9								11,628.9				10,772.8
Notes Receivable, Related Parties		0								0				0
Total Assets		11,931.1								11,931.1				11,246
Long-term Debt Due Within One Year		50								50				50
Long-term Debt		4,343.4								4,343.4				3,898.5
Total Long-term Debt Outstanding		4,393.4								4,393.4				3,948.5
Income Tax (Expense) Benefit		36.7				31.7				115.4		82.8
Interest Income		0.2				0.2				0.4		2.3
Interest Expense		36.1				32.7				104.5		95.1
AEP Transmission Co [Member] | Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0.2				0				0.3		0.6
Revenues		0	[6]			0	[7]			0	[8]	0	[9]
AEP Transmission Co [Member] | Transmission [Member]
Reportable Segment Information
Revenue from Contracts with Customers		79.2				62.9				239.3		184.6
Reconciling Adjustments [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0				0				0		0
Revenue from Related Parties		(376)				(374.2)				(1,112.2)		(1,007.6)
Revenues		(376)				(374.2)				(1,112.2)		(1,007.6)
Net Income (Loss)		0				0				0		0
Balance Sheet Information
Total Property, Plant and Equipment		0								0				0
Accumulated Depreciation and Amortization		0								0				0
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		0								0				0
Total Assets	[10]	(4,588.1)								(4,588.1)				(3,961.7)
Long-term Debt Due Within One Year		0								0				0
Long-term Debt - Affiliated		(65)								(65)				(65)
Long-term Debt		0								0				0
Total Long-term Debt Outstanding		(65)								(65)				(65)
Reconciling Adjustments [Member] | Other Revenues [Member]
Reportable Segment Information
Revenues		(3)	[2]			(35)	[3]			(8.6)	[4]	(71.3)	[5]
Reconciling Adjustments [Member] | AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0				0				0		0
Revenue from Related Parties		0				0				0		0
Revenues		0				0				0		0
Net Income (Loss)		0				0				0		0
Balance Sheet Information
Total Property, Plant and Equipment		0								0				0
Accumulated Depreciation and Amortization		0								0				0
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		0								0				0
Notes Receivable, Related Parties	[11]	(4,343.5)								(4,343.5)				(3,948.5)
Total Assets	[12]	(4,498.9)								(4,498.9)				(4,023.1)
Total Long-term Debt Outstanding	[11]	(4,440)								(4,440)				(3,990)
Income Tax (Expense) Benefit		0				0				0		0
Interest Income	[13]	(40.2)				(38.2)				(116.7)		(109.9)
Interest Expense	[13]	(40.2)				(38.2)				(116.6)		(109.9)
Reconciling Adjustments [Member] | AEP Transmission Co [Member] | Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0								0		0
Vertically Integrated Utilities [Member]
Reportable Segment Information
Revenue from Related Parties		42.5				34.7				111.3		98.1
Revenues		2,759.3				2,434.8				7,557.2		6,753.5
Net Income (Loss)		438.7				394.2				938.9		896.8
Balance Sheet Information
Total Property, Plant and Equipment		50,990.6								50,990.6				49,023.3
Accumulated Depreciation and Amortization		16,647.1								16,647.1				15,586.2
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		34,343.5								34,343.5				33,437.1
Total Assets		45,775.5								45,775.5				42,752.7
Long-term Debt Due Within One Year		1,243								1,243				1,034.6
Long-term Debt - Affiliated		65								65				65
Long-term Debt		13,616								13,616				12,375.6
Total Long-term Debt Outstanding		14,924								14,924				13,475.2
Vertically Integrated Utilities [Member] | Vertically Integrated Utilities [Member]
Reportable Segment Information
Revenue from Contracts with Customers		2,716.8				2,400.1				7,445.9		6,655.4
Vertically Integrated Utilities [Member] | Other Revenues [Member]
Reportable Segment Information
Revenues		(0.9)	[2]			0	[3]			(0.6)	[4]	0	[5]
Transmission And Distribution Utilities [Member]
Reportable Segment Information
Revenue from Related Parties		5.3				41.2				24.9		98
Revenues		1,200.3				1,165.3				3,391.8		3,306.7
Net Income (Loss)		155.9				147.4				424		403.1
Balance Sheet Information
Total Property, Plant and Equipment		22,171.7								22,171.7				21,145
Accumulated Depreciation and Amortization		4,059.9								4,059.9				3,879.3
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		18,111.8								18,111.8				17,265.7
Total Assets		21,053.1								21,053.1				19,765.9
Long-term Debt Due Within One Year		815.2								815.2				588.8
Long-term Debt - Affiliated		0								0				0
Long-term Debt		7,869								7,869				6,661.9
Total Long-term Debt Outstanding		8,684.2								8,684.2				7,250.7
Transmission And Distribution Utilities [Member] | Transmission and Distribution Utilities Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		1,195				1,124.1				3,366.9		3,208.7
Transmission And Distribution Utilities [Member] | Other Revenues [Member]
Reportable Segment Information
Revenues		4.9	[2]			36.2	[3]			14.2	[4]	78.1	[5]
AEP Transmission Holdco [Member]
Reportable Segment Information
Revenue from Related Parties		301.3				244.5				882.2		662.1
Revenues		391.6				317.9				1,146.8		877.8
Net Income (Loss)		167.9				139.3				510.7		373.1
Balance Sheet Information
Total Property, Plant and Equipment		12,865.6								12,865.6				11,827.2
Accumulated Depreciation and Amortization		758.1								758.1				595.7
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		12,107.5								12,107.5				11,231.5
Total Assets		13,287.6								13,287.6				12,627.3
Long-term Debt Due Within One Year		52.4								52.4				52.3
Long-term Debt - Affiliated		0								0				0
Long-term Debt		4,544.2								4,544.2				4,075.7
Total Long-term Debt Outstanding		4,596.6								4,596.6				4,128
AEP Transmission Holdco [Member] | Transmission [Member]
Reportable Segment Information
Revenue from Contracts with Customers		90.3				73.4				264.6		215.7
Generation And Marketing [Member]
Reportable Segment Information
Revenue from Related Parties		3.7				25.2				50.3		82.1
Revenues		621.1				490				1,691.9		1,305.5
Net Income (Loss)		99.5				114.6				184.2		203.6
Balance Sheet Information
Total Property, Plant and Equipment		2,125.8								2,125.8				1,910.2
Accumulated Depreciation and Amortization		222.8								222.8				166.1
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		1,903								1,903				1,744.1
Total Assets		4,387.6								4,387.6				3,585.9
Long-term Debt Due Within One Year		0								0				0
Long-term Debt - Affiliated		0								0				0
Long-term Debt		0								0				0
Total Long-term Debt Outstanding		0								0				0
Generation And Marketing [Member] | Generation and Marketing Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		617.4				464.8				1,641.6		1,223.4
Generation And Marketing [Member] | Other Revenues [Member]
Reportable Segment Information
Revenues		150.7	[2],[14]			(4.5)	[3],[15]			175.3	[4],[16]	13.2	[5],[17]
All Other [Member]
Reportable Segment Information
Revenue from Related Parties	[18]	23.2				28.6				43.5		67.3
Revenues	[18]	26.7				32.6				55.1		72
Net Income (Loss)	[18]	(65.1)				(47.3)				(108.3)		(114.6)
Balance Sheet Information
Total Property, Plant and Equipment	[18]	414.5								414.5				407.3
Accumulated Depreciation and Amortization	[18]	189.1								189.1				184.1
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET	[18]	225.4								225.4				223.2
Total Assets	[18],[19]	6,421.4								6,421.4				5,987.1
Long-term Debt Due Within One Year	[18],[20]	411.2								411.2				410.4
Long-term Debt - Affiliated	[18]	0								0				0
Long-term Debt	[18],[20]	6,027.3								6,027.3				5,873.2
Total Long-term Debt Outstanding	[18],[20]	6,438.5								6,438.5				6,283.6
All Other [Member] | Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers	[18]	3.5				4				11.6		4.7
Revenues		3.1	[2]			(2.2)	[3]			8.4	[4]	(6.7)	[5]
State Transcos [Member] | AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Related Parties		297.6				241.2				864.6		652.6
Revenues		377				304.1				1,104.2		837.8
Net Income (Loss)		145.3				117.5				445.5		308
Balance Sheet Information
Total Property, Plant and Equipment		12,359.3								12,359.3				11,345.6
Accumulated Depreciation and Amortization		730.4								730.4				572.8
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		11,628.9								11,628.9				10,772.8
Notes Receivable, Related Parties		0								0				0
Total Assets		11,984.7								11,984.7				11,185.1
Total Long-term Debt Outstanding		4,440								4,440				3,990
Income Tax (Expense) Benefit		36.7				31.7				115.4		82.7
Interest Income		0.1				0				0.1		0.9
Interest Expense		36.1				32.7				104.5		95.1
State Transcos [Member] | AEP Transmission Co [Member] | Other Revenues [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0.2								0.3		0.6
State Transcos [Member] | AEP Transmission Co [Member] | Transmission [Member]
Reportable Segment Information
Revenue from Contracts with Customers		79.2				62.9				239.3		184.6
AEPTCo Parent [Member] | AEP Transmission Co [Member]
Reportable Segment Information
Revenue from Contracts with Customers		0				0				0		0
Revenue from Related Parties		0				0				0		0
Revenues		0				0				0		0
Net Income (Loss)	[21]	0.1				0.1				0.2		1.1
Balance Sheet Information
Total Property, Plant and Equipment		0								0				0
Accumulated Depreciation and Amortization		0								0				0
TOTAL PROPERTY, PLANT AND EQUIPMENT - NET		0								0				0
Notes Receivable, Related Parties		4,343.5								4,343.5				3,948.5
Total Assets	[22]	4,445.3								4,445.3				4,084
Total Long-term Debt Outstanding		4,393.4								4,393.4				$ 3,948.5
Income Tax (Expense) Benefit		0				0				0		0.1
Interest Income		40.3				38.4				117		111.3
Interest Expense		$ 40.2				$ 38.2				$ 116.6		$ 109.9
[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]	Amounts include affiliated and nonaffiliated revenues.
[7]	Amounts include affiliated and nonaffiliated revenues.
[8]	Amounts include affiliated and nonaffiliated revenues.
[9]	Amounts include affiliated and nonaffiliated revenues.
[10]	Reconciling Adjustments for Total Assets primarily include elimination of intercompany advances to affiliates and intercompany accounts receivable.
[11]	Elimination of intercompany debt.
[12]	Primarily relates to the elimination of Notes Receivable from the State Transcos.
[13]	Elimination of intercompany interest income/interest expense on affiliated debt arrangement.
[14]	Generation & Marketing includes economic hedge activity.
[15]	Generation & Marketing includes economic hedge activity.
[16]	Generation & Marketing includes economic hedge activity
[17]	Generation & Marketing includes economic hedge activity.
[18]	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.
[19]	Includes elimination of AEP Parent’s investments in wholly-owned subsidiary companies.
[20]	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.
[21]	Includes the elimination of AEPTCo Parent’s equity earnings in the State Transcos.
[22]	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			9 Months Ended			12 Months Ended
		Sep. 30, 2021USD ($)MWhMMBTUgal		Sep. 30, 2020USD ($)	Sep. 30, 2021USD ($)MWhMMBTUgal		Sep. 30, 2020USD ($)	Dec. 31, 2020USD ($)MWhMMBTUgal
Cash Collateral Netting
Cash Collateral Received Netted Against Risk Management Assets		$ 309,700,000			$ 309,700,000			$ 3,400,000
Cash Collateral Paid Netted Against Risk Management Liabilities		38,300,000			38,300,000			6,800,000
Fair Value of Derivative Instruments
Current Risk Management Assets		369,200,000			369,200,000			94,700,000
Long-term Risk Management Assets		278,300,000			278,300,000			242,200,000
Total Assets		647,500,000			647,500,000			336,900,000
Current Risk Management Liabilities		106,500,000			106,500,000			78,800,000
Long-term Risk Management Liabilities		199,600,000			199,600,000			232,800,000
Total Liabilities		306,100,000			306,100,000			311,600,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		169,400,000		$ 36,000,000	265,600,000		$ 81,900,000
Carrying Amount of Hedged Asset (Liability)	[1],[2]	(965,600,000)			(965,600,000)			(995,900,000)
Cumulative Fair Value Hedging Adjustment in the Carrying Amount of the Hedged Asset (Liability)	[1],[2]	(22,100,000)			(22,100,000)			(51,700,000)
Gain (Loss) on Hedging Instruments
Gain (Loss) on Fair Value Hedging Instruments	[3]	(100,000)		0	(23,800,000)		42,600,000
Gain (Loss) on Fair Value Portion of Long Term Debt	[3]	100,000		0	23,800,000		(42,600,000)
Collateral Triggering Events [Abstract]
Fair Value Of Derivative Liabilities Subject To Cross Default Provisions		128,200,000			128,200,000			188,400,000
Amount of Cash Collateral Posted		0			0			0
Additional Settlement Liability if Cross Default Provision is Triggered		95,800,000			95,800,000			169,200,000
Derivatives and Hedging (Textuals) [Abstract]
Hedged Liability, Discontinued Fair Value Hedge, Cumulative Increase (Decrease)		(47,000,000)			(47,000,000)			(53,000,000)
Credit Downgrade Trigger Exposure		25,000,000			25,000,000
Investment in Private Investee
Derivatives and Hedging (Textuals) [Abstract]
Cost Method Investments								8,000,000
Equity Method Investments, Fair Value Disclosure		30,000,000			30,000,000
Unrealized Gain (Loss) on Investments		(16,000,000)			22,000,000
AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		400,000		(100,000)	1,700,000		(1,300,000)
Appalachian Power Co [Member]
Cash Collateral Netting
Cash Collateral Received Netted Against Risk Management Assets		600,000			600,000			400,000
Cash Collateral Paid Netted Against Risk Management Liabilities		10,700,000			10,700,000			0
Fair Value of Derivative Instruments
Current Risk Management Assets		47,000,000			47,000,000			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		10,800,000		4,500,000	27,000,000		17,000,000
Collateral Triggering Events [Abstract]
Fair Value Of Derivative Liabilities Subject To Cross Default Provisions		1,000,000			1,000,000			4,300,000
Amount of Cash Collateral Posted		0			0			0
Additional Settlement Liability if Cross Default Provision is Triggered		0			0			3,500,000
Indiana Michigan Power Co [Member]
Cash Collateral Netting
Cash Collateral Received Netted Against Risk Management Assets		300,000			300,000			1,700,000
Cash Collateral Paid Netted Against Risk Management Liabilities		17,400,000			17,400,000			0
Fair Value of Derivative Instruments
Current Risk Management Assets		5,500,000			5,500,000			3,600,000
Current Risk Management Liabilities		2,500,000			2,500,000			100,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(15,000,000)		2,700,000	(20,500,000)		8,400,000
Collateral Triggering Events [Abstract]
Fair Value Of Derivative Liabilities Subject To Cross Default Provisions		600,000			600,000			500,000
Amount of Cash Collateral Posted		0			0			0
Additional Settlement Liability if Cross Default Provision is Triggered		0			0			100,000
Ohio Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Liabilities		3,500,000			3,500,000			8,700,000
Long-term Risk Management Liabilities		86,900,000			86,900,000			101,600,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		16,000,000		5,800,000	26,900,000		(2,200,000)
Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		18,500,000			18,500,000			10,300,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		14,200,000		2,600,000	40,600,000		22,900,000
Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets		17,500,000			17,500,000			3,200,000
Long-term Risk Management Assets		2,100,000			2,100,000			0
Current Risk Management Liabilities		0			0			700,000
Long-term Risk Management Liabilities		0			0			1,000,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		13,100,000		4,700,000	40,500,000		16,600,000
Collateral Triggering Events [Abstract]
Fair Value Of Derivative Liabilities Subject To Cross Default Provisions		0			0			1,800,000
Amount of Cash Collateral Posted		0			0			0
Additional Settlement Liability if Cross Default Provision is Triggered		0			0			1,800,000
Risk Management Contracts [Member]
Fair Value of Derivative Instruments
Total Assets	[4]	275,500,000	[5]		275,500,000	[5]		322,100,000	[6]
Total Liabilities	[4]	273,200,000	[5]		273,200,000	[5]		218,900,000	[6]
Risk Management Contracts [Member] | AEP Texas Inc. [Member]
Fair Value of Derivative Instruments
Total Assets	[4]	0			0			0
Risk Management Contracts [Member] | Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[4],[7]	47,000,000			47,000,000			20,100,000
Total Liabilities	[4],[7]	1,300,000			1,300,000			1,300,000
Risk Management Contracts [Member] | Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[4],[7]	5,500,000			5,500,000			3,700,000
Total Liabilities	[4],[7]	2,500,000			2,500,000			200,000
Risk Management Contracts [Member] | Ohio Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[4],[7]	0			0			0
Total Liabilities	[4],[7]	90,400,000			90,400,000			110,300,000
Risk Management Contracts [Member] | Public Service Co Of Oklahoma [Member]
Fair Value of Derivative Instruments
Total Assets	[4],[7]	18,500,000			18,500,000			10,300,000
Total Liabilities	[4],[7]	0			0
Risk Management Contracts [Member] | Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Total Assets	[4],[7]	19,600,000			19,600,000			3,200,000
Total Liabilities	[4],[7]	0			0			1,700,000
Commodity [Member]
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		283,900,000			283,900,000			(60,600,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months					$ 56,500,000			(27,100,000)
Derivatives and Hedging (Textuals) [Abstract]
Maximum Term for Exposure to Variability of Future Cash Flows					114 months
Cross Default Provisions Maximum Third Party Obligation Amount		50,000,000			$ 50,000,000			50,000,000
Commodity [Member] | Risk Management Contracts [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]	1,005,500,000			1,005,500,000			239,100,000
Long-term Risk Management Assets	[8]	337,300,000			337,300,000			275,900,000
Total Assets	[8]	1,342,800,000			1,342,800,000			515,000,000
Current Risk Management Liabilities	[8]	834,500,000			834,500,000			193,000,000
Long-term Risk Management Liabilities	[8]	234,600,000			234,600,000			222,200,000
Total Liabilities	[8]	1,069,100,000			1,069,100,000			415,200,000
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	273,700,000			273,700,000			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			800,000			400,000
Long-term Risk Management Assets	[8]	100,000			100,000			0
Total Assets	[8]	900,000			900,000			400,000
Current Risk Management Liabilities	[8]	0			0			0
Long-term Risk Management Liabilities	[8]	0			0			0
Total Liabilities	[8]	0			0			0
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	900,000			900,000			400,000
Commodity [Member] | Risk Management Contracts [Member] | Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]	95,700,000			95,700,000			38,800,000
Long-term Risk Management Assets	[8]	200,000			200,000			700,000
Total Assets	[8]	95,900,000			95,900,000			39,500,000
Current Risk Management Liabilities	[8]	60,200,000			60,200,000			19,700,000
Long-term Risk Management Liabilities	[8]	200,000			200,000			600,000
Total Liabilities	[8]	60,400,000			60,400,000			20,300,000
