PPL (PPL) 10-K 18 Feb 22 2021 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2021	Jan. 31, 2022	Jun. 30, 2021
Document Entity Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2021
Document Transition Report	false
Entity File Number	1-11459
Entity Registrant Name	PPL Corporation
Entity Tax Identification Number	23-2758192
Entity Incorporation State Country Code	PA
Entity Address, Address Line One	Two North Ninth Street
Entity Address, City or Town	Allentown,
Entity Address, State or Province	PA
Entity Address, Postal Zip Code	18101-1179
City Area Code	(610)
Local Phone Number	774-5151
Title of 12(g) Security	Common Stock of PPL Electric Utilities Corporation
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		735,361,885
Entity Public Float			$ 21,524,716,380
Amendment Flag	false
Entity Central Index Key	0000922224
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Document Fiscal Period Focus	2021
Document Fiscal Period Focus	FY
Documents Incorporated by Reference	PPL Corporation has incorporated herein by reference certain sections of PPL Corporation's 2022 Notice of Annual Meeting and Proxy Statement, which will be filed with the Securities and Exchange Commission not later than 120 days after December 31, 2021 and which will provide the information required by Part III of this Report.
ICFR Auditor Attestation Flag	true
Auditor Name	Deloitte & Touche LLP
Auditor Location	Parsippany, New Jersey
Auditor Firm ID	34
2007 Series A Due 2067 [Member]
Document Entity Information [Line Items]
Title of 12(b) Security	2007 Series A due 2067
Trading Symbol	PPL/67
Security Exchange Name	NYSE
Common Stock [Member]
Document Entity Information [Line Items]
Title of 12(b) Security	Common Stock of PPL Corporation
Trading Symbol	PPL
Security Exchange Name	NYSE
PPL Electric Utilities Corp [Member]
Document Entity Information [Line Items]
Entity File Number	1-905
Entity Registrant Name	PPL Electric Utilities Corporation
Entity Tax Identification Number	23-0959590
Entity Incorporation State Country Code	PA
Entity Address, Address Line One	Two North Ninth Street
Entity Address, City or Town	Allentown,
Entity Address, State or Province	PA
Entity Address, Postal Zip Code	18101-1179
City Area Code	(610)
Local Phone Number	774-5151
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		66,368,056
Amendment Flag	false
Entity Central Index Key	0000317187
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	false
Auditor Name	Deloitte & Touche LLP
Auditor Location	Parsippany, New Jersey
Auditor Firm ID	34
Louisville Gas And Electric Co [Member]
Document Entity Information [Line Items]
Entity File Number	1-2893
Entity Registrant Name	Louisville Gas and Electric Company
Entity Tax Identification Number	61-0264150
Entity Incorporation State Country Code	KY
Entity Address, Address Line One	220 West Main Street
Entity Address, City or Town	Louisville,
Entity Address, State or Province	KY
Entity Address, Postal Zip Code	40202-1377
City Area Code	(502)
Local Phone Number	627-2000
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		21,294,223
Amendment Flag	false
Entity Central Index Key	0000060549
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	false
Auditor Name	Deloitte & Touche LLP
Auditor Location	Louisville, Kentucky
Auditor Firm ID	34
Kentucky Utilities Co [Member]
Document Entity Information [Line Items]
Entity File Number	1-3464
Entity Registrant Name	Kentucky Utilities Company
Entity Tax Identification Number	61-0247570
Entity Incorporation State Country Code	KY
Entity Address, Address Line One	One Quality Street
Entity Address, City or Town	Lexington,
Entity Address, State or Province	KY
Entity Address, Postal Zip Code	40507-1462
City Area Code	(502)
Local Phone Number	627-2000