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	35,500,000			35,500,000			19,200,000
Commodity [Member] | Risk Management Contracts [Member] | Indiana Michigan Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]	37,800,000			37,800,000			17,200,000
Long-term Risk Management Assets	[8]	100,000			100,000			500,000
Total Assets	[8]	37,900,000			37,900,000			17,700,000
Current Risk Management Liabilities	[8]	51,900,000			51,900,000			12,100,000
Long-term Risk Management Liabilities	[8]	100,000			100,000			400,000
Total Liabilities	[8]	52,000,000			52,000,000			12,500,000
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	(14,100,000)			(14,100,000)			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			600,000			300,000
Long-term Risk Management Assets	[8]	100,000			100,000			0
Total Assets	[8]	700,000			700,000			300,000
Current Risk Management Liabilities	[8]	3,500,000			3,500,000			8,700,000
Long-term Risk Management Liabilities	[8]	86,900,000			86,900,000			101,600,000
Total Liabilities	[8]	90,400,000			90,400,000			110,300,000
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	(89,700,000)			(89,700,000)			(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]	19,000,000			19,000,000			10,500,000
Long-term Risk Management Assets	[8]	0			0			0
Total Assets	[8]	19,000,000			19,000,000			10,500,000
Current Risk Management Liabilities	[8]	200,000			200,000			0
Long-term Risk Management Liabilities	[8]	0			0			0
Total Liabilities	[8]	200,000			200,000			0
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	18,800,000			18,800,000			10,500,000
Commodity [Member] | Risk Management Contracts [Member] | Southwestern Electric Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]	18,100,000			18,100,000			3,400,000
Long-term Risk Management Assets	[8]	2,100,000			2,100,000			0
Total Assets	[8]	20,200,000			20,200,000			3,400,000
Current Risk Management Liabilities	[8]	200,000			200,000			700,000
Long-term Risk Management Liabilities	[8]	0			0			1,000,000
Total Liabilities	[8]	200,000			200,000			1,700,000
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	20,000,000			20,000,000			1,700,000
Commodity [Member] | Hedging Contracts [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]	321,100,000			321,100,000			21,100,000
Long-term Risk Management Assets	[8]	85,800,000			85,800,000			18,000,000
Total Assets	[8]	406,900,000			406,900,000			39,100,000
Current Risk Management Liabilities	[8]	33,100,000			33,100,000			54,400,000
Long-term Risk Management Liabilities	[8]	14,300,000			14,300,000			60,100,000
Total Liabilities	[8]	47,400,000			47,400,000			114,500,000
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	359,500,000			359,500,000			(75,400,000)
Interest Rate [Member]
Commodity:
Derivative, Notional Amount		1,250,000,000			1,250,000,000			1,150,000,000
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		(26,100,000)			(26,100,000)			(47,500,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months					$ (2,600,000)			(5,700,000)
Derivatives and Hedging (Textuals) [Abstract]
Maximum Term for Exposure to Variability of Future Cash Flows					111 months
Deferred (Gain) Loss on Discontinuation of Fair Value Hedge		57,000,000			$ 57,000,000
Notional Amount of a Discontinued Hedge		500,000,000			500,000,000
Interest Rate [Member] | AEP Texas Inc. [Member]
Commodity:
Derivative, Notional Amount		0			0			0
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		(1,500,000)			(1,500,000)			(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			0			200,000,000
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		7,700,000			7,700,000			(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			0
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		(7,000,000)			(7,000,000)			(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			0
Interest Rate [Member] | Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Notional Amount		0			0			0
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		0			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			0
Impact of Cash Flow Hedges on the Condensed Balance Sheet
AOCI Gain (Loss) Net of Tax		800,000			800,000			(300,000)
Portion Expected to be Reclassified to Net Income During the Next Twelve Months					(400,000)			(1,500,000)
Interest Rate [Member] | Hedging Contracts [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[8]	8,300,000			8,300,000			5,000,000
Long-term Risk Management Assets	[8]	0			0			0
Total Assets	[8]	8,300,000			8,300,000			5,000,000
Current Risk Management Liabilities	[8]	0			0			3,400,000
Long-term Risk Management Liabilities	[8]	28,800,000			28,800,000			4,100,000
Total Liabilities	[8]	28,800,000			28,800,000			7,500,000
Total MTM Derivative Contract Net Assets (Liabilities)	[8]	(20,500,000)			(20,500,000)			(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		1,334,900,000			1,334,900,000			265,200,000
Long-term Risk Management Assets		423,100,000			423,100,000			293,900,000
Total Assets		1,758,000,000			1,758,000,000			559,100,000
Current Risk Management Liabilities		867,600,000			867,600,000			250,800,000
Long-term Risk Management Liabilities		277,700,000			277,700,000			286,400,000
Total Liabilities		1,145,300,000			1,145,300,000			537,200,000
Total MTM Derivative Contract Net Assets (Liabilities)		612,700,000			612,700,000			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]	(965,700,000)			(965,700,000)			(170,500,000)
Long-term Risk Management Assets	[9]	(144,800,000)			(144,800,000)			(51,700,000)
Total Assets	[9]	(1,110,500,000)			(1,110,500,000)			(222,200,000)
Current Risk Management Liabilities	[9]	(761,100,000)			(761,100,000)			(172,000,000)
Long-term Risk Management Liabilities	[9]	(78,100,000)			(78,100,000)			(53,600,000)
Total Liabilities	[9]	(839,200,000)			(839,200,000)			(225,600,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	(271,300,000)			(271,300,000)			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)			(800,000)			(400,000)
Long-term Risk Management Assets	[9]	(100,000)			(100,000)			0
Total Assets	[9]	(900,000)			(900,000)			(400,000)
Current Risk Management Liabilities	[9]	0			0			0
Long-term Risk Management Liabilities	[9]	0			0			0
Total Liabilities	[9]	0			0			0
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	(900,000)			(900,000)			(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]	(48,700,000)			(48,700,000)			(18,800,000)
Long-term Risk Management Assets	[9]	(200,000)			(200,000)			(600,000)
Total Assets	[9]	(48,900,000)			(48,900,000)			(19,400,000)
Current Risk Management Liabilities	[9]	(58,900,000)			(58,900,000)			(18,500,000)
Long-term Risk Management Liabilities	[9]	(200,000)			(200,000)			(500,000)
Total Liabilities	[9]	(59,100,000)			(59,100,000)			(19,000,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	10,200,000			10,200,000			(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]	(32,300,000)			(32,300,000)			(13,600,000)
Long-term Risk Management Assets	[9]	(100,000)			(100,000)			(400,000)
Total Assets	[9]	(32,400,000)			(32,400,000)			(14,000,000)
Current Risk Management Liabilities	[9]	(49,400,000)			(49,400,000)			(12,000,000)
Long-term Risk Management Liabilities	[9]	(100,000)			(100,000)			(300,000)
Total Liabilities	[9]	(49,500,000)			(49,500,000)			(12,300,000)
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	17,100,000			17,100,000			(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)			(600,000)			(300,000)
Long-term Risk Management Assets	[9]	(100,000)			(100,000)			0
Total Assets	[9]	(700,000)			(700,000)			(300,000)
Current Risk Management Liabilities	[9]	0			0			0
Long-term Risk Management Liabilities	[9]	0			0			0
Total Liabilities	[9]	0			0			0
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	(700,000)			(700,000)			(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]	(500,000)			(500,000)			(200,000)
Long-term Risk Management Assets	[9]	0			0			0
Total Assets	[9]	(500,000)			(500,000)			(200,000)
Current Risk Management Liabilities	[9]	(200,000)			(200,000)			0
Long-term Risk Management Liabilities	[9]	0			0			0
Total Liabilities	[9]	(200,000)			(200,000)			0
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	(300,000)			(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]	(600,000)			(600,000)			(200,000)
Long-term Risk Management Assets	[9]	0			0			0
Total Assets	[9]	(600,000)			(600,000)			(200,000)
Current Risk Management Liabilities	[9]	(200,000)			(200,000)			0
Long-term Risk Management Liabilities	[9]	0			0			0
Total Liabilities	[9]	(200,000)			(200,000)			0
Total MTM Derivative Contract Net Assets (Liabilities)	[9]	(400,000)			(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]	369,200,000			369,200,000			94,700,000
Long-term Risk Management Assets	[10]	278,300,000			278,300,000			242,200,000
Total Assets	[10]	647,500,000			647,500,000			336,900,000
Current Risk Management Liabilities	[10]	106,500,000			106,500,000			78,800,000
Long-term Risk Management Liabilities	[10]	199,600,000			199,600,000			232,800,000
Total Liabilities	[10]	306,100,000			306,100,000			311,600,000
Total MTM Derivative Contract Net Assets (Liabilities)	[10]	341,400,000			341,400,000			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			0
Long-term Risk Management Assets	[10]	0			0			0
Total Assets	[10]	0			0			0
Current Risk Management Liabilities	[10]	0			0			0
Long-term Risk Management Liabilities	[10]	0			0			0
Total Liabilities	[10]	0			0			0
Total MTM Derivative Contract Net Assets (Liabilities)	[10]	0			0			0
Net Amounts of Assets/Liabilities Presented in the Statement of Financial Position [Member] | Appalachian Power Co [Member]
Fair Value of Derivative Instruments
Current Risk Management Assets	[10]	47,000,000			47,000,000			22,400,000
Long-term Risk Management Assets	[10]	0			0			100,000
Total Assets	[10]	47,000,000			47,000,000			22,500,000
Current Risk Management Liabilities	[10]	1,300,000			1,300,000			4,600,000
Long-term Risk Management Liabilities	[10]	0			0			100,000
Total Liabilities	[10]	1,300,000			1,300,000			4,700,000
Total MTM Derivative Contract Net Assets (Liabilities)	[10]	45,700,000			45,700,000			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]	5,500,000			5,500,000			3,600,000
Long-term Risk Management Assets	[10]	0			0			100,000
Total Assets	[10]	5,500,000			5,500,000			3,700,000
Current Risk Management Liabilities	[10]	2,500,000			2,500,000			100,000
Long-term Risk Management Liabilities	[10]	0			0			100,000
Total Liabilities	[10]	2,500,000			2,500,000			200,000
Total MTM Derivative Contract Net Assets (Liabilities)	[10]	3,000,000			3,000,000			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			0
Long-term Risk Management Assets	[10]	0			0			0
Total Assets	[10]	0			0			0
Current Risk Management Liabilities	[10]	3,500,000			3,500,000			8,700,000
Long-term Risk Management Liabilities	[10]	86,900,000			86,900,000			101,600,000
Total Liabilities	[10]	90,400,000			90,400,000			110,300,000
Total MTM Derivative Contract Net Assets (Liabilities)	[10]	(90,400,000)			(90,400,000)			(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]	18,500,000			18,500,000			10,300,000
Long-term Risk Management Assets	[10]	0			0			0
Total Assets	[10]	18,500,000			18,500,000			10,300,000
Current Risk Management Liabilities	[10]	0			0			0
Long-term Risk Management Liabilities	[10]	0			0			0
Total Liabilities	[10]	0			0			0
Total MTM Derivative Contract Net Assets (Liabilities)	[10]	18,500,000			18,500,000			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]	17,500,000			17,500,000			3,200,000
Long-term Risk Management Assets	[10]	2,100,000			2,100,000			0
Total Assets	[10]	19,600,000			19,600,000			3,200,000
Current Risk Management Liabilities	[10]	0			0			700,000
Long-term Risk Management Liabilities	[10]	0			0			1,000,000
Total Liabilities	[10]	0			0			1,700,000
Total MTM Derivative Contract Net Assets (Liabilities)	[10]	$ 19,600,000			$ 19,600,000			$ 1,500,000
Power [Member]
Commodity:
Derivative, Energy Notional Amount | MWh		341.9			341.9			331.3
Power [Member] | AEP Texas Inc. [Member]
Commodity:
Derivative, Energy Notional Amount | MWh		0			0			0
Power [Member] | Appalachian Power Co [Member]
Commodity:
Derivative, Energy Notional Amount | MWh		55.4			55.4			46.9
Power [Member] | Indiana Michigan Power Co [Member]
Commodity:
Derivative, Energy Notional Amount | MWh		23.1			23.1			19.7
Power [Member] | Ohio Power Co [Member]
Commodity:
Derivative, Energy Notional Amount | MWh		2.8			2.8			3
Power [Member] | Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Energy Notional Amount | MWh		18.7			18.7			11.9
Power [Member] | Southwestern Electric Power Co [Member]
Commodity:
Derivative, Energy Notional Amount | MWh		5.4			5.4			4
Natural Gas [Member]
Commodity:
Derivative, Energy Notional Amount | MMBTU		28.1			28.1			26.9
Natural Gas [Member] | AEP Texas Inc. [Member]
Commodity:
Derivative, Energy Notional Amount | MMBTU		0			0			0
Natural Gas [Member] | Appalachian Power Co [Member]
Commodity:
Derivative, Energy Notional Amount | MMBTU		0			0			0
Natural Gas [Member] | Indiana Michigan Power Co [Member]
Commodity:
Derivative, Energy Notional Amount | MMBTU		0			0			0
Natural Gas [Member] | Ohio Power Co [Member]
Commodity:
Derivative, Energy Notional Amount | MMBTU		0			0			0
Natural Gas [Member] | Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Energy Notional Amount | MMBTU		0			0			0
Natural Gas [Member] | Southwestern Electric Power Co [Member]
Commodity:
Derivative, Energy Notional Amount | MMBTU		5.2			5.2			7.9
Heating Oil and Gasoline [Member]
Commodity:
Derivative, Volume Notional Amount | gal		7.8			7.8			6.9
Heating Oil and Gasoline [Member] | AEP Texas Inc. [Member]
Commodity:
Derivative, Volume Notional Amount | gal		2			2			1.8
Heating Oil and Gasoline [Member] | Appalachian Power Co [Member]
Commodity:
Derivative, Volume Notional Amount | gal		1.2			1.2			1.1
Heating Oil and Gasoline [Member] | Indiana Michigan Power Co [Member]
Commodity:
Derivative, Volume Notional Amount | gal		0.7			0.7			0.6
Heating Oil and Gasoline [Member] | Ohio Power Co [Member]
Commodity:
Derivative, Volume Notional Amount | gal		1.5			1.5			1.4
Heating Oil and Gasoline [Member] | Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Volume Notional Amount | gal		0.9			0.9			0.7
Heating Oil and Gasoline [Member] | Southwestern Electric Power Co [Member]
Commodity:
Derivative, Volume Notional Amount | gal		1.1			1.1			0.9
Interest Rate Contract [Member]
Commodity:
Derivative, Notional Amount		$ 116,500,000			$ 116,500,000			$ 129,800,000
Interest Rate Contract [Member] | AEP Texas Inc. [Member]
Commodity:
Derivative, Notional Amount		0			0			0
Interest Rate Contract [Member] | Appalachian Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0			0
Interest Rate Contract [Member] | Indiana Michigan Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0			0
Interest Rate Contract [Member] | Ohio Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0			0
Interest Rate Contract [Member] | Public Service Co Of Oklahoma [Member]
Commodity:
Derivative, Notional Amount		0			0			0
Interest Rate Contract [Member] | Southwestern Electric Power Co [Member]
Commodity:
Derivative, Notional Amount		0			0			0
Warrants Held in Investee
Fair Value of Derivative Instruments
Total Assets		16,000,000			16,000,000			$ 32,000,000
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(10,000,000)			(16,000,000)
Vertically Integrated Utilities Revenues [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		(900,000)		500,000	(600,000)		800,000
Vertically Integrated Utilities Revenues [Member] | AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0	0		0
Vertically Integrated Utilities Revenues [Member] | Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0	0		0
Vertically Integrated Utilities Revenues [Member] | Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0	0		0
Vertically Integrated Utilities Revenues [Member] | Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0	0		0
Vertically Integrated Utilities Revenues [Member] | Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0	0		0
Vertically Integrated Utilities Revenues [Member] | Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0	0		0
Generation and Marketing Revenues [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		128,800,000		11,500,000	144,900,000		11,100,000
Generation and Marketing Revenues [Member] | AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0	0		0
Generation and Marketing Revenues [Member] | Appalachian Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0	0		0
Generation and Marketing Revenues [Member] | Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0	0		0
Generation and Marketing Revenues [Member] | Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0	0		0
Generation and Marketing Revenues [Member] | Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0	0		0
Generation and Marketing Revenues [Member] | Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0	0		0
Electric Generation, Transmission and Distribution Revenues [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0	0		0
Electric Generation, Transmission and Distribution Revenues [Member] | AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0	0		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		(900,000)		300,000	(600,000)		400,000
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		0	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	0		0
Electric Generation, Transmission and Distribution Revenues [Member] | Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0	0		0
Electric Generation, Transmission and Distribution Revenues [Member] | Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		0		0	0		100,000
Purchased Electricity for Resale [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		200,000		300,000	1,200,000		1,200,000
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	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		100,000		200,000	1,000,000		1,000,000
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		100,000	100,000		100,000
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	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	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	0		0
Other Operation Expense [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		900,000		(400,000)	1,900,000		(1,400,000)
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		300,000		(100,000)	600,000		(400,000)
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		100,000		(100,000)	200,000		(200,000)
Other Operation Expense [Member] | Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		100,000		(100,000)	200,000		(200,000)
Other Operation Expense [Member] | Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		100,000		(100,000)	300,000		(300,000)
Other Operation Expense [Member] | Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		100,000		(100,000)	200,000		(200,000)
Other Operation Expense [Member] | Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		200,000		(100,000)	300,000		(200,000)
Maintenance Expense [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		1,100,000		(800,000)	2,400,000		(2,200,000)
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		200,000		(200,000)	600,000		(600,000)
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		200,000		(100,000)	400,000		(300,000)
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		(100,000)	200,000		(200,000)
Maintenance Expense [Member] | Ohio Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		200,000		(200,000)	400,000		(400,000)
Maintenance Expense [Member] | Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		100,000		0	200,000		(200,000)
Maintenance Expense [Member] | Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts		100,000		(100,000)	300,000		(300,000)
Regulatory Assets [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	(7,200,000)		7,900,000	(7,800,000)		(8,500,000)
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		200,000	0		(300,000)
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]	(2,900,000)		400,000	(2,900,000)		(100,000)
Regulatory Assets [Member] | Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	(16,900,000)		200,000	(22,900,000)		(200,000)
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]	14,900,000		4,400,000	20,300,000		(9,900,000)
Regulatory Assets [Member] | Public Service Co Of Oklahoma [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	0		(400,000)	0		(600,000)
Regulatory Assets [Member] | Southwestern Electric Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	100,000		2,900,000	1,400,000		2,200,000
Regulatory Liabilities [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	46,500,000		17,000,000	123,600,000		80,900,000
Regulatory Liabilities [Member] | AEP Texas Inc. [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	(100,000)		0	500,000		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]	14,200,000		3,800,000	28,900,000		16,200,000
Regulatory Liabilities [Member] | Indiana Michigan Power Co [Member]
Amount of Gain (Loss) Recognized on Risk Management Contracts
Amount of Gain (Loss) Recognized on Risk Management Contracts	[11]	1,700,000		2,600,000	1,900,000		8,800,000
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]	800,000		1,700,000	5,900,000		8,400,000
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]	14,000,000		3,100,000	40,200,000		23,900,000
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]	$ 12,700,000		$ 2,000,000	$ 38,500,000		$ 14,800,000
[1]	Amounts include $(47) million and $(53) million as of September 30, 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 September 30, 2021 maturity of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $2 million in 2021 and $7 million in periods 2022-2024; Level 2 matures $20 million in 2021, $112 million in periods 2022-2024, $22 million in periods 2025-2026 and $13 million in periods 2027-2033; Level 3 matures $96 million in 2021, $18 million in periods 2022-2024, $5 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 disclosed as gross.  These instruments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with the accounting guidance for “Derivatives and Hedging.”
[9]	Amounts include counterparty netting of risk management and hedging contracts and associated cash collateral in accordance with the accounting guidance for “Derivatives and Hedging.”
[10]	All derivative contracts subject to a master netting arrangement or similar agreement are offset in the statement of financial position.
[11]	Represents realized and unrealized gains and losses subject to regulatory accounting treatment recorded as either current or noncurrent on the balance sheets.

Fair Value Long-term Debt, Othe

Fair Value Long-term Debt, Other Temporary Investments, Nuclear Trusts (Details) - USD ($)		3 Months Ended		9 Months Ended			12 Months Ended
		Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021		Sep. 30, 2020	Dec. 31, 2020
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		$ 34,578,300,000		$ 34,578,300,000			$ 31,072,500,000
Long Term Debt, Fair Value	[1]	38,925,100,000		38,925,100,000			37,457,000,000
Other Temporary Investments
Cost		238,500,000		238,500,000			214,900,000
Gross Unrealized Gains		33,900,000		33,900,000			31,500,000
Gross Unrealized Losses		0		0			0
Other Short-term Investments		272,400,000		272,400,000			246,400,000
Debt and Equity Securities Within Other Temporary Investments
Proceeds from Investment Sales		6,000,000	$ 5,100,000	15,100,000		$ 35,900,000
Purchases of Investments		12,900,000	22,500,000	26,000,000		39,500,000
Gross Realized Gains on Investment Sales		2,400,000	200,000	3,600,000		2,400,000
Gross Realized Losses on Investment Sales		0	0	0		200,000
Nuclear Trust Fund Investments
Fair Value		3,609,800,000		3,609,800,000			3,306,700,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		3,609,800,000		3,609,800,000			3,306,700,000
Spent Nuclear Fuel and Decommissioning Trusts [Member]
Unrealized Gain on Securities				1,700,000,000			1,400,000,000
Nuclear Trust Fund Investments
Gross Unrealized Gains				1,726,900,000			1,509,800,000
Securities Activity Within Decommissioning and SNF Trusts
Proceeds from Investment Sales		433,900,000	316,600,000	1,556,600,000		1,257,100,000
Purchases of Investments		436,600,000	318,600,000	1,586,300,000		1,290,000,000
Gross Realized Gains on Investment Sales		9,600,000	3,400,000	98,300,000		25,400,000
Gross Realized Losses on Investment Sales		7,000,000	500,000	12,500,000		25,200,000
Contractual Maturities, Fair Value of Debt Securities
Within 1 year		292,900,000		292,900,000
After 1 year through 5 years		433,400,000		433,400,000
After 5 years through 10 years		251,500,000		251,500,000
After 10 years		280,900,000		280,900,000
Fair Value Measurements (Textuals)
Adjusted Cost of Debt Securities		1,200,000,000		1,200,000,000			1,100,000,000
Adjusted Cost of Domestic Equity Securities		634,000,000		634,000,000			654,000,000
Unrealized Loss on Securities				4,000,000			9,000,000
Other than Temporary Impairment Losses, Investments				9,000,000			9,200,000
Cash [Member]
Other Temporary Investments
Cost	[2]	77,300,000		77,300,000			68,300,000
Gross Unrealized Gains	[2]	0		0			0
Gross Unrealized Losses	[2]	0		0			0
Other Short-term Investments	[2],[3]	77,300,000		77,300,000			68,300,000
Fixed Income Funds [Member]
Nuclear Trust Fund Investments
Fair Value		1,258,700,000		1,258,700,000			1,226,200,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,258,700,000		1,258,700,000			1,226,200,000
Fixed Income Funds [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains				74,100,000			109,000,000
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				9,000,000			9,200,000
Mutual Funds Fixed Income [Member]
Other Temporary Investments
Cost	[4]	141,800,000		141,800,000			120,700,000
Gross Unrealized Gains	[4]	1,800,000		1,800,000			2,800,000
Gross Unrealized Losses	[4]	0		0			0
Other Short-term Investments	[4]	143,600,000		143,600,000			123,500,000
Domestic [Member]
Nuclear Trust Fund Investments
Fair Value	[5]	2,287,200,000		2,287,200,000			2,054,700,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[5]	2,287,200,000		2,287,200,000			2,054,700,000
Domestic [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains	[6]			1,652,800,000			1,400,800,000
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				0			0
Mutual Funds Equity [Member]
Other Temporary Investments
Cost		19,400,000		19,400,000			25,900,000
Gross Unrealized Gains		32,100,000		32,100,000			28,700,000
Gross Unrealized Losses		0		0			0
Other Short-term Investments	[5]	51,500,000		51,500,000			54,600,000
Cash and Cash Equivalents [Member]
Nuclear Trust Fund Investments
Fair Value	[7]	63,900,000		63,900,000			25,800,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[7]	63,900,000		63,900,000			25,800,000
Cash and Cash Equivalents [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains				0			0
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				0			0
US Government Agencies Debt Securities [Member]
Nuclear Trust Fund Investments
Fair Value		1,135,300,000		1,135,300,000			1,025,600,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,135,300,000		1,135,300,000			1,025,600,000
US Government Agencies Debt Securities [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains				66,900,000			98,500,000
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				6,800,000			7,100,000
Corporate Debt [Member]
Nuclear Trust Fund Investments
Fair Value		86,600,000		86,600,000			86,300,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		86,600,000		86,600,000			86,300,000
Corporate Debt [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains				6,900,000			9,600,000
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				2,000,000			1,700,000
State and Local Jurisdiction [Member]
Nuclear Trust Fund Investments
Fair Value		36,800,000		36,800,000			114,300,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		36,800,000		36,800,000			114,300,000
State and Local Jurisdiction [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Nuclear Trust Fund Investments
Gross Unrealized Gains				300,000			900,000
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				200,000			400,000
AEP Texas Inc. [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		5,216,100,000		5,216,100,000			4,820,400,000
Long Term Debt, Fair Value		5,763,900,000		5,763,900,000			5,682,600,000
AEP Transmission Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		4,393,400,000		4,393,400,000			3,948,500,000
Long Term Debt, Fair Value		5,074,500,000		5,074,500,000			4,984,300,000
Appalachian Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		4,937,800,000		4,937,800,000			4,834,100,000
Long Term Debt, Fair Value		6,067,000,000		6,067,000,000			6,391,800,000
Indiana Michigan Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		3,231,100,000		3,231,100,000			3,029,900,000
Long Term Debt, Fair Value		3,790,500,000		3,790,500,000			3,775,300,000
Nuclear Trust Fund Investments
Fair Value		3,609,800,000		3,609,800,000			3,306,700,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		3,609,800,000		3,609,800,000			3,306,700,000
Indiana Michigan Power Co [Member] | Spent Nuclear Fuel and Decommissioning Trusts [Member]
Unrealized Gain on Securities				1,700,000,000			1,400,000,000
Nuclear Trust Fund Investments
Gross Unrealized Gains				1,726,900,000			1,509,800,000
Securities Activity Within Decommissioning and SNF Trusts
Proceeds from Investment Sales		433,900,000	316,600,000	1,556,600,000		1,257,100,000
Purchases of Investments		436,600,000	318,600,000	1,586,300,000		1,290,000,000
Gross Realized Gains on Investment Sales		9,600,000	3,400,000	98,300,000		25,400,000
Gross Realized Losses on Investment Sales		7,000,000	$ 500,000	12,500,000		$ 25,200,000
Contractual Maturities, Fair Value of Debt Securities
Within 1 year		292,900,000		292,900,000
After 1 year through 5 years		433,400,000		433,400,000
After 5 years through 10 years		251,500,000		251,500,000
After 10 years		280,900,000		280,900,000
Fair Value Measurements (Textuals)
Adjusted Cost of Debt Securities		1,200,000,000		1,200,000,000			1,100,000,000
Adjusted Cost of Domestic Equity Securities		634,000,000		634,000,000			654,000,000
Unrealized Loss on Securities				4,000,000			9,000,000
Other than Temporary Impairment Losses, Investments				9,000,000			9,200,000
Indiana Michigan Power Co [Member] | Fixed Income Funds [Member]
Nuclear Trust Fund Investments
Fair Value		1,258,700,000		1,258,700,000			1,226,200,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,258,700,000		1,258,700,000			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				74,100,000			109,000,000
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				9,000,000			9,200,000
Indiana Michigan Power Co [Member] | Domestic [Member]
Nuclear Trust Fund Investments
Fair Value	[5]	2,287,200,000		2,287,200,000			2,054,700,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[5]	2,287,200,000		2,287,200,000			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				1,652,800,000	[6]		1,400,800,000
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				0			0
Indiana Michigan Power Co [Member] | Cash and Cash Equivalents [Member]
Nuclear Trust Fund Investments
Fair Value	[7]	63,900,000		63,900,000			25,800,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value	[7]	63,900,000		63,900,000			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
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				0			0
Indiana Michigan Power Co [Member] | US Government Agencies Debt Securities [Member]
Nuclear Trust Fund Investments
Fair Value		1,135,300,000		1,135,300,000			1,025,600,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		1,135,300,000		1,135,300,000			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				66,900,000			98,500,000
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				6,800,000			7,100,000
Indiana Michigan Power Co [Member] | Corporate Debt [Member]
Nuclear Trust Fund Investments
Fair Value		86,600,000		86,600,000			86,300,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		86,600,000		86,600,000			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				6,900,000			9,600,000
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				2,000,000			1,700,000
Indiana Michigan Power Co [Member] | State and Local Jurisdiction [Member]
Nuclear Trust Fund Investments
Fair Value		36,800,000		36,800,000			114,300,000
Contractual Maturities, Fair Value of Debt Securities
Fair Value		36,800,000		36,800,000			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				300,000			900,000
Fair Value Measurements (Textuals)
Other than Temporary Impairment Losses, Investments				200,000			400,000
Ohio Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		3,468,100,000		3,468,100,000			2,430,200,000
Long Term Debt, Fair Value		3,948,600,000		3,948,600,000			3,154,900,000
Public Service Co Of Oklahoma [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		1,913,300,000		1,913,300,000			1,373,800,000
Long Term Debt, Fair Value		2,169,200,000		2,169,200,000			1,732,100,000
Southwestern Electric Power Co [Member]
Book Values and Fair Values of Long - term Debt
Total Long-term Debt Outstanding		3,129,900,000		3,129,900,000			2,636,400,000
Long Term Debt, Fair Value		3,534,000,000		3,534,000,000			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		$ 1,600,000,000			$ 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 September 30, 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 $1.7 billion and $1.4 billion and unrealized losses of $4 million and $9 million as of September 30, 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			9 Months Ended
		Sep. 30, 2021		Sep. 30, 2020	Sep. 30, 2021		Sep. 30, 2020	Dec. 31, 2020
Other [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		$ 11,200,000			$ 11,200,000			$ 10,500,000
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		7,900,000			7,900,000			9,000,000
Total Assets		(1,069,800,000)			(1,069,800,000)			(199,000,000)
Risk Management Assets
Risk Management Assets		(1,088,900,000)			(1,088,900,000)			(218,500,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities		(817,500,000)			(817,500,000)			(221,900,000)
Other Short-term Investments		272,400,000			272,400,000			246,400,000
Spent Nuclear Fuel and Decommissioning Trusts		3,609,800,000			3,609,800,000			3,306,700,000
Total Assets		4,575,900,000			4,575,900,000			3,921,800,000
Risk Management Assets		647,500,000			647,500,000			336,900,000
Risk Management Liabilities		306,100,000			306,100,000			311,600,000
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		101,200,000		$ 111,600,000	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]	27,500,000		18,700,000	68,900,000		39,600,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	2,900,000		6,500,000	(64,100,000)		(2,400,000)
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Other Comprehensive Income (Loss)	[3]	17,800,000		2,600,000	35,500,000		21,700,000
Settlements		(54,500,000)		(37,000,000)	(113,300,000)		(115,300,000)
Transfers into Level 3	[4],[5]	(5,800,000)		(1,000,000)	(200,000)		(1,100,000)
Transfers out of Level 3	[5]	(4,100,000)		1,100,000	(26,200,000)		5,600,000
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	44,000,000		3,600,000	115,100,000		48,100,000
Ending Balance		129,000,000		106,100,000	129,000,000		106,100,000
Level 1 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		261,200,000			261,200,000			235,900,000
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		2,343,200,000			2,343,200,000			2,071,500,000
Total Assets		2,651,600,000			2,651,600,000			2,308,300,000
Risk Management Assets
Risk Management Assets		16,900,000			16,900,000			900,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		8,400,000			8,400,000			900,000
Level 2 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0			0
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,258,700,000			1,258,700,000			1,226,200,000
Total Assets		2,740,900,000			2,740,900,000			1,524,400,000
Risk Management Assets
Risk Management Assets		1,466,300,000			1,466,300,000			298,200,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		991,000,000			991,000,000			357,800,000
Level 3 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0			0
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
Total Assets		253,200,000			253,200,000			288,100,000
Risk Management Assets
Risk Management Assets		253,200,000			253,200,000			256,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		124,200,000			124,200,000			174,800,000
2021 [Member] | Level 1 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		2,000,000			2,000,000
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		20,000,000			20,000,000
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		96,000,000			96,000,000			47,000,000
2022 - 2024 [Member] | Level 1 [Member]
Fair Value Measurements 1 (Textuals)
Maturity of Net Fair Value of Risk Management Contracts Prior to Cash Collateral, Assets/Liabilities		7,000,000			7,000,000
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		112,000,000			112,000,000			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		18,000,000			18,000,000			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		22,000,000			22,000,000			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		5,000,000			5,000,000			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		13,000,000			13,000,000			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)			(21,000,000)			(13,000,000)
Risk Management Commodity Contracts [Member] | Other [Member]
Risk Management Assets