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		37,817,878
Amendment Flag	false
Entity Central Index Key	0000055387
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Incorporation State Country Code	Virginia
ICFR Auditor Attestation Flag	false
Auditor Name	Deloitte & Touche LLP
Auditor Location	Louisville, Kentucky
Auditor Firm ID	34

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Thousands, $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating Revenues
Operating Revenues		$ 5,783	$ 5,474	$ 5,602
Operation
Fuel		710	632	709
Energy purchases		752	634	723
Other operation and maintenance		1,608	1,420	1,509
Depreciation		1,082	1,022	949
Taxes, other than income		207	180	186
Total Operating Expenses		4,359	3,888	4,076
Operating Income		1,424	1,586	1,526
Other Income (Expense) - net		15	2	14
Interest Expense		918	634	621
Income (Loss) from Continuing Operations Before Income Taxes		521	954	919
Income Taxes		503	314	183
Income (Loss) from Continuing Operations After Income Taxes		18	640	736
Income (Loss) from Discontinued Operations (net of income taxes)		(1,498)	829	1,010
Net income (Loss)		$ (1,480)	$ 1,469	$ 1,746
Income (Loss) from Continuing Operations, Per Basic Share		$ 0.03	$ 0.83	$ 1.01
Earnings per Share of Common Stock [Abstract]
Income (Loss) from Discontinued Operation ( net of income taxes)		(1.96)	1.08	1.38
Net Income (Loss) Available to PPL Common Shareowners		(1.93)	1.91	2.39
Income (Loss) from Continuing Operations, Per Diluted Share		0.03	0.83	1
Income (Loss) from Discontinued Operation (net of income taxes)		(1.96)	1.08	1.37
Net Income (Loss) Available to PPL Common Shareowners		$ (1.93)	$ 1.91	$ 2.37
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic		762,902	768,590	728,512
Diluted		764,819	769,384	736,754
PPL Electric Utilities Corp [Member]
Operating Revenues
Operating Revenues		$ 2,402	$ 2,331	$ 2,358
Operation
Energy purchases		566	491	549
Other operation and maintenance		557	513	566
Depreciation		424	403	386
Taxes, other than income		120	107	112
Total Operating Expenses		1,667	1,514	1,613
Operating Income		735	817	745
Other Income (Expense) - net		21	18	25
Interest Income from Affiliate		5	2	6
Interest Expense		162	173	170
Income (Loss) from Continuing Operations Before Income Taxes		599	664	606
Income Taxes		154	167	149
Net income (Loss)	[1]	445	497	457
Louisville Gas And Electric Co [Member]
Operating Revenues
Retail and wholesale		1,545	1,435	1,473
Electric revenue from affiliates		24	21	27
Operating Revenues		1,569	1,456	1,500
Operation
Fuel		265	246	289
Energy purchases		167	125	154
Energy purchases from affiliate		23	19	7
Other operation and maintenance		400	373	387
Depreciation		279	259	231
Taxes, other than income		46	40	39
Total Operating Expenses		1,180	1,062	1,107
Operating Income		389	394	393
Other Income (Expense) - net		(5)	(1)	(11)
Interest Expense		81	87	87
Income (Loss) from Continuing Operations Before Income Taxes		303	306	295
Income Taxes		54	62	63
Net income (Loss)	[2]	249	244	232
Kentucky Utilities Co [Member]
Operating Revenues
Retail and wholesale		1,803	1,671	1,733
Electric revenue from affiliates		23	19	7
Operating Revenues		1,826	1,690	1,740
Operation
Fuel		445	386	420
Energy purchases		19	18	20
Energy purchases from affiliate		24	21	27
Other operation and maintenance		463	429	438
Depreciation		366	346	315
Taxes, other than income		41	37	35
Total Operating Expenses		1,358	1,237	1,255
Operating Income		468	453	485
Other Income (Expense) - net		4	3	(4)
Interest Expense		109	113	109
Income (Loss) from Continuing Operations Before Income Taxes		363	343	372
Income Taxes		67	63	79
Net income (Loss)	[3]	$ 296	$ 280	$ 293
[1]	Net income equals comprehensive income.
[2]	Net income equals comprehensive income.
[3]	Net income equals comprehensive income.