Risk Management Assets	[7]	(1,054,000,000)	[8]		(1,054,000,000)	[8]		(190,000,000)	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	(782,600,000)	[8]		(782,600,000)	[8]		(193,400,000)	[9]
Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[7]	275,500,000	[8]		275,500,000	[8]		322,100,000	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	273,200,000	[8]		273,200,000	[8]		218,900,000	[9]
Risk Management Commodity Contracts [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets	[7]	16,900,000	[8]		16,900,000	[8]		900,000	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	8,400,000	[8]		8,400,000	[8]		900,000	[9]
Risk Management Commodity Contracts [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[7]	1,090,700,000	[8]		1,090,700,000	[8]		258,800,000	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	923,300,000	[8]		923,300,000	[8]		244,200,000	[9]
Risk Management Commodity Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[7]	221,900,000	[8]		221,900,000	[8]		252,400,000	[9]
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	124,100,000	[8]		124,100,000	[8]		167,200,000	[9]
Energy Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		145,600,000			145,600,000			213,500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		117,300,000			117,300,000			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			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]	108.40			108.40			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]	35.57			35.57			32.73
Natural Gas Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		9,000,000			9,000,000			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0			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]	2.92			2.92			2.18
Natural Gas Contracts [Member] | Level 3 [Member] | High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[12]	6.27			6.27			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]	4.59			4.59			2.40
FTRs [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		98,600,000			98,600,000			42,800,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		6,900,000			6,900,000			3,400,000
FTRs [Member] | Level 3 [Member] | Low [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	(21.95)			(21.95)			(15.08)
FTRs [Member] | Level 3 [Member] | High [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10]	13.46			13.46			9.66
FTRs [Member] | Level 3 [Member] | Weighted Average [Member]
Level 3 Quantitative Information
Fair Value Significant Unobservable Input Price Per Unit	[10],[11]	0.46			0.46			0.19
Commodity Hedges [Member] | Other [Member]
Risk Management Assets
Risk Management Assets	[7]	(34,900,000)			(34,900,000)			(28,500,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	(34,900,000)			(34,900,000)			(28,500,000)
Commodity Hedges [Member]
Risk Management Assets
Risk Management Assets	[7]	363,700,000			363,700,000			9,800,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	4,100,000			4,100,000			85,200,000
Commodity Hedges [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets	[7]	0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	0			0			0
Commodity Hedges [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[7]	367,300,000			367,300,000			34,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	38,900,000			38,900,000			106,100,000
Commodity Hedges [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[7]	31,300,000			31,300,000			3,900,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7]	100,000			100,000			7,600,000
Interest Rate [Member] | Other [Member]
Risk Management Assets
Risk Management Assets		0			0			0
Interest Rate [Member]
Risk Management Assets
Risk Management Assets		4,900,000			4,900,000			2,400,000
Interest Rate [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets		0			0			0
Interest Rate [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets		4,900,000			4,900,000			2,400,000
Interest Rate [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		0			0			0
Fair Value Hedges [Member] | Other [Member]
Risk Management Assets
Risk Management Assets		0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0			0
Fair Value Hedges [Member]
Risk Management Assets
Risk Management Assets		3,400,000			3,400,000			2,600,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		28,800,000			28,800,000			4,100,000
Fair Value Hedges [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets		0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0			0
Fair Value Hedges [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets		3,400,000			3,400,000			2,600,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		28,800,000			28,800,000			4,100,000
Fair Value Hedges [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0			0
Other Investments | Other [Member]
Risk Management Assets
Risk Management Assets	[13]	0			0			0
Other Investments
Risk Management Assets
Risk Management Assets	[13]	46,200,000			46,200,000			31,800,000
Other Investments | Level 1 [Member]
Risk Management Assets
Risk Management Assets	[13]	30,300,000			30,300,000			0
Other Investments | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[13]	15,900,000			15,900,000			0
Other Investments | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[13]	0			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			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		(900,000)			(900,000)			(400,000)
AEP Texas Inc. [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		43,900,000			43,900,000			28,700,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		43,900,000			43,900,000			28,700,000
AEP Texas Inc. [Member] | Level 1 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		43,900,000			43,900,000			28,700,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		43,900,000			43,900,000			28,700,000
AEP Texas Inc. [Member] | Level 2 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		900,000			900,000			400,000
AEP Texas Inc. [Member] | Level 3 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		0			0			0
AEP Texas Inc. [Member] | Risk Management Commodity Contracts [Member] | Other [Member]
Risk Management Assets
Risk Management Assets	[7]	(900,000)			(900,000)			(400,000)
AEP Texas Inc. [Member] | Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[7]	0			0			0
AEP Texas Inc. [Member] | Risk Management Commodity Contracts [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets	[7]	0			0			0
AEP Texas Inc. [Member] | Risk Management Commodity Contracts [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[7]	900,000			900,000			400,000
AEP Texas Inc. [Member] | Risk Management Commodity Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[7]	0			0			0
Appalachian Power Co [Member] | Other [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		0			0			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		(48,900,000)			(48,900,000)			(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		10,100,000			10,100,000			16,900,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		57,100,000			57,100,000			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		36,600,000		36,500,000	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]	4,000,000		6,400,000	38,800,000		13,100,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	0		0	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	0		0
Settlements		(10,500,000)		(11,100,000)	(58,200,000)		(51,400,000)
Transfers into Level 3	[4],[5]	0		0	0		0
Transfers out of Level 3	[5]	100,000		0	0		700,000
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	15,700,000		(2,200,000)	46,000,000		29,500,000
Ending Balance		45,900,000		29,600,000	45,900,000		29,600,000
Appalachian Power Co [Member] | Level 1 [Member]
Assets, Fair Value Disclosure
Cash and Cash Equivalents		10,100,000			10,100,000			16,900,000
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		10,100,000			10,100,000			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			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		48,900,000			48,900,000			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			0
Spent Nuclear Fuel and Decommissioning Trusts
Total Assets		47,000,000			47,000,000			19,900,000
Risk Management Assets
Risk Management Assets		47,000,000			47,000,000			19,900,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		1,100,000			1,100,000			600,000
Appalachian Power Co [Member] | Risk Management Commodity Contracts [Member] | Other [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	(48,900,000)			(48,900,000)			(19,200,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	(59,100,000)			(59,100,000)			(18,800,000)
Appalachian Power Co [Member] | Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	47,000,000			47,000,000			20,100,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	1,300,000			1,300,000			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			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	0			0			0
Appalachian Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	48,900,000			48,900,000			19,400,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	59,300,000			59,300,000			19,500,000
Appalachian Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	47,000,000			47,000,000			19,900,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	1,100,000			1,100,000			600,000
Appalachian Power Co [Member] | Energy Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		200,000			200,000			1,000,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		1,100,000			1,100,000			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]	26.70			26.70			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]	87.14			87.14			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]	53.61			53.61			25.08
Appalachian Power Co [Member] | FTRs [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		46,800,000			46,800,000			18,900,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			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]	0.35			0.35			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]	13.46			13.46			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]	1.83			1.83			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		7,900,000			7,900,000			9,000,000
Total Assets		(24,500,000)			(24,500,000)			(4,900,000)
Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		3,609,800,000			3,609,800,000			3,306,700,000
Total Assets		3,615,300,000			3,615,300,000			3,310,400,000
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		7,300,000		4,500,000	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]	100,000		3,300,000	400,000		2,400,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	0		0	0		0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Other Comprehensive Income (Loss)	[3]	0		0	0		0
Settlements		(3,800,000)		(5,000,000)	(2,500,000)		(8,500,000)
Transfers into Level 3	[4],[5]	0		0	0		0
Transfers out of Level 3	[5]	0		0	0		400,000
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	(300,000)		1,000,000	3,300,000		3,700,000
Ending Balance		3,300,000		3,800,000	3,300,000		3,800,000
Indiana Michigan Power Co [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		2,343,200,000			2,343,200,000			2,071,500,000
Total Assets		2,343,200,000			2,343,200,000			2,071,500,000
Indiana Michigan Power Co [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,258,700,000			1,258,700,000			1,226,200,000
Total Assets		1,289,600,000			1,289,600,000			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			0
Total Assets		7,000,000			7,000,000			2,500,000
Risk Management Assets
Risk Management Assets		7,000,000			7,000,000			2,500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		3,700,000			3,700,000			400,000
Indiana Michigan Power Co [Member] | Risk Management Commodity Contracts [Member] | Other [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	(32,400,000)			(32,400,000)			(13,900,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	(49,500,000)			(49,500,000)			(12,200,000)
Indiana Michigan Power Co [Member] | Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	5,500,000			5,500,000			3,700,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	2,500,000			2,500,000			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			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	0			0			0
Indiana Michigan Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	30,900,000			30,900,000			15,100,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	48,300,000			48,300,000			12,000,000
Indiana Michigan Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	7,000,000			7,000,000			2,500,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	3,700,000			3,700,000			400,000
Indiana Michigan Power Co [Member] | Energy Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		200,000			200,000			600,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		700,000			700,000			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]	26.70			26.70			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]	87.14			87.14			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]	53.61			53.61			25.08
Indiana Michigan Power Co [Member] | FTRs [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		6,800,000			6,800,000			1,900,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		3,000,000			3,000,000			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]	(1.85)			(1.85)			(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]	5.75			5.75			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]	0.37			0.37			0.33
Ohio Power Co [Member]
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		(105,400,000)		(117,400,000)	(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]	100,000		0	400,000		(1,200,000)
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	0		0	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	0		0
Settlements		900,000		1,300,000	5,800,000		6,400,000
Transfers into Level 3	[4],[5]	0		0			0
Transfers out of Level 3	[5]	0		0	0		0
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	14,000,000		2,900,000	13,700,000		(14,800,000)
Ending Balance		(90,400,000)		(113,200,000)	(90,400,000)		(113,200,000)
Ohio Power Co [Member] | Risk Management Commodity Contracts [Member] | Other [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	(700,000)			(700,000)			(300,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	0			0			0
Ohio Power Co [Member] | Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	90,400,000			90,400,000			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			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	0			0			0
Ohio Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	700,000			700,000			300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	0			0			0
Ohio Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	90,400,000			90,400,000			110,300,000
Ohio Power Co [Member] | Energy Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		90,400,000			90,400,000			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]	9.89			9.89			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]	81.50			81.50			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]	32.40			32.40			28.30
Public Service Co Of Oklahoma [Member]
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		22,900,000		23,800,000	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]	13,500,000		3,000,000	16,100,000		11,900,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	0		0	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	0		0
Settlements		(20,600,000)		(10,300,000)	(26,400,000)		(27,600,000)
Transfers into Level 3	[4],[5]	0		0	0		0
Transfers out of Level 3	[5]	0		0	0		0
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	2,700,000		(400,000)	18,500,000		16,000,000
Ending Balance		18,500,000		16,100,000	18,500,000		16,100,000
Public Service Co Of Oklahoma [Member] | Risk Management Commodity Contracts [Member] | Other [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	(500,000)			(500,000)			(200,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	(200,000)			(200,000)
Public Service Co Of Oklahoma [Member] | Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	18,500,000			18,500,000			10,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	0			0
Public Service Co Of Oklahoma [Member] | Risk Management Commodity Contracts [Member] | Level 1 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	0			0			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[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			300,000			200,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	0			0
Public Service Co Of Oklahoma [Member] | Risk Management Commodity Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	18,700,000			18,700,000			10,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	200,000			200,000
Public Service Co Of Oklahoma [Member] | FTRs [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		18,700,000			18,700,000			10,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		200,000			200,000			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]	(18.86)			(18.86)			(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]	4.10			4.10			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]	(2.44)			(2.44)			(1.93)
Southwestern Electric Power Co [Member]
Changes in the Fair Value of Net Trading Derivatives and other investments
Beginning Balance		14,600,000		3,300,000	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]	5,800,000		1,500,000	9,500,000		2,800,000
Unrealized Gain (Loss) Included in Net Income (or Changes in Net Assets) Relating to Assets Still Held at the Reporting Date	[1]	0		0	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	0		0
Settlements		(9,800,000)		(3,500,000)	(13,000,000)		(6,900,000)
Transfers into Level 3	[4],[5]	0		0	0		0
Transfers out of Level 3	[5]	0		0	0		0
Changes in Fair Value Allocated to Regulated Jurisdiction	[6]	9,000,000		2,400,000	21,500,000		6,400,000
Ending Balance		19,600,000		$ 3,700,000	19,600,000		$ 3,700,000
Southwestern Electric Power Co [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		19,800,000			19,800,000			3,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		200,000			200,000			1,700,000
Southwestern Electric Power Co [Member] | Risk Management Commodity Contracts [Member] | Other [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	(600,000)			(600,000)			(200,000)
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	(200,000)			(200,000)			0
Southwestern Electric Power Co [Member] | Risk Management Commodity Contracts [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	19,600,000			19,600,000			3,200,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	0			0			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			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	0			0			0
Southwestern Electric Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 2 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	400,000			400,000			100,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	0			0			0