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Net income	$ (1,480)	$ 1,469	$ 1,746
Amounts arising during the period - gains (losses), net of tax (expense) benefit:
Foreign currency translation adjustments, net of tax	372	267	108
Qualifying derivatives, net of tax	(39)	(19)	(11)
Defined benefit plans:
Prior service costs, net of tax	0	(1)	(1)
Net actuarial gain (loss), net of tax	(1)	(341)	(592)
Reclassifications from AOCI - (gains) losses, net of tax expense (benefit):
Qualifying derivatives, net of tax	25	24	13
Defined benefit plans:
Prior service costs, net of tax	2	3	2
Net actuarial (gain) loss, net of tax	126	205	87
Foreign currency translation adjustments, net of tax (UK Sale Reclassification)	786	0	0
Qualifying derivatives, net of tax (UK Sale Reclassification)	15	0	0
Total other comprehensive income (loss)	4,063	138	(394)
Comprehensive income	2,583	1,607	1,352
Net actuarial (gain) loss, net of tax (UK Sale Reclassification)	2,769	0	0
Prior service costs, net of tax (UK Sale Reclassification)	$ 8	$ 0	$ 0

CONSOLIDATED STATEMENTS OF CO_2

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Tax effect of foreign currency translation adjustments arising during the period	$ (123)	$ 0	$ 0
Tax effect of qualifying derivatives arising during the period	11	5	2
Tax effect of defined benefit plans - prior service costs arising during period	0	0	0
Tax effect of defined benefit plans - net actuarial gain (loss) arising during period	1	74	119
Tax effect of qualifying derivatives reclassified from AOCI	(5)	(8)	(5)
Tax effect of defined benefit plans - prior service costs reclassified from AOCI	(1)	(1)	(1)
Tax effect of defined benefit plans - net actuarial (gain) loss reclassified from AOCI	(33)	(51)	(22)
Other Comprehensive Income (Loss), Foreign Currency Translation Gain (Loss), Reclassification Adjustment from AOCI, Realized upon Sale or Liquidation, Tax	140	0	0
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification Adjustment from AOCI, Realized upon Sale or Liquidation, Tax	0	0	0
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, Realized upon Sale or Liquidation, Tax	(2)	0	0
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, Realized upon Sale or Liquidation, Tax	$ (798)	$ 0	$ 0

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Cash Flows from Operating Activities
Net income		$ (1,480)	$ 1,469	$ 1,746
Loss (income) from discontinued operations (net of income taxes)		1,498	(829)	(1,010)
Income (Loss) from Continuing Operations After Income Taxes		18	640	736
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		1,082	1,022	949
Amortization		39	58	58
Deferred income taxes and investment tax credits		87	169	169
Impairment of solar panels		37	0	0
Loss on Extinguishment of Debt		395	0	0
Other		20	67	69
Change in current assets and current liabilities
Accounts receivable		(14)	(70)	(3)
Accounts payable		24	(1)	(66)
Taxes payable		27	131	9
Regulatory assets and liabilities, net		52	(63)	(88)
Other		(67)	118	(29)
Other operating activities
Defined benefit plans - funding		(53)	(119)	(73)
Other assets		(111)	(59)	(100)
Other liabilities		8	(21)	(24)
Net cash provided by operating activities - continuing operations		1,544	1,872	1,607
Net cash provided by operating activities - discontinued operations		726	874	820
Net cash provided by operating activities		2,270	2,746	2,427
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(1,973)	(2,270)	(2,243)
Proceeds from sale of discontinued operations, net of cash divested		10,560	0	0
Other investing activities		(23)	4	10
Net cash provided by (used in) investing activities - continuing operations		8,564	(2,266)	(2,233)
Net cash provided by (used in) investing activities - discontinued operations		(607)	(992)	(847)
Net cash provided by (used in) investing activities		7,957	(3,258)	(3,080)
Cash Flows from Financing Activities
Issuance of long-term debt		650	1,848	1,099
Retirement of long-term debt		(4,606)	(975)	(300)
Issuance of common stock		9	34	1,167
Proceeds from project financing		19	173	0
Payment of common stock dividends		(1,279)	(1,275)	(1,192)
Purchase of treasury stock		(1,003)	0	0
Issuance of term loan		0	300	0
Issuance of commercial paper		0	73	0
Retirement of term loan		(300)	0	0
Retirement of commercial paper		(73)	0	0
Net increase (decrease) in short-term debt		(726)	(43)	(341)
Other financing activities		(35)	(36)	(25)
Net cash provided by (used in) financing activities - continuing operations		(7,344)	99	408
Net cash provided by (used in) financing activities - discontinued operations		(411)	209	171
Contributions from discontinued operations		365	78	257
Net cash provided by (used in) financing activities		(7,390)	386	836
Effect of Exchange Rates on Cash, Cash Equivalents and Restricted Cash included in Discontinued Operations		8	17	10
Net (Increase) Decrease in Cash, Cash Equivalents and Restricted Cash included in Discontinued Operations		284	(108)	(154)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		3,129	(217)	39
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		443	660	621
Cash, Cash Equivalents and Restricted Cash at End of Period		3,572	443	660
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		191	586	552
Income taxes - net		284	4	(12)
Accrued expenditures for property, plant and equipment at December 31,		245	257	292
PPL Electric Utilities Corp [Member]
Cash Flows from Operating Activities
Net income	[1]	445	497	457
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		424	403	386
Amortization		19	26	24
Defined benefit plans - expense (income)		(10)	(1)	0
Deferred income taxes and investment tax credits		79	83	90
Other		(19)	(5)	(19)
Change in current assets and current liabilities
Accounts receivable		(9)	(47)	33
Accounts payable		(3)	21	5
Unbilled Revenues		(8)	13	(14)
Fuel, materials and supplies		(5)	(18)	(8)
Prepayments		(4)	(3)	(1)
Taxes payable		14	4	1
Regulatory assets and liabilities, net		96	(40)	(43)
Other		(1)	(10)	(3)
Other operating activities
Defined benefit plans - funding		(21)	(21)	(21)
Other assets		(12)	(28)	15
Other liabilities		(16)	10	11
Net cash provided by operating activities		969	884	913
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(898)	(1,145)	(1,114)
Expenditures for intangible assets		(6)	(9)	(7)
Net decrease in notes receivable from affiliates		(499)	0	0
Other investing activities		3	3	4
Net cash provided by (used in) investing activities		(1,400)	(1,151)	(1,117)
Cash Flows from Financing Activities
Issuance of long-term debt		650	250	393
Retirement of long-term debt		(400)	0	(100)
Contributions from parent		1,075	940	400
Payment of common stock dividends to parent		(334)	(400)	(486)
Return of Capital to Parent		(574)	(745)	0
Other financing activities		(5)	(2)	(8)
Net cash provided by (used in) financing activities		412	43	199
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(19)	(224)	(5)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		40	264	269
Cash, Cash Equivalents and Restricted Cash at End of Period		21	40	264
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		156	158	154
Income taxes - net		64	67	32
Accrued expenditures for property, plant and equipment at December 31,		118	156	180
Louisville Gas And Electric Co [Member]
Cash Flows from Operating Activities
Net income	[2]	249	244	232
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		279	259	231
Amortization		2	9	15
Defined benefit plans - expense (income)		1	3	3
Deferred income taxes and investment tax credits		8	3	56
Change in current assets and current liabilities
Accounts receivable		(11)	(3)	(9)
Accounts receivable from affiliates		(13)	4	6
Accounts payable		32	(18)	(10)
Unbilled Revenues		(1)	(3)	1
Accounts payable to affiliates		(4)	(5)	5
Fuel, materials and supplies		(17)	4	5
Taxes payable		2	(1)	7
Regulatory assets and liabilities, net		(23)	0	(19)
Other		(18)	(3)	(5)
Other operating activities
Defined benefit plans - funding		(3)	(11)	(6)
Other assets		2	(2)	(1)
Expenditures for asset retirement obligations		(27)	(20)	(30)
Other liabilities		0	23	11
Net cash provided by operating activities		458	483	492