Southwestern Electric Power Co [Member] | Risk Management Commodity Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets	[7],[15]	19,800,000			19,800,000			3,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities	[7],[15]	200,000			200,000			1,700,000
Southwestern Electric Power Co [Member] | Natural Gas Contracts [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		9,000,000			9,000,000			0
Liabilities, Fair Value Disclosure
Risk Management Liabilities		0			0			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]	3.58			3.58			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]	6.27			6.27			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]	4.44			4.44			2.41
Southwestern Electric Power Co [Member] | FTRs [Member] | Level 3 [Member]
Risk Management Assets
Risk Management Assets		10,800,000			10,800,000			3,300,000
Liabilities, Fair Value Disclosure
Risk Management Liabilities		200,000			200,000			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]	(18.86)			(18.86)			(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]	4.10			4.10			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]	(2.44)			(2.44)			(1.93)
Cash [Member] | Other [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[16]	11,200,000			11,200,000			10,500,000
Cash [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[16],[17]	77,300,000			77,300,000			68,300,000
Cash [Member] | Level 1 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[16]	66,100,000			66,100,000			57,800,000
Cash [Member] | Level 2 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[16]	0			0			0
Cash [Member] | Level 3 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[16]	0			0			0
Fixed Income Funds [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
Fixed Income Funds [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,258,700,000			1,258,700,000			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			0
Fixed Income Funds [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,258,700,000			1,258,700,000			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			0
Fixed Income Funds [Member] | Indiana Michigan Power Co [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
Fixed Income Funds [Member] | Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,258,700,000			1,258,700,000			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			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		1,258,700,000			1,258,700,000			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			0
Mutual Funds Fixed Income [Member] | Other [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0			0
Mutual Funds Fixed Income [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[18]	143,600,000			143,600,000			123,500,000
Mutual Funds Fixed Income [Member] | Level 1 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		143,600,000			143,600,000			123,500,000
Mutual Funds Fixed Income [Member] | Level 2 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0			0
Mutual Funds Fixed Income [Member] | Level 3 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments		0			0			0
Mutual Funds Equity [Member] | Other [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[19]	0			0			0
Mutual Funds Equity [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[19]	51,500,000			51,500,000			54,600,000
Mutual Funds Equity [Member] | Level 1 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[19]	51,500,000			51,500,000			54,600,000
Mutual Funds Equity [Member] | Level 2 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[19]	0			0			0
Mutual Funds Equity [Member] | Level 3 [Member]
Assets, Fair Value Disclosure
Other Short-term Investments	[19]	0			0			0
Cash and Cash Equivalents [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[20]	7,900,000			7,900,000			9,000,000
Cash and Cash Equivalents [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[20]	63,900,000			63,900,000			25,800,000
Cash and Cash Equivalents [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[20]	56,000,000			56,000,000			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			0
Cash and Cash Equivalents [Member] | Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[20]	0			0			0
Cash and Cash Equivalents [Member] | Indiana Michigan Power Co [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[20]	7,900,000			7,900,000			9,000,000
Cash and Cash Equivalents [Member] | Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[20]	63,900,000			63,900,000			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]	56,000,000			56,000,000			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			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			0
US Government Agencies Debt Securities [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
US Government Agencies Debt Securities [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,135,300,000			1,135,300,000			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			0
US Government Agencies Debt Securities [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,135,300,000			1,135,300,000			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			0
US Government Agencies Debt Securities [Member] | Indiana Michigan Power Co [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
US Government Agencies Debt Securities [Member] | Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,135,300,000			1,135,300,000			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			0
US Government Agencies Debt Securities [Member] | Indiana Michigan Power Co [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		1,135,300,000			1,135,300,000			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			0
Corporate Debt [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
Corporate Debt [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		86,600,000			86,600,000			86,300,000
Corporate Debt [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
Corporate Debt [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		86,600,000			86,600,000			86,300,000
Corporate Debt [Member] | Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
Corporate Debt [Member] | Indiana Michigan Power Co [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
Corporate Debt [Member] | Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		86,600,000			86,600,000			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			0
Corporate Debt [Member] | Indiana Michigan Power Co [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		86,600,000			86,600,000			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			0
State and Local Jurisdiction [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
State and Local Jurisdiction [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		36,800,000			36,800,000			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			0
State and Local Jurisdiction [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		36,800,000			36,800,000			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			0
State and Local Jurisdiction [Member] | Indiana Michigan Power Co [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		0			0			0
State and Local Jurisdiction [Member] | Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts		36,800,000			36,800,000			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			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		36,800,000			36,800,000			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			0
Domestic [Member] | Other [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[19]	0			0			0
Domestic [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[19]	2,287,200,000			2,287,200,000			2,054,700,000
Domestic [Member] | Level 1 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[19]	2,287,200,000			2,287,200,000			2,054,700,000
Domestic [Member] | Level 2 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[19]	0			0			0
Domestic [Member] | Level 3 [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[19]	0			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			0
Domestic [Member] | Indiana Michigan Power Co [Member]
Spent Nuclear Fuel and Decommissioning Trusts
Spent Nuclear Fuel and Decommissioning Trusts	[19]	2,287,200,000			2,287,200,000			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]	2,287,200,000			2,287,200,000			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			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			$ 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 September 30, 2021 maturity of the net fair value of risk management contracts prior to cash collateral, assets/(liabilities), were as follows: Level 1 matures $2 million in 2021 and $7 million in periods 2022-2024; Level 2 matures $20 million in 2021, $112 million in periods 2022-2024, $22 million in periods 2025-2026 and $13 million in periods 2027-2033; Level 3 matures $96 million in 2021, $18 million in periods 2022-2024, $5 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		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21.00%	21.00%	21.00%	21.00%
State Income Tax, net of Federal Benefit	0.60%	2.70%	1.20%	2.60%
Tax Reform Excess ADIT Reversal	(8.50%)	(11.00%)	(8.90%)	(12.10%)
Production and Investment Tax Credits	(4.70%)	(4.60%)	(4.90%)	(4.50%)
Flow Through	0.00%	0.50%	0.20%	0.50%
AFUDC Equity	(1.20%)	(1.50%)	(1.10%)	(1.50%)
Parent Company Loss Benefit	0.00%	0.00%	0.00%	0.00%
Discrete Tax Adjustments (a)	0.20%	(7.40%)	1.10%	(3.00%)
Other	0.70%	0.10%	0.10%	0.20%
Effective Income Tax Rate	8.10%	(0.20%)	8.70%	3.20%
Income Taxes (Textuals) [Abstract]
Income Taxes Receivable		$ 95		$ 95
Tax Cuts and Jobs Act, Change in Tax Rate, Deferred Tax Asset, Income Tax Expense			$ 48
Income Tax Expense Re-Measurement			20
Income Tax Benefit Re-Measurement			$ 1
AEP Texas Inc. [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21.00%	21.00%	21.00%	21.00%
State Income Tax, net of Federal Benefit	0.30%	2.00%	0.30%	1.80%
Tax Reform Excess ADIT Reversal	(6.30%)	(14.60%)	(7.20%)	(23.40%)
Production and Investment Tax Credits	(0.30%)	(0.50%)	(0.30%)	(0.50%)
Flow Through	0.30%	0.20%	0.30%	0.10%
AFUDC Equity	(1.00%)	(3.50%)	(1.10%)	(3.20%)
Parent Company Loss Benefit	(1.10%)	0.00%	(0.70%)	0.00%
Discrete Tax Adjustments (a)	0.00%	(3.60%)	0.00%	(1.60%)
Other	(0.10%)	0.30%	0.00%	0.40%
Effective Income Tax Rate	12.80%	1.30%	12.30%	(5.40%)
AEP Transmission Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21.00%	21.00%	21.00%	21.00%
State Income Tax, net of Federal Benefit	3.00%	2.90%	2.80%	2.90%
Tax Reform Excess ADIT Reversal	0.30%	0.40%	0.30%	0.40%
Production and Investment Tax Credits	0.00%	0.00%	0.00%	0.00%
Flow Through	0.30%	0.50%	0.30%	0.50%
AFUDC Equity	(2.20%)	(2.60%)	(1.90%)	(2.60%)
Parent Company Loss Benefit	(2.30%)	(0.90%)	(1.90%)	(0.90%)
Discrete Tax Adjustments (a)	0.00%	(0.20%)	0.00%	(0.10%)
Other	0.10%	0.10%	0.00%	(0.10%)
Effective Income Tax Rate	20.20%	21.20%	20.60%	21.10%
Appalachian Power Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21.00%	21.00%	21.00%	21.00%
State Income Tax, net of Federal Benefit	(0.30%)	3.10%	1.50%	3.10%
Tax Reform Excess ADIT Reversal	(14.20%)	(22.00%)	(15.20%)	(20.80%)
Production and Investment Tax Credits	(0.20%)	0.00%	0.00%	0.00%
Flow Through	0.40%	1.60%	1.70%	1.60%
AFUDC Equity	(1.80%)	(1.10%)	(1.20%)	(1.10%)
Parent Company Loss Benefit	(1.20%)	(3.10%)	(1.30%)	(3.10%)
Discrete Tax Adjustments (a)	0.00%	(6.60%)	0.00%	(2.30%)
Other	0.30%	0.00%	0.10%	(0.10%)
Effective Income Tax Rate	4.00%	(7.10%)	6.60%	(1.70%)
Indiana Michigan Power Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21.00%	21.00%	21.00%	21.00%
State Income Tax, net of Federal Benefit	1.90%	3.40%	1.60%	3.40%
Tax Reform Excess ADIT Reversal	(16.10%)	(16.70%)	(17.70%)	(16.70%)
Production and Investment Tax Credits	(2.00%)	(1.60%)	(2.20%)	(1.60%)
Flow Through	(2.80%)	0.20%	(3.00%)	0.20%
AFUDC Equity	(1.00%)	(0.90%)	(1.00%)	(0.90%)
Parent Company Loss Benefit	(3.60%)	(3.70%)	(2.80%)	(3.70%)
Discrete Tax Adjustments (a)	0.00%	2.30%	0.00%	1.80%
Other	0.80%	0.00%	0.40%	(0.10%)
Effective Income Tax Rate	(1.80%)	4.00%	(3.70%)	3.40%
Ohio Power Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21.00%	21.00%	21.00%	21.00%
State Income Tax, net of Federal Benefit	1.20%	0.80%	0.80%	0.70%
Tax Reform Excess ADIT Reversal	(8.90%)	(6.70%)	(9.10%)	(8.80%)
Production and Investment Tax Credits	0.00%	0.00%	0.00%	0.00%
Flow Through	0.60%	0.90%	0.90%	0.90%
AFUDC Equity	(0.30%)	(0.90%)	(0.80%)	(0.90%)
Parent Company Loss Benefit	0.00%	(0.30%)	0.00%	(0.30%)
Discrete Tax Adjustments (a)	0.00%	8.40%	(1.30%)	2.60%
Other	0.00%	0.30%	0.20%	0.20%
Effective Income Tax Rate	13.60%	23.50%	11.70%	15.40%
Public Service Co Of Oklahoma [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21.00%	21.00%	21.00%	21.00%
State Income Tax, net of Federal Benefit	5.00%	4.60%	4.80%	4.60%
Tax Reform Excess ADIT Reversal	(19.80%)	(20.30%)	(19.80%)	(20.30%)
Production and Investment Tax Credits	(8.90%)	(1.10%)	(8.10%)	(1.10%)
Flow Through	0.70%	0.20%	0.70%	0.20%
AFUDC Equity	(0.20%)	(0.60%)	(0.30%)	(0.60%)
Parent Company Loss Benefit	0.00%	(1.70%)	0.00%	(1.70%)
Discrete Tax Adjustments (a)	0.00%	(0.60%)	(0.90%)	(0.40%)
Other	(0.10%)	0.10%	(0.20%)	0.10%
Effective Income Tax Rate	(2.30%)	1.60%	(2.80%)	1.80%
Southwestern Electric Power Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal Statutory Rate	21.00%	21.00%	21.00%	21.00%
State Income Tax, net of Federal Benefit	(6.90%)	2.40%	(3.40%)	2.30%
Tax Reform Excess ADIT Reversal	(4.20%)	(7.30%)	(4.30%)	(11.50%)
Production and Investment Tax Credits	(5.40%)	(0.50%)	(4.60%)	(0.50%)
Flow Through	(0.20%)	(1.20%)	(0.20%)	(1.20%)
AFUDC Equity	(0.50%)	(0.30%)	(0.60%)	(0.30%)
Parent Company Loss Benefit	0.70%	(2.00%)	0.00%	(1.90%)
Discrete Tax Adjustments (a)	1.20%	(0.60%)	0.60%	(0.30%)
Other	(0.20%)	(0.60%)	(0.10%)	(0.40%)
Effective Income Tax Rate	5.50%	10.90%	8.40%	7.20%

Financing Activities (Details)

Financing Activities (Details) - USD ($)		1 Months Ended	3 Months Ended								9 Months Ended
		Oct. 28, 2021	Sep. 30, 2021		Jun. 30, 2021	Mar. 31, 2021	Sep. 30, 2020		Jun. 30, 2020	Mar. 31, 2020	Sep. 30, 2021		Sep. 30, 2020	Dec. 31, 2020
Long-term Debt
Senior Unsecured Notes			$ 28,778,100,000								$ 28,778,100,000			$ 25,116,100,000
Pollution Control Bonds			1,881,000,000								1,881,000,000			1,936,700,000
Notes Payable			235,100,000								235,100,000			239,100,000
Securitization Bonds			639,700,000								639,700,000			716,400,000
Spent Nuclear Fuel Obligation	[1]		281,300,000								281,300,000			281,200,000
Junior Subordinated Notes	[2]		1,629,900,000								1,629,900,000			1,624,100,000
Other Long-term Debt			1,133,200,000								1,133,200,000			1,158,900,000
Total Long-term Debt Outstanding			34,578,300,000								34,578,300,000			31,072,500,000
Long-term Debt Due Within One Year			2,521,800,000								2,521,800,000			2,086,100,000
Long-term Debt			32,056,500,000								32,056,500,000			28,986,400,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]										5,115,800,000
Repayments of Long-term Debt											1,549,800,000		$ 700,500,000
Short-term Debt:
Securitized Debt for Receivables	[4]		750,000,000								750,000,000			592,000,000
Commercial Paper			1,254,000,000								1,254,000,000			1,852,300,000
364-Day Term Loan			500,000,000								500,000,000			0
Notes Payable			0								0			35,000,000
Total Short-term Debt			$ 2,504,000,000								$ 2,504,000,000			$ 2,479,300,000
Securitized Debt for Receivables	[4],[5]		0.19%								0.19%			0.85%
Comparative Accounts Receivable Information
Effective Interest Rates on Securitization of Accounts Receivable			0.18%				0.36%				0.19%		1.05%
Net Uncollectible Accounts Receivable Written Off			$ 7,500,000				$ 2,900,000				$ 22,600,000		$ 10,500,000
Customer Accounts Receivable Managed Portfolio
Accounts Receivable Retained Interest and Pledged as Collateral Less Uncollectible Accounts			1,031,300,000								1,031,300,000			$ 958,400,000
Total Principal Outstanding			750,000,000								750,000,000			592,000,000
Delinquent Securitized Accounts Receivable			60,000,000								60,000,000			62,300,000
Bad Debt Reserves Related to Securitization, Sale of Accounts Receivable			39,800,000								39,800,000			60,000,000
Unbilled Receivables Related to Securitization, Sale of Accounts Receivable			224,500,000								224,500,000			296,800,000
Fees Paid to AEP Credit for Customer Accounts Receivable Sold
Fees Paid to AEP Credit for Customer Accounts Receivable Sold			4,623,000,000				4,066,400,000				12,730,600,000		11,307,900,000
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											$ 548,000,000		136,500,000
Trust Fund Assets One Time Fee Obligation for Nuclear Fuel Disposition			327,000,000								$ 327,000,000			$ 324,000,000
Maximum Percentage Debt to Capitalization											67.50%
Total Commitment from Bank Conduits to Finance Receivables			750,000,000								$ 750,000,000
Forward Equity Purchase Contract Included in Current and Noncurrent Liabilities as of September 30,			(7,800,000)		$ (10,500,000)	$ 19,100,000	103,700,000		$ 1,600,000	$ 30,200,000
Commitment from Bank Conduits to Finance Receivables			125,000,000								125,000,000
Commitment from Bank Conduits to Finance Receivables Two			625,000,000								$ 625,000,000
Equity Distribution Agreement
Financing Activities (Textuals)
Stock Issued During Period, Shares, New Issues											5,421,825
Issuance of Common Stock											$ 461,000,000
2020 Equity Units [Member]
Financing Activities (Textuals)
Equity Units Issued											17,000,000
Per Unit Conversion for Equity Units			$ 50								$ 50
Net Equity Units Issuance Proceeds											$ 833,000,000
Corporate unit ownership share of an equity unit			5.00%								5.00%
Principal Amounts of Junior Subordinated Debt											$ 1,000
Forward Equity Purchase Contract Date											2023
Equity Units Annual Distribution Rate			6.125%								6.125%
Forward Equity Contract Payment Rate			4.825%								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								$ 50
Net Equity Units Issuance Proceeds											$ 785,000,000
Corporate unit ownership share of an equity unit			5.00%								5.00%
Principal Amounts of Junior Subordinated Debt											$ 1,000
Forward Equity Purchase Contract Date											2022
Equity Units Annual Distribution Rate			6.125%								6.125%
Forward Equity Contract Payment Rate			2.725%								2.725%
Maximum Shares Issued Under Equity Units Conversion											9,701,860
Junior Subordinated Debt [Member] | 2020 Equity Units [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt											$ 850,000,000
Interest Rate (Percentage)			1.30%								1.30%
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%								3.40%
Senior Unsecured Notes [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]										$ 175,000,000
Due Date											2028
Interest Rate (Percentage)			1.80%								1.80%