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(466)	(456)	(482)
Net cash provided by (used in) investing activities		(466)	(456)	(482)
Increase (Decrease) in Due to Related Parties		324	0	0
Cash Flows from Financing Activities
Issuance of long-term debt		0	0	399
Retirement of long-term debt		0	0	(200)
Acquisition of outstanding bonds		0	0	(40)
Remarketing of reacquired bonds		0	0	40
Issuance of commercial paper		0	41	0
Retirement of commercial paper		(41)	0	0
Contributions from parent		74	103	25
Payment of common stock dividends to parent		(192)	(161)	(182)
Other financing activities		(3)	(1)	(6)
Net cash provided by (used in) financing activities		10	(35)	(5)
Net Increase (Decrease) in Cash and Cash Equivalents		2	(8)	5
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		77	82	77
Income taxes - net		52	63	2
Accrued expenditures for property, plant and equipment at December 31,		60	60	59
Net increase (decrease) in short-term debt		(152)	(17)	(41)
Kentucky Utilities Co [Member]
Cash Flows from Operating Activities
Net income	[3]	296	280	293
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		366	346	315
Amortization		12	8	10
Defined benefit plans - expense (income)		(3)	0	(1)
Deferred income taxes and investment tax credits		1	20	39
Other		(3)	(1)	(3)
Change in current assets and current liabilities
Accounts receivable		6	(13)	(3)
Accounts receivable from affiliates		1	(1)	0
Accounts payable		(12)	9	(15)
Unbilled Revenues		6	(9)	4
Accounts payable to affiliates		15	(16)	(2)
Fuel, materials and supplies		1	6	(6)
Taxes payable		(10)	2	2
Regulatory assets and liabilities, net		(22)	(26)	(26)
Other		(18)	(5)	(6)
Other operating activities
Defined benefit plans - funding		(1)	(3)	(3)
Other assets		9	(2)	(2)
Expenditures for asset retirement obligations		(36)	(64)	(59)
Other liabilities		0	12	16
Net cash provided by operating activities		608	543	553
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(560)	(510)	(610)
Other investing activities		4	3	0
Net cash provided by (used in) investing activities		(556)	(507)	(610)
Increase (Decrease) in Due to Related Parties		294	0	0
Cash Flows from Financing Activities
Issuance of long-term debt		0	498	306
Retirement of long-term debt		0	(500)	0
Issuance of commercial paper		0	32	0
Retirement of commercial paper		(32)	0	0
Contributions from parent		100	128	68
Payment of common stock dividends to parent		(250)	(200)	(229)
Other financing activities		(2)	(5)	(5)
Net cash provided by (used in) financing activities		(61)	(26)	55
Net Increase (Decrease) in Cash and Cash Equivalents		(9)	10	(2)
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		105	109	101
Income taxes - net		72	44	39
Accrued expenditures for property, plant and equipment at December 31,		67	40	54
Net increase (decrease) in short-term debt		$ (171)	$ 21	$ (85)
[1]	Net income equals comprehensive income.
[2]	Net income equals comprehensive income.
[3]	Net income equals comprehensive income.

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions		Dec. 31, 2021	Dec. 31, 2020
Current Assets
Cash and cash equivalents		$ 3,571	$ 442
Accounts receivable (less reserve:)
Customer		583	603
Other		58	86
Unbilled revenues		307	301
Fuel, materials and supplies		322	302
Prepayments		60	53
Regulatory assets		64	99
Other current assets		106	130
Total Current Assets		5,007	20,900
Property, Plant and Equipment
Regulated utility plant		30,477	29,040
Less: accumulated depreciation - regulated utility plant		6,488	6,008
Regulated utility plant, net		23,989	23,032
Non-regulated property, plant and equipment		266	237
Less: accumulated depreciation - non-regulated property, plant and equipment		41	37
Non-regulated property, plant and equipment, net		225	200
Construction work in progress		1,256	1,268
Property, Plant and Equipment, net		25,470	24,500
Other Noncurrent Assets
Regulatory assets		1,236	1,262
Goodwill		716	716
Other intangibles		343	351
Other noncurrent assets		451	387
Total Other Noncurrent Assets		2,746	2,716
Total Assets		33,223	48,116
Current Liabilities
Short-term debt		69	1,168