Commercial Paper [Member]
Short-term Debt:
Weighted Average Interest Rate	[5]		0.25%								0.25%			0.29%
364 Day Term Loan
Short-term Debt:
Weighted Average Interest Rate	[5]		0.72%								0.72%			0.00%
Loans Payable [Member]
Short-term Debt:
Weighted Average Interest Rate	[5]		0.00%								0.00%			2.55%
AEP Texas Inc. [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 5,216,100,000								$ 5,216,100,000			$ 4,820,400,000
Long-term Debt Due Within One Year			315,100,000								315,100,000			88,700,000
Long-term Debt			4,901,000,000								4,901,000,000			4,731,700,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 52,200,000		$ 356,500,000
Financing Activities (Textuals)
Maximum Percentage Debt to Capitalization											67.50%
AEP Texas Inc. [Member] | Utility [Member]
Maximum Interest Rate											0.40%		2.70%
Minimum Interest Rate											0.02%		0.33%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool											$ 355,500,000
Maximum Loans to Money Pool											104,700,000
Average Borrowings from Money Pool											234,700,000
Average Loans to Money Pool											45,200,000
Net Loans (Borrowings) to/from Money Pool			47,600,000								47,600,000
Authorized Short Term Borrowing Limit											$ 500,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed											0.33%		1.55%
Average Interest Rate For Funds Loaned											0.27%		0.87%
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			$ 7,000,000								$ 7,000,000
Maximum and Minimum Interest Rates
Maximum Interest Rate For Funds Loaned											0.41%		2.70%
Minimum Interest Rate for Funds Loaned											0.21%		0.33%
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Loaned											0.34%		1.44%
AEP Texas Inc. [Member] | Securitization Bonds [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 29,700,000
Due Date											2024
Interest Rate (Percentage)			2.85%								2.85%
AEP Texas Inc. [Member] | Securitization Bonds Two [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 22,500,000
Due Date											2025
Interest Rate (Percentage)			2.06%								2.06%
AEP Texas Inc. [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											2051
Interest Rate (Percentage)			3.45%								3.45%
AEP Transmission Co [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 4,393,400,000								$ 4,393,400,000			3,948,500,000
Long-term Debt Due Within One Year			50,000,000								50,000,000			50,000,000
Long-term Debt			4,343,400,000								4,343,400,000			3,898,500,000
Financing Activities (Textuals)
Sub-Limit of Secured Debt			$ 50,000,000								$ 50,000,000
Maximum Percentage of Consolidated Tangible Net Assets			10.00%								10.00%
Tangible Capital to Tangible Assets			0.10%								0.10%
Maximum Percentage Debt to Capitalization											67.50%
AEP Transmission Co [Member] | Utility [Member]
Maximum Interest Rate											0.40%		2.70%
Minimum Interest Rate											0.02%		0.33%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool											$ 444,900,000
Maximum Loans to Money Pool											117,300,000
Average Borrowings from Money Pool											225,100,000
Average Loans to Money Pool											24,400,000
Net Loans (Borrowings) to/from Money Pool			$ 73,900,000								73,900,000
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											0.32%		1.63%
Average Interest Rate For Funds Loaned											0.07%		2.00%
AEP Transmission Co [Member] | Direct Borrowing [Member]
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool											$ 14,600,000
Maximum Loans to Money Pool											224,200,000
Average Borrowings from Money Pool											1,600,000
Average Loans to Money Pool											139,300,000
Borrowings from Parent			8,600,000								8,600,000
Loans to Parent			$ 0								0
Authorized Short Term Borrowing Limit	[7]										$ 50,000,000
Maximum and Minimum Interest Rates
Maximum Interest Rate for Funds Borrowed											0.86%		2.70%
Minimum Interest Rate For Funds Borrowed											0.25%		0.50%
Maximum Interest Rate For Funds Loaned											0.86%		2.70%
Minimum Interest Rate for Funds Loaned											0.25%		0.50%
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed											0.35%		1.45%
Average Interest Rate For Funds Loaned											0.34%		1.40%
AEP Transmission Co [Member] | Senior Unsecured Notes [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]										$ 450,000,000
Due Date											2051
Interest Rate (Percentage)			2.75%								2.75%
Appalachian Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 4,937,800,000								$ 4,937,800,000			4,834,100,000
Long-term Debt Due Within One Year			380,600,000								380,600,000			518,300,000
Long-term Debt			4,557,200,000								4,557,200,000			4,315,800,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											393,000,000		$ 90,300,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues			131,000,000								131,000,000			136,000,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit			342,200,000				323,500,000				$ 980,600,000		961,800,000
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			1,300,000	[8]			2,000,000				$ 3,700,000	[8]	$ 5,000,000
Appalachian Power Co [Member] | Utility [Member]
Maximum Interest Rate											0.40%		2.70%
Minimum Interest Rate											0.02%		0.33%
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											134,400,000
Net Loans (Borrowings) to/from Money Pool			$ 185,200,000								185,200,000
Authorized Short Term Borrowing Limit											$ 500,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed											0.28%		2.14%
Average Interest Rate For Funds Loaned											0.28%		0.99%
Appalachian 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											$ 100,000
Due Date											2026
Interest Rate (Percentage)			13.72%								13.72%
Appalachian Power Co [Member] | Pollution Control Bond [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 17,500,000
Due Date											2021
Interest Rate (Percentage)			4.63%								4.63%
Appalachian Power Co [Member] | Securitization Bonds [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 25,400,000
Due Date											2023
Interest Rate (Percentage)			2.01%								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											$ 500,000,000
Due Date											2031
Interest Rate (Percentage)			2.70%								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%								4.60%
Indiana Michigan Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 3,231,100,000								$ 3,231,100,000			3,029,900,000
Long-term Debt Due Within One Year			132,700,000								132,700,000			369,600,000
Long-term Debt			3,098,400,000								3,098,400,000			2,660,300,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											307,200,000		$ 71,100,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues			173,900,000								173,900,000			170,500,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit			536,800,000				532,300,000				1,478,900,000		1,443,600,000
Financing Activities (Textuals)
Trust Fund Assets One Time Fee Obligation for Nuclear Fuel Disposition			327,000,000								327,000,000			324,000,000
Reacquired Pollution Control Bonds Held by Trustees			40,000,000								$ 40,000,000
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			2,100,000	[8]			3,900,000				$ 5,300,000	[8]	$ 9,300,000
Indiana Michigan Power Co [Member] | Utility [Member]
Maximum Interest Rate											0.40%		2.70%
Minimum Interest Rate											0.02%		0.33%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool											$ 166,500,000
Maximum Loans to Money Pool											368,200,000
Average Borrowings from Money Pool											117,500,000
Average Loans to Money Pool											76,300,000
Net Loans (Borrowings) to/from Money Pool			$ 80,600,000								80,600,000
Authorized Short Term Borrowing Limit											$ 500,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed											0.32%		1.30%
Average Interest Rate For Funds Loaned											0.25%		1.44%
Indiana Michigan Power Co [Member] | Notes Payable, Other Payables [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]										$ 64,900,000
Due Date											2025
Interest Rate (Percentage)			0.93%								0.93%
Indiana Michigan Power Co [Member] | Notes Payable, Other Payables [Member] | Subsequent Event [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt		$ 8,000,000
Indiana Michigan Power Co [Member] | Notes Payable, Other Payable Two [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 1,900,000
Due Date											2021
Interest Rate (Variable)											Variable
Indiana Michigan Power Co [Member] | Notes Payable, Other Payable Three [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 4,500,000
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											$ 5,400,000
Due Date											2022
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											$ 14,300,000
Due Date											2023
Interest Rate (Variable)											Variable
Indiana Michigan Power Co [Member] | Notes Payable, Other Payable Six [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 12,600,000
Due Date											2024
Interest Rate (Variable)											Variable
Indiana Michigan Power Co [Member] | Notes Payable, Other Payable Seven [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 19,600,000
Due Date											2025
Interest Rate (Variable)											Variable
Indiana Michigan Power Co [Member] | Notes Payable, Other Payable Eight [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 7,400,000
Due Date											2025
Interest Rate (Percentage)			0.93%								0.93%
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											$ 200,000,000
Due Date											2021
Interest Rate (Variable)											Variable
Indiana Michigan Power Co [Member] | Other Long Term Debt Two [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 1,500,000
Due Date											2025
Interest Rate (Percentage)			6.00%								6.00%
Indiana Michigan Power Co [Member] | Pollution Control Bond [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 40,000,000
Due Date											2021
Interest Rate (Percentage)			2.05%								2.05%
Indiana Michigan 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											2051
Interest Rate (Percentage)			3.25%								3.25%
Ohio Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 3,468,100,000								$ 3,468,100,000			2,430,200,000
Long-term Debt Due Within One Year			500,100,000								500,100,000			500,100,000
Long-term Debt			2,968,000,000								2,968,000,000			1,930,100,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											100,000		$ 100,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues			377,300,000								377,300,000			398,800,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit			668,400,000				666,000,000				1,867,500,000		1,793,000,000
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			4,600,000	[8]			9,800,000				$ 3,500,000	[8]	$ 19,600,000
Ohio Power Co [Member] | Utility [Member]
Maximum Interest Rate											0.40%		2.70%
Minimum Interest Rate											0.02%		0.33%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool											$ 259,200,000
Maximum Loans to Money Pool											622,900,000
Average Borrowings from Money Pool											62,800,000
Average Loans to Money Pool											182,500,000
Net Loans (Borrowings) to/from Money Pool			$ 622,900,000								622,900,000
Authorized Short Term Borrowing Limit											$ 500,000,000
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Borrowed											0.27%		1.32%
Average Interest Rate For Funds Loaned											0.15%		2.06%
Ohio 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											$ 100,000
Due Date											2028
Interest Rate (Percentage)			1.15%								1.15%
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%								1.63%
Ohio Power Co [Member] | Senior Unsecured Notes [Member] | Subsequent Event [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt		$ 500,000,000
Ohio Power Co [Member] | Senior Unsecured Notes Two [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]										$ 600,000,000
Due Date											2051
Interest Rate (Percentage)			2.90%								2.90%
Public Service Co Of Oklahoma [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 1,913,300,000								$ 1,913,300,000			1,373,800,000
Long-term Debt Due Within One Year			500,000								500,000			500,000
Long-term Debt			1,912,800,000								1,912,800,000			1,373,300,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											750,400,000		$ 13,000,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues			147,100,000								147,100,000			85,000,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit			460,100,000				369,200,000				$ 1,068,800,000		961,400,000
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			1,100,000	[8]			1,500,000				$ 2,400,000	[8]	$ 3,800,000
Public Service Co Of Oklahoma [Member] | Utility [Member]
Maximum Interest Rate											0.40%		2.70%
Minimum Interest Rate											0.02%		0.33%
Money Pool Participants Money Pool Activity And Authorized Borrowing Limits
Maximum Borrowings from Money Pool											$ 267,700,000
Maximum Loans to Money Pool											747,300,000
Average Borrowings from Money Pool											142,800,000
Average Loans to Money Pool											184,900,000
Net Loans (Borrowings) to/from Money Pool			$ 59,500,000								59,500,000
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											0.34%		1.24%
Average Interest Rate For Funds Loaned											0.06%		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
Repayments of Long-term Debt											$ 400,000
Due Date											2027
Interest Rate (Percentage)			3.00%								3.00%
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											$ 500,000,000
Due Date											2022
Interest Rate (Variable)											Variable
Public Service Co Of Oklahoma [Member] | Senior Unsecured Notes [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]										$ 400,000,000
Due Date											2031
Interest Rate (Percentage)			2.20%								2.20%
Public Service Co Of Oklahoma [Member] | Senior Unsecured Notes Two [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]										$ 400,000,000
Due Date											2051
Interest Rate (Percentage)			3.15%								3.15%
Public Service Co Of Oklahoma [Member] | OtherLongTermDebtThree
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] | Senior Unsecured Notes Three
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%								4.40%
Southwestern Electric Power Co [Member]
Long-term Debt
Total Long-term Debt Outstanding			$ 3,129,900,000								$ 3,129,900,000			2,636,400,000
Long-term Debt Due Within One Year			381,200,000								381,200,000			106,200,000
Long-term Debt			2,748,700,000								2,748,700,000			2,530,200,000
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											4,700,000		$ 19,700,000
Short-term Debt:
Notes Payable			0								0			35,000,000
Accounts Receivable and Accrued Unbilled Revenues
Accounts Receivable and Accrued Unbilled Revenues			185,600,000								185,600,000			$ 158,600,000
Proceeds from Sale of Receivables
Proceeds from Sale of Receivables to AEP Credit			488,500,000				478,300,000				$ 1,265,500,000		1,225,300,000
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			1,300,000	[8]			2,800,000				$ 4,100,000	[8]	$ 6,800,000
Southwestern Electric Power Co [Member] | Utility [Member]
Maximum Interest Rate											0.40%		2.70%
Minimum Interest Rate											0.02%		0.33%
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											148,000,000
Average Loans to Money Pool											142,000,000
Net Loans (Borrowings) to/from Money Pool			(122,900,000)								(122,900,000)
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%		1.55%
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								$ 2,100,000
Maximum and Minimum Interest Rates
Maximum Interest Rate For Funds Loaned											0.41%		2.70%
Minimum Interest Rate for Funds Loaned											0.21%		0.33%
Average Interest Rates for Funds Borrowed From and Loaned to Money Pool
Average Interest Rate For Funds Loaned											0.34%		1.44%
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											$ 3,200,000
Due Date											2032
Interest Rate (Percentage)			4.58%								4.58%
Southwestern Electric 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											$ 1,500,000
Due Date											2028
Interest Rate (Percentage)			4.68%								4.68%
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%								1.65%
Southwestern Electric Power Co [Member] | Loans Payable [Member]
Short-term Debt:
Weighted Average Interest Rate	[5]		0.00%								0.00%			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]										$ 25,900,000
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%								2.75%
Transource Energy [Member] | Senior Unsecured Notes Two [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%								2.75%
Kentucky Power Co [Member] | Other Long Term Debt [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Proceeds from Issuance of Debt	[3]										$ 150,000,000
Due Date											2023
Interest Rate (Variable)											Variable
Kentucky Power Co [Member] | Senior Unsecured Notes [Member]
Long-term Debt and Other Securities Issued, Retired and Principal Payments Made
Repayments of Long-term Debt											$ 39,800,000
Due Date											2021
Interest Rate (Percentage)			7.25%								7.25%
Maximum [Member] | 2020 Equity Units [Member]
Financing Activities (Textuals)
AEP Share Price for Equity Unit Conversion			$ 99.95								$ 99.95
Shares Per Equity Unit			0.6003								0.6003
Maximum [Member] | 2019 Equity Units [Member]
Financing Activities (Textuals)
AEP Share Price for Equity Unit Conversion			$ 99.58								$ 99.58
Shares Per Equity Unit			0.6026								0.6026
Minimum [Member] | 2020 Equity Units [Member]
Financing Activities (Textuals)
AEP Share Price for Equity Unit Conversion			$ 83.29								$ 83.29
Shares Per Equity Unit			0.5003								0.5003
Minimum [Member] | 2019 Equity Units [Member]
Financing Activities (Textuals)
AEP Share Price for Equity Unit Conversion			$ 82.98								$ 82.98
Shares Per Equity Unit			0.5021								0.5021
Retained Earnings [Member]
Financing Activities (Textuals)
Forward Equity Purchase Contract Included in Current and Noncurrent Liabilities as of September 30,					400,000	600,000					$ 0		$ 120,600,000
Additional Paid-in Capital [Member]
Financing Activities (Textuals)
Forward Equity Purchase Contract Included in Current and Noncurrent Liabilities as of September 30,			$ (6,300,000)		$ 200,000	$ 21,900,000	$ 104,000,000	[9]	$ 2,600,000	$ 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 September 30,											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 September 30,											$ 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 $327 million and $324 million as of September 30, 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.