Long-term debt due within one year		474	1,074
Accounts payable		679	745
Taxes		96	69
Interest		81	113
Dividends		305	319
Regulatory liabilities		182	79
Other current liabilities		437	465
Total Current Liabilities		2,323	15,055
Long-term Debt [Abstract]
Long-term Debt		10,666	13,615
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		3,151	2,536
Investment tax credits		119	122
Accrued pension obligations		183	189
Asset retirement obligations		157	132
Regulatory liabilities		2,422	2,530
Other deferred credits and noncurrent liabilities		479	564
Total Deferred Credits and Other Noncurrent Liabilities		6,511	6,073
Commitments and Contingent Liabilities
Equity
Common stock	[1]	8	8
Additional paid-in capital		12,303	12,270
Earnings reinvested		2,572	5,315
Accumulated other comprehensive loss		(157)	(4,220)
Total Equity		13,723	13,373
Total Liabilities and Equity		$ 33,223	$ 48,116
Common stock par value		$ 0.01	$ 0.01
Total current assets held for sale		$ 0	$ 18,983
Total current liabilities held for sale		0	11,023
Treasury Stock		(1,003)	0
PPL Electric Utilities Corp [Member]
Current Assets
Cash and cash equivalents		21	40
Accounts receivable (less reserve:)
Customer		305	311
Other		22	17
Accounts receivable from affiliates		11	10
Notes Receivable, Related Parties, Current		499	0
Unbilled revenues		129	121
Fuel, materials and supplies		61	59
Prepayments		13	9
Regulatory assets		22	40
Other current assets		21	13
Total Current Assets		1,104	620
Property, Plant and Equipment
Regulated utility plant		14,082	13,514
Less: accumulated depreciation - regulated utility plant		3,386	3,297
Regulated utility plant, net		10,696	10,217
Construction work in progress		581	592
Property, Plant and Equipment, net		11,277	10,809
Other Noncurrent Assets
Regulatory assets		488	541
Other intangibles		270	268
Assets for Plan Benefits, Defined Benefit Plan		50	12
Other noncurrent assets		113	74
Total Other Noncurrent Assets		921	895
Total Assets		13,302	12,324
Current Liabilities
Long-term debt due within one year		474	400
Accounts payable		367	428
Accounts payable to affiliates		56	39
Taxes		31	17
Interest		35	39
Regulatory liabilities		153	68
Other current liabilities		108	105
Total Current Liabilities		1,224	1,096
Long-term Debt [Abstract]
Long-term Debt		4,010	3,836
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,668	1,559
Accrued pension obligations		8	8
Regulatory liabilities		559	578
Other deferred credits and noncurrent liabilities		97	123
Total Deferred Credits and Other Noncurrent Liabilities		2,332	2,268
Commitments and Contingent Liabilities
Equity
Common stock	[2]	364	364
Additional paid-in capital		4,254	3,753
Earnings reinvested		1,118	1,007
Total Equity		5,736	5,124
Total Liabilities and Equity		$ 13,302	$ 12,324
Common stock no par value		$ 0	$ 0
Louisville Gas And Electric Co [Member]
Current Assets
Cash and cash equivalents		$ 9	$ 7
Accounts receivable (less reserve:)
Customer		130	127
Other		25	35
Accounts receivable from affiliates		31	16
Unbilled revenues		80	79
Fuel, materials and supplies		137	119
Prepayments		14	14
Regulatory assets		33	23
Other current assets		2	1
Total Current Assets		461	421
Property, Plant and Equipment
Regulated utility plant		7,192	6,735
Less: accumulated depreciation - regulated utility plant		1,172	1,020
Regulated utility plant, net		6,020	5,715
Construction work in progress		242	320
Property, Plant and Equipment, net		6,262	6,035
Other Noncurrent Assets
Regulatory assets		337	351
Goodwill		389	389
Other intangibles		30	35
Other noncurrent assets		113	114
Total Other Noncurrent Assets		869	889
Total Assets		7,592	7,345
Current Liabilities
Short-term debt		69	262
Long-term debt due within one year		0	292
Notes payable with affiliates		324	0
Accounts payable		163	153
Accounts payable to affiliates		31	31
Taxes		34	32
Interest		15	15
Asset Retirement Obligations		10	10
Price risk management liabilities		1	2
Customer deposits		32	32
Regulatory liabilities		21	0
Other current liabilities		37	50
Total Current Liabilities		737	879