[8]	In 2020, an increase in allowance for doubtful accounts was recognized in response to the anticipated impact of COVID-19 on the collectability of accounts receivable, which caused an increase in fees paid by the registrants. In 2021, due to higher than expected collections of accounts receivables, allowance for doubtful accounts was adjusted resulting in the issuance of credits to offset the higher fees previously paid and to lower subsequent fees paid.
[9]	Includes $(121) million related to a forward equity purchase contract associated with the issuance of Equity Units.

Property, Plant and Equipment_3

Property, Plant and Equipment (Details) - USD ($) $ in Millions		9 Months Ended	12 Months Ended
		Sep. 30, 2021	Dec. 31, 2020
Asset Retirement Obligations (ARO)
Beginning Balance	[1],[2],[3],[4]	$ 2,516.7
Accretion Expense	[1],[2],[3],[4]	77.6
Liabilities Incurred	[1],[2],[3],[4]	17.7
Liabilities Settled	[1],[2],[3],[4]	(27.6)
Asset Retirement Obligation, Revision of Estimate	[1],[2],[3],[4]	75.1
Ending Balance	[1],[2],[3],[4]	2,659.5	$ 2,516.7
Appalachian Power Co [Member]
Asset Retirement Obligations (ARO)
Beginning Balance	[2],[3]	313.1
Accretion Expense	[2],[3]	9.9
Liabilities Incurred	[2],[3]	0
Liabilities Settled	[2],[3]	(5.8)
Asset Retirement Obligation, Revision of Estimate	[2],[3]	84.7
Ending Balance	[2],[3]	401.9	313.1
Indiana Michigan Power Co [Member]
Property, Plant and Equipment (Textuals)
Asset Retirement Obligations (ARO) Liability for Nuclear Decommissioning of the Cook Plant		1,850	1,800
Glen Lyn Station [Member] | Appalachian Power Co [Member]
Asset Retirement Obligations (ARO)
Asset Retirement Obligation, Revision of Estimate		$ 79	$ 199
[1]	Includes ARO related to Sabine and DHLC.
[2]	Includes ARO related to asbestos removal.
[3]	Includes ARO related to ash disposal facilities.
[4]	Includes ARO related to nuclear decommissioning costs for the Cook Plant of $1.85 billion and $1.80 billion as of September 30, 2021 and December 31, 2020, respectively.

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Details) - USD ($) $ in Millions		3 Months Ended				9 Months Ended
		Sep. 30, 2021		Sep. 30, 2020		Sep. 30, 2021		Sep. 30, 2020		Dec. 31, 2020
Disaggregation of Revenue
Revenue from Contracts with Customers		$ 4,623		$ 4,066.4		$ 12,730.6		$ 11,307.9
Revenues		4,623		4,066.4		12,730.6		11,307.9
Revenue, Performance Obligation
Fixed Performance Obligations		836				836
Revenue Textuals
Revenue from Related Parties		0		0		0		0
Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		3,360.8		3,116.7		9,147.6		8,664.6
Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,742.3		1,648.1		4,657.4		4,399.7
Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		898.8		818.9		2,446.1		2,316
Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		661.1		598.3		1,885.8		1,798.6
Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		58.6		51.4		158.3		150.3
Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,008		872.3		3,097.8		2,436.4
Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		281.6		188.9		876.5		553.5
Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		308.8	[1]	244.3	[2]	878.6	[3]	786	[4]
Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		23.5	[5]	15.5	[6]	65	[7]	49.5	[8]
Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		394.1	[9]	423.6	[10]	1,277.7	[11]	1,047.4	[12]
Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		93.5	[5]	70.2	[6]	261	[7]	224.3	[8]
Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		4,462.3		4,059.2		12,506.4		11,325.3
Alternative and Other [Member]
Disaggregation of Revenue
Revenues		160.7		7.2		224.2		(17.4)
Alternative [Member]
Disaggregation of Revenue
Revenues		5.9	[5]	12.7	[6]	35.5	[7]	(30.7)	[8]
Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		93.8		77.4		276.2		220.4
Revenues		154.8	[5]	(5.5)	[6]	188.7	[7]	13.3	[8]
2021 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		314.9				314.9
2022-2023 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		199.3				199.3
2024-2025 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		160.3				160.3
After 2025
Revenue, Performance Obligation
Fixed Performance Obligations		161.5				161.5
AEP Texas Inc. [Member]
Disaggregation of Revenue
Revenues		432.6		432		1,195.3		1,257.1
Revenue, Performance Obligation
Fixed Performance Obligations		132.7				132.7
Affiliated Companies - Contracts with Customers		4.8				4.8				$ 5.1
Revenue Textuals
Revenue from Related Parties		0.9		41.4		2.9		89.4
AEP Texas Inc. [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		295.2		275.1		793.6		846.7
AEP Texas Inc. [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		172.5		165.3		423.7		447.8
AEP Texas Inc. [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		89.1		78		265.2		285.2
AEP Texas Inc. [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		25.4		24.9		81.6		91.4
AEP Texas Inc. [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		8.2		6.9		23.1		22.3
AEP Texas Inc. [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		131.5		101.8		364.5		290.4
AEP Texas Inc. [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[13]	0	[14]	0	[15]	0	[16]
AEP Texas Inc. [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		131.5	[17]	101.8	[18]	364.5	[19]	290.4	[20]
AEP Texas Inc. [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		6.8	[21]	15.2	[22]	35.4	[23]	33.4	[24]
AEP Texas Inc. [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		433.5		392.1		1,193.5		1,170.5
AEP Texas Inc. [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(0.9)		39.9		1.8		86.6
AEP Texas Inc. [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		(0.9)	[25]	(0.7)	[26]	1.8	[27]	(0.3)	[28]
AEP Texas Inc. [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0.9		0.5		3.3		2.5
Revenues		0	[25]	40.6	[26]	0	[27]	86.9	[28]
AEP Texas Inc. [Member] | 2021 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		132.7				132.7
AEP Texas Inc. [Member] | 2022-2023 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
AEP Texas Inc. [Member] | 2024-2025 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
AEP Texas Inc. [Member] | After 2025
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
AEP Transmission Co [Member]
Disaggregation of Revenue
Revenues		377		304.1		1,104.2		837.8
Revenue, Performance Obligation
Fixed Performance Obligations		331.7				331.7
Affiliated Companies - Contracts with Customers		96.7				96.7				81.2
Revenue Textuals
Revenue from Related Parties		297.6		241.2		864.6		652.6
AEP Transmission Co [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
AEP Transmission Co [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
AEP Transmission Co [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
AEP Transmission Co [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
AEP Transmission Co [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
AEP Transmission Co [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		360.1		305.7		1,045.2		902.6
AEP Transmission Co [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[13]	0	[14]	0	[15]	0	[16]
AEP Transmission Co [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		360.1	[17]	305.7	[18]	1,045.2	[19]	902.6	[20]
Revenue Textuals
Revenue from Related Parties		281		243		823		715
AEP Transmission Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		5	[21]	3	[22]	12.5	[23]	17.5	[24]
AEP Transmission Co [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		365.1		308.7		1,057.7		920.1
AEP Transmission Co [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		11.9		(4.6)		46.5		(82.3)
AEP Transmission Co [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		11.9	[25]	(4.6)	[26]	46.5	[27]	(82.3)	[28]
AEP Transmission Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0.2		0		0.3		0.6
Revenues		0	[25]	0	[26]	0	[27]	0	[28]
AEP Transmission Co [Member] | Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		96.4				96.4				81
AEP Transmission Co [Member] | 2021 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		331.7				331.7
AEP Transmission Co [Member] | 2022-2023 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
AEP Transmission Co [Member] | 2024-2025 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
AEP Transmission Co [Member] | After 2025
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
Appalachian Power Co [Member]
Disaggregation of Revenue
Revenues		804		735.7		2,298		2,122.6
Revenue, Performance Obligation
Fixed Performance Obligations		117.6				117.6
Affiliated Companies - Contracts with Customers		77.4				77.4				64.3
Revenue Textuals
Revenue from Related Parties		52.4		44.4		140.6		124.9
Appalachian Power Co [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		660.4		619.6		1,919.6		1,810.9
Appalachian Power Co [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		340.1		324.2		1,025		954.4
Appalachian Power Co [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		146.9		138.4		409.5		390.6
Appalachian Power Co [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		154.8		139.4		433.4		415
Appalachian Power Co [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		18.6		17.6		51.7		50.9
Appalachian Power Co [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		118.9		101.1		325.3		276.8
Appalachian Power Co [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		83.7	[13]	70.3	[14]	231.2	[15]	185.3	[16]
Revenue Textuals
Revenue from Related Parties		30		28		90		85
Appalachian Power Co [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		35.2	[17]	30.8	[18]	94.1	[19]	91.5	[20]
Appalachian Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		22.5	[21]	16.1	[22]	43.6	[23]	46.8	[24]
Appalachian Power Co [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		801.8		736.8		2,288.5		2,134.5
Appalachian Power Co [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		2.2		(1.1)		9.5		(11.9)
Appalachian Power Co [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		2.2	[25]	(1.1)	[26]	9.5	[27]	(11.9)	[28]
Appalachian Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		3.1		2.4		8.2		7.8
Revenues		0	[25]	0	[26]	0	[27]	0	[28]
Appalachian Power Co [Member] | Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		64.1				64.1				52.7
Appalachian Power Co [Member] | 2021 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		44.9				44.9
Appalachian Power Co [Member] | 2022-2023 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		34.5				34.5
Appalachian Power Co [Member] | 2024-2025 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		26.6				26.6
Appalachian Power Co [Member] | After 2025
Revenue, Performance Obligation
Fixed Performance Obligations		11.6				11.6
Indiana Michigan Power Co [Member]
Disaggregation of Revenue
Revenues		635.7		586.7		1,784		1,703.6
Revenue, Performance Obligation
Fixed Performance Obligations		34.8				34.8
Affiliated Companies - Contracts with Customers		37.9				37.9				51.3
Revenue Textuals
Revenue from Related Parties		1.1		1.3		2.6		9.1
Indiana Michigan Power Co [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		523.7		499.7		1,431.7		1,400
Indiana Michigan Power Co [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		231.7		222.6		624.4		610.8
Indiana Michigan Power Co [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		143.9		135.8		384.5		376
Indiana Michigan Power Co [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		146.8		139.7		418.9		408.2
Indiana Michigan Power Co [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1.3		1.6		3.9		5
Indiana Michigan Power Co [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		88.9		68.9		273.4		237.6
Indiana Michigan Power Co [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		80.2	[13]	61.5	[14]	248.1	[15]	215.5	[16]
Indiana Michigan Power Co [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		8.7	[17]	7.4	[18]	25.3	[19]	22.1	[20]
Indiana Michigan Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		24.2	[21]	17.7	[22]	81.9	[23]	60.6	[24]
Indiana Michigan Power Co [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		636.8		586.3		1,787		1,698.2
Indiana Michigan Power Co [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(1.1)		0.4		(3)		5.4
Indiana Michigan Power Co [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		(1.1)	[25]	0.4	[26]	(3)	[27]	5.4	[28]
Indiana Michigan Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1.7		1.2		5.1		3.7
Revenues		0	[25]	0	[26]	0	[27]	0	[28]
Revenue Textuals
Revenue from Related Parties		17		15		46		49
Indiana Michigan Power Co [Member] | Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		24.6				24.6				34.8
Indiana Michigan Power Co [Member] | 2021 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		10				10
Indiana Michigan Power Co [Member] | 2022-2023 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		11.5				11.5
Indiana Michigan Power Co [Member] | 2024-2025 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		8.8				8.8
Indiana Michigan Power Co [Member] | After 2025
Revenue, Performance Obligation
Fixed Performance Obligations		4.5				4.5
Ohio Power Co [Member]
Disaggregation of Revenue
Revenues		767.7		741		2,196.5		2,071.7
Revenue, Performance Obligation
Fixed Performance Obligations		32.3				32.3
Affiliated Companies - Contracts with Customers		64.7				64.7				65.1
Revenue Textuals
Revenue from Related Parties		4.3		8.3		21.9		33
Ohio Power Co [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		689.1		682.8		1,968		1,878.8
Ohio Power Co [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		425.4		429.4		1,217.5		1,162.6
Ohio Power Co [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		190.8		181.2		538.9		507.3
Ohio Power Co [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		69.8		69.1		202.2		199.1
Ohio Power Co [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		3.1		3.1		9.4		9.8
Ohio Power Co [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		19.1		17.2		56.2		51.1
Ohio Power Co [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[13]	0	[14]	0	[15]	0	[16]
Ohio Power Co [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		19.1	[17]	17.2	[18]	56.2	[19]	51.1	[20]
Ohio Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		47.3	[21]	27.6	[22]	113.8	[23]	78.9	[24]
Ohio Power Co [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		755.5		727.6		2,138		2,008.8
Ohio Power Co [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		12.2		13.4		58.5		62.9
Ohio Power Co [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		7.3	[25]	10	[26]	44.3	[27]	49.6	[28]
Ohio Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2.4		2.3		6.8		7.3
Revenues		4.9	[25]	3.4	[26]	14.2	[27]	13.3	[28]
Ohio Power Co [Member] | Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		44.5				44.5				45.9
Ohio Power Co [Member] | 2021 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		22.2				22.2
Ohio Power Co [Member] | 2022-2023 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		10.1				10.1
Ohio Power Co [Member] | 2024-2025 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
Ohio Power Co [Member] | After 2025
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
Public Service Co Of Oklahoma [Member]
Disaggregation of Revenue
Revenues		483.8		382.2		1,124.4		988.1
Revenue, Performance Obligation
Fixed Performance Obligations		3.5				3.5
Affiliated Companies - Contracts with Customers		31.7				31.7				15.6
Revenue Textuals
Revenue from Related Parties		1		1.4		3.1		3.8
Payments to Acquire Property, Plant, and Equipment						297		0
Public Service Co Of Oklahoma [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		458.2		363.6		1,063.5		933.3
Public Service Co Of Oklahoma [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		236.8		195.8		516.4		463.5
Public Service Co Of Oklahoma [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		120.9		94.4		286.8		247.8
Public Service Co Of Oklahoma [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		77.1		55		202.1		170.8
Public Service Co Of Oklahoma [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		23.4		18.4		58.2		51.2
Public Service Co Of Oklahoma [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		17.8		14.3		35.6		30.1
Public Service Co Of Oklahoma [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		7.2	[13]	5.8	[14]	6.8	[15]	9.9	[16]
Public Service Co Of Oklahoma [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		10.6	[17]	8.5	[18]	28.8	[19]	20.2	[20]
Public Service Co Of Oklahoma [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		8.3	[21]	4.8	[22]	24.8	[23]	23.2	[24]
Public Service Co Of Oklahoma [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		484.3		382.7		1,123.9		986.6
Public Service Co Of Oklahoma [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(0.5)		(0.5)		0.5		1.5
Public Service Co Of Oklahoma [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		(0.5)	[25]	(0.5)	[26]	0.5	[27]	1.5	[28]
Public Service Co Of Oklahoma [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1.5		1		3.9		8
Revenues		0	[25]	0	[26]	0	[27]	0	[28]
Public Service Co Of Oklahoma [Member] | Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		17.7				17.7				7.8
Public Service Co Of Oklahoma [Member] | 2021 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		3.5				3.5
Public Service Co Of Oklahoma [Member] | 2022-2023 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
Public Service Co Of Oklahoma [Member] | 2024-2025 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
Public Service Co Of Oklahoma [Member] | After 2025
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
Southwestern Electric Power Co [Member]
Disaggregation of Revenue
Revenues		584.1		517.3		1,630.3		1,318.2
Revenue, Performance Obligation
Fixed Performance Obligations		10.1				10.1
Affiliated Companies - Contracts with Customers		35.6				35.6				25.1
Revenue Textuals
Revenue from Related Parties		13.5		10.9		32.2		31.5
Payments to Acquire Property, Plant, and Equipment						355.8		0
Southwestern Electric Power Co [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		464		440.5		1,186.8		1,102.4
Southwestern Electric Power Co [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		230.9		219.4		547.1		498.7
Southwestern Electric Power Co [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		145.4		135		385.4		351.2
Southwestern Electric Power Co [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		85.4		83.8		247.1		245.9
Southwestern Electric Power Co [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2.3		2.3		7.2		6.6
Southwestern Electric Power Co [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		114.2		71		420.7		194.2
Southwestern Electric Power Co [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		77.1	[13]	42.3	[14]	326.2	[15]	106.7	[16]
Southwestern Electric Power Co [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		37.1	[17]	28.7	[18]	94.5	[19]	87.5	[20]
Southwestern Electric Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		6.1	[21]	5.6	[22]	17.7	[23]	21.1	[24]
Southwestern Electric Power Co [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		584.3		517.1		1,625.2		1,317.7
Southwestern Electric Power Co [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(0.2)		0.2		5.1		0.5
Southwestern Electric Power Co [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		(0.2)	[25]	0.2	[26]	5.1	[27]	0.5	[28]
Southwestern Electric Power Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0.5		0.7		1.5		2.4
Revenues		0	[25]	0	[26]	0	[27]	0	[28]
Southwestern Electric Power Co [Member] | Short-term Contract with Customer [Member]
Revenue, Performance Obligation
Affiliated Companies - Contracts with Customers		19.9				19.9				$ 11.2
Southwestern Electric Power Co [Member] | 2021 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		10.1				10.1
Southwestern Electric Power Co [Member] | 2022-2023 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
Southwestern Electric Power Co [Member] | 2024-2025 [Member]
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
Southwestern Electric Power Co [Member] | After 2025
Revenue, Performance Obligation
Fixed Performance Obligations		0				0
Consolidation Eliminations [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Revenues		(376)		(374.2)		(1,112.2)		(1,007.6)
Revenue Textuals
Revenue from Related Parties		(376)		(374.2)		(1,112.2)		(1,007.6)
Consolidation Eliminations [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(0.1)		(0.1)		(0.5)		(0.5)
Consolidation Eliminations [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Consolidation Eliminations [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Consolidation Eliminations [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(0.1)		(0.1)		(0.5)		(0.5)
Consolidation Eliminations [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Consolidation Eliminations [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(321.1)		(302)		(951.7)		(823.6)
Consolidation Eliminations [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Consolidation Eliminations [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(317.4)	[1]	(276.9)	[2]	(901.5)	[3]	(741.7)	[4]
Consolidation Eliminations [Member] | Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(0.6)	[5]	(0.3)	[6]	(1.7)	[7]	(1.2)	[8]
Consolidation Eliminations [Member] | Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(3.1)	[9]	(24.8)	[10]	(48.5)	[11]	(80.7)	[12]
Consolidation Eliminations [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(40.1)	[5]	(43.7)	[6]	(87.9)	[7]	(115.7)	[8]
Consolidation Eliminations [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		(361.3)		(345.8)		(1,040.1)		(939.8)
Consolidation Eliminations [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(14.7)		(28.4)		(72.1)		(67.8)
Consolidation Eliminations [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		(11.7)	[5]	6.6	[6]	(63.5)	[7]	3.5	[8]
Consolidation Eliminations [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenues		(3)	[5]	(35)	[6]	(8.6)	[7]	(71.3)	[8]
Consolidation Eliminations [Member] | AEP Transmission Co [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Revenues		0		0		0		0
Revenue Textuals
Revenue from Related Parties		0		0		0		0
Consolidation Eliminations [Member] | AEP Transmission Co [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0				0		0
North Central Wind Energy Facilities
Revenue Textuals
Payments to Acquire Property, Plant, and Equipment						(652.8)		0
Vertically Integrated Utilities [Member]
Disaggregation of Revenue
Revenues		2,759.3		2,434.8		7,557.2		6,753.5
Revenue Textuals
Revenue from Related Parties		42.5		34.7		111.3		98.1
Vertically Integrated Utilities [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,376.7		2,158.9		6,386.6		5,939.6
Vertically Integrated Utilities [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,144.3		1,053.3		3,016.2		2,789.1
Vertically Integrated Utilities [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		618.9		559.7		1,642		1,523.6
Vertically Integrated Utilities [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		566		504.5		1,602.5		1,508.7
Vertically Integrated Utilities [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		47.5		41.4		125.9		118.2
Vertically Integrated Utilities [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		333.6		242.8		1,024.4		695.8
Vertically Integrated Utilities [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		233.8		158.4		757.1		447.4
Vertically Integrated Utilities [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		99.8	[1]	84.4	[2]	267.3	[3]	248.4	[4]
Vertically Integrated Utilities [Member] | Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[5]	0	[6]	0	[7]	0	[8]
Vertically Integrated Utilities [Member] | Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[9]	0	[10]	0	[11]	0	[12]
Vertically Integrated Utilities [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		49.4	[5]	34.1	[6]	136.1	[7]	124.1	[8]
Vertically Integrated Utilities [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		2,759.7		2,435.8		7,547.1		6,759.5
Vertically Integrated Utilities [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		(0.4)		(1)		10.1		(6)
Vertically Integrated Utilities [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		0.5	[5]	(1)	[6]	10.7	[7]	(6)	[8]
Vertically Integrated Utilities [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenues		(0.9)	[5]	0	[6]	(0.6)	[7]	0	[8]
Transmission And Distribution Utilities [Member]
Disaggregation of Revenue
Revenues		1,200.3		1,165.3		3,391.8		3,306.7
Revenue Textuals
Revenue from Related Parties		5.3		41.2		24.9		98
Transmission And Distribution Utilities [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		984.2		957.9		2,761.5		2,725.5
Transmission And Distribution Utilities [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		598		594.8		1,641.2		1,610.6
Transmission And Distribution Utilities [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		279.9		259.2		804.1		792.4
Transmission And Distribution Utilities [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		95.2		93.9		283.8		290.4
Transmission And Distribution Utilities [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		11.1		10		32.4		32.1
Transmission And Distribution Utilities [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		150.6		119.1		420.7		341.6
Transmission And Distribution Utilities [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Transmission And Distribution Utilities [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		150.6	[1]	119.1	[2]	420.7	[3]	341.6	[4]
Transmission And Distribution Utilities [Member] | Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[5]	0	[6]	0	[7]	0	[8]
Transmission And Distribution Utilities [Member] | Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[9]	0	[10]	0	[11]	0	[12]
Transmission And Distribution Utilities [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		54.2	[5]	42.8	[6]	149.3	[7]	112.3	[8]
Transmission And Distribution Utilities [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1,189		1,119.8		3,331.5		3,179.4
Transmission And Distribution Utilities [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		11.3		45.5		60.3		127.3
Transmission And Distribution Utilities [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		6.4	[5]	9.3	[6]	46.1	[7]	49.2	[8]
Transmission And Distribution Utilities [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenues		4.9	[5]	36.2	[6]	14.2	[7]	78.1	[8]
AEP Transmission Holdco [Member]
Disaggregation of Revenue
Revenues		391.6		317.9		1,146.8		877.8
AEP Transmission Holdco [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
AEP Transmission Holdco [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
AEP Transmission Holdco [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
AEP Transmission Holdco [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
AEP Transmission Holdco [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
AEP Transmission Holdco [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		375.8		317.7		1,092.1		937.7
AEP Transmission Holdco [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
AEP Transmission Holdco [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		375.8	[1]	317.7	[2]	1,092.1	[3]	937.7	[4]
Revenue Textuals
Revenue from Related Parties		286		246		835		725
AEP Transmission Holdco [Member] | Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[5]	0	[6]	0	[7]	0	[8]
AEP Transmission Holdco [Member] | Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[9]	0	[10]	0	[11]	0	[12]
AEP Transmission Holdco [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		5.1	[5]	2.4	[6]	12.5	[7]	17.5	[8]
AEP Transmission Holdco [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		380.9		320.1		1,104.6		955.2
AEP Transmission Holdco [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		10.7		(2.2)		42.2		(77.4)
AEP Transmission Holdco [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		10.7	[5]	(2.2)	[6]	42.2	[7]	(77.4)	[8]
AEP Transmission Holdco [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenues		0	[5]	0	[6]	0	[7]	0	[8]
Generation And Marketing [Member]
Disaggregation of Revenue
Revenues		621.1		490		1,691.9		1,305.5
Revenue Textuals
Revenue from Related Parties		3.7		25.2		50.3		82.1
Generation And Marketing [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Generation And Marketing [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Generation And Marketing [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Generation And Marketing [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Generation And Marketing [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Generation And Marketing [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		469		493.8		1,511.7		1,290.6
Generation And Marketing [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		47.8		30.5		119.4		106.1
Revenue Textuals
Revenue from Related Parties		4		19		49		81
Generation And Marketing [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[1]	0	[2]	0	[3]	0	[4]
Generation And Marketing [Member] | Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		24.1	[5]	15.8	[6]	66.7	[7]	50.7	[8]
Generation And Marketing [Member] | Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		397.1	[9]	447.5	[10]	1,325.6	[11]	1,133.8	[12]
Generation And Marketing [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		1.4	[5]	0.7	[6]	4.9	[7]	1.7	[8]
Generation And Marketing [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		470.4		494.5		1,516.6		1,292.3
Generation And Marketing [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		150.7		(4.5)		175.3		13.2
Generation And Marketing [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		0	[5]	0	[6]	0	[7]	0	[8]
Generation And Marketing [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenues		150.7	[5],[29]	(4.5)	[6],[30]	175.3	[7],[31]	13.2	[8],[32]
Other Segments [Member]
Disaggregation of Revenue
Revenues	[33]	26.7		32.6		55.1		72
Revenue Textuals
Revenue from Related Parties	[33]	23.2		28.6		43.5		67.3
Other Segments [Member] | Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Other Segments [Member] | Residential [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Other Segments [Member] | Commercial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Other Segments [Member] | Industrial [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Other Segments [Member] | Other Retail [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Other Segments [Member] | Wholesale and Competitive [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0.1		0.9		0.6		(5.7)
Other Segments [Member] | Wholesale Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0		0		0		0
Other Segments [Member] | Wholesale Transmission [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[1]	0	[2]	0	[3]	0	[4]
Other Segments [Member] | Renewable Generation [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0	[5]	0	[6]	0	[7]	0	[8]
Other Segments [Member] | Retail, Trading and Marketing Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		0.1	[9]	0.9	[10]	0.6	[11]	(5.7)	[12]
Other Segments [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		23.5	[5]	33.9	[6]	46.1	[7]	84.4	[8]
Other Segments [Member] | Affiliated and Nonaffiliated [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers		23.6		34.8		46.7		78.7
Other Segments [Member] | Alternative and Other [Member]
Disaggregation of Revenue
Revenues		3.1		(2.2)		8.4		(6.7)
Other Segments [Member] | Alternative [Member]
Disaggregation of Revenue
Revenues		0	[5]	0	[6]	0	[7]	0	[8]
Other Segments [Member] | Other Revenues [Member]
Disaggregation of Revenue
Revenue from Contracts with Customers	[33]	3.5		4		11.6		4.7
Revenues		$ 3.1	[5]	$ (2.2)	[6]	$ 8.4	[7]	$ (6.7)	[8]
[1]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $286 million. The remaining affiliated amounts were immaterial.
[2]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $246 million. The remaining affiliated amounts were immaterial
[3]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $835 million. The remaining affiliated amounts were immaterial.
[4]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEP Transmission Holdco was $725 million. The remaining affiliated amounts were immaterial.
[5]	Amounts include affiliated and nonaffiliated revenues.
[6]	Amounts include affiliated and nonaffiliated revenues
[7]	Amounts include affiliated and nonaffiliated revenues.
[8]	Amounts include affiliated and nonaffiliated revenues.
[9]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $4 million. The remaining affiliated amounts were immaterial.
[10]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $19 million. The remaining affiliated amounts were immaterial.
[11]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $49 million. The remaining affiliated amounts were immaterial.
[12]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for Generation & Marketing was $81 million. The remaining affiliated amounts were immaterial.
[13]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $30 million primarily relating to the PPA with KGPCo.
[14]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $28 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial.
[15]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $90 million primarily relating to the PPA with KGPCo.
[16]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for APCo was $85 million primarily relating to the PPA with KGPCo. The remaining affiliated amounts were immaterial.
[17]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $281 million. The remaining affiliated amounts were immaterial.
[18]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $243 million. The remaining affiliated amounts were immaterial.
[19]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $823 million. The remaining affiliated amounts were immaterial.
[20]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for AEPTCo was $715 million. The remaining affiliated amounts were immaterial.
[21]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $17 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial.
[22]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $15 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial.
[23]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $46 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial.
[24]	Amounts include affiliated and nonaffiliated revenues. The affiliated revenue for I&M was $49 million primarily relating to barging, urea transloading and other transportation services. The remaining affiliated amounts were immaterial.
[25]	Amounts include affiliated and nonaffiliated revenues.
[26]	Amounts include affiliated and nonaffiliated revenues.
[27]	Amounts include affiliated and nonaffiliated revenues.
[28]	Amounts include affiliated and nonaffiliated revenues.
[29]	Generation & Marketing includes economic hedge activity.
[30]	Generation & Marketing includes economic hedge activity.
[31]	Generation & Marketing includes economic hedge activity
[32]	Generation & Marketing includes economic hedge activity.
[33]	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.

Subsequent Events (Details)

Subsequent Events (Details) $ in Millions	9 Months Ended
	Sep. 30, 2021USD ($)MW	Oct. 28, 2021USD ($)
Mitchell Power Plant
Generation MWs | MW	1,560
Accounts Receivable and Accrued Unbilled Revenues [Member]
Major Classes of Assets	$ 24.7
Fuel, Materials and Supplies [Member]
Major Classes of Assets	26.5
Property, Plant and Equipment
Major Classes of Assets	2,264.6
Other Regulatory Assets (Liabilities) [Member]
Major Classes of Assets	501.7
Other Classes of Assets that are not Major [Member]
Major Classes of Assets	43.8
Total Assets [Member]
Major Classes of Assets	2,861.3
Accounts Payable [Member]
Major Classes of Liabilities	51.2
Long-term Debt Due Within One Year [Member]
Major Classes of Liabilities	125
Customer Deposits [Member]
Major Classes of Liabilities	31.9
Deferred Income Taxes [Member]
Major Classes of Liabilities	448.3
Long-term Debt [Member]
Major Classes of Liabilities	978
Regulatory Liabilities and Deferred Investment Tax Credits [Member]
Major Classes of Liabilities	146.5
Other Classes of Liabilities that are not Major [Member]
Major Classes of Liabilities	93.2
Total Liabilities [Member]
Major Classes of Liabilities	1,874.1
AEP Transmission Co [Member] | Accounts Receivable and Accrued Unbilled Revenues [Member]
Major Classes of Assets	1.6
AEP Transmission Co [Member] | Fuel, Materials and Supplies [Member]
Major Classes of Assets	0
AEP Transmission Co [Member] | Property, Plant and Equipment
Major Classes of Assets	164.5
AEP Transmission Co [Member] | Other Regulatory Assets (Liabilities) [Member]
Major Classes of Assets	0
AEP Transmission Co [Member] | Other Classes of Assets that are not Major [Member]
Major Classes of Assets	0.3
AEP Transmission Co [Member] | Total Assets [Member]
Major Classes of Assets	166.4
AEP Transmission Co [Member] | Accounts Payable [Member]
Major Classes of Liabilities	1.5
AEP Transmission Co [Member] | Long-term Debt Due Within One Year [Member]
Major Classes of Liabilities	0
AEP Transmission Co [Member] | Customer Deposits [Member]
Major Classes of Liabilities	0
AEP Transmission Co [Member] | Deferred Income Taxes [Member]
Major Classes of Liabilities	14.9
AEP Transmission Co [Member] | Long-term Debt [Member]
Major Classes of Liabilities	0
AEP Transmission Co [Member] | Regulatory Liabilities and Deferred Investment Tax Credits [Member]
Major Classes of Liabilities	7.5
AEP Transmission Co [Member] | Other Classes of Liabilities that are not Major [Member]
Major Classes of Liabilities	4.2
AEP Transmission Co [Member] | Total Liabilities [Member]
Major Classes of Liabilities	$ 28.1
Kentucky Power Co [Member] | Mitchell Power Plant
Jointly Owned Utility Plant, Proportionate Ownership Share	50.00%
Wheeling Power Company | Mitchell Power Plant
Jointly Owned Utility Plant, Proportionate Ownership Share	50.00%
Subsequent Event [Member]
Cash expected for sale of asset		$ 1,450
Stock Purchase Agreement		$ 2,850