Long-term Debt [Abstract]
Long-term Debt		2,006	1,715
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		751	716
Investment tax credits		32	33
Price risk management liabilities		17	21
Asset retirement obligations		74	57
Regulatory liabilities		818	882
Other deferred credits and noncurrent liabilities		78	94
Total Deferred Credits and Other Noncurrent Liabilities		1,770	1,803
Commitments and Contingent Liabilities
Equity
Common stock	[3]	424	424
Additional paid-in capital		1,997	1,923
Earnings reinvested		658	601
Total Equity		3,079	2,948
Total Liabilities and Equity		$ 7,592	$ 7,345
Common stock no par value		$ 0	$ 0
Kentucky Utilities Co [Member]
Current Assets
Cash and cash equivalents		$ 13	$ 22
Accounts receivable (less reserve:)
Customer		144	156
Other		12	30
Accounts receivable from affiliates		0	1
Unbilled revenues		91	97
Fuel, materials and supplies		124	123
Prepayments		15	15
Regulatory assets		9	36
Other current assets		2	1
Total Current Assets		410	481
Property, Plant and Equipment
Regulated utility plant		9,219	8,808
Less: accumulated depreciation - regulated utility plant		1,929	1,690
Regulated utility plant, net		7,290	7,118
Construction work in progress		378	321
Property, Plant and Equipment, net		7,668	7,439
Other Noncurrent Assets
Regulatory assets		411	370
Goodwill		607	607
Other intangibles		23	26
Other noncurrent assets		153	149
Total Other Noncurrent Assets		1,194	1,152
Total Assets		9,272	9,072
Current Liabilities
Short-term debt		0	203
Long-term debt due within one year		0	132
Notes payable with affiliates		294	0
Accounts payable		108	121
Accounts payable to affiliates		64	43
Taxes		19	29
Interest		18	19
Asset Retirement Obligations		22	40
Customer deposits		32	32
Regulatory liabilities		8	11
Other current liabilities		47	59
Total Current Liabilities		612	689
Long-term Debt [Abstract]
Long-term Debt		2,618	2,486
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		865	835
Investment tax credits		87	88
Asset retirement obligations		83	75
Regulatory liabilities		1,045	1,070
Other deferred credits and noncurrent liabilities		34	47
Total Deferred Credits and Other Noncurrent Liabilities		2,114	2,115
Commitments and Contingent Liabilities
Equity
Common stock	[4]	308	308
Additional paid-in capital		2,957	2,857
Earnings reinvested		663	617
Total Equity		3,928	3,782
Total Liabilities and Equity		$ 9,272	$ 9,072
Common stock no par value		$ 0	$ 0
[1]	1,560,000 shares authorized; 769,890 shares issued and 735,112 shares outstanding at December 31, 2021. 1,560,000 shares authorized; 768,907 shares issued and outstanding at December 31, 2020.
[2]	170,000 shares authorized; 66,368 shares issued and outstanding at December 31, 2021 and December 31, 2020
[3]	75,000 shares authorized; 21,294 shares issued and outstanding at December 31, 2021 and December 31, 2020.
[4]	80,000 shares authorized; 37,818 shares issued and outstanding at December 31, 2021 and December 31, 2020.

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) shares in Thousands, $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 65	$ 71
Unbilled Revenues, Reserve	2	4
Other Noncurrent Assets [Abstract]
Accounts Receivable, Allowance for Credit Loss, Noncurrent	$ 2	$ 0
Equity
Common stock par value	$ 0.01	$ 0.01
Common stock shares authorized	1,560,000	1,560,000
Common stock shares issued	769,890	768,907
Common stock shares outstanding	735,112	768,907
PPL Electric Utilities Corp [Member]
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 31	$ 41
Unbilled Revenues, Reserve	2	2
Other Noncurrent Assets [Abstract]
Accounts Receivable, Allowance for Credit Loss, Noncurrent	$ 2	$ 0
Equity
Common stock no par value	$ 0	$ 0
Common stock shares authorized	170,000	170,000
Common stock shares issued	66,368	66,368
Common stock shares outstanding	66,368	66,368
Louisville Gas And Electric Co [Member]
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 3	$ 2
Unbilled Revenues, Reserve	$ 0	$ 1
Equity
Common stock no par value	$ 0	$ 0
Common stock shares authorized	75,000	75,000
Common stock shares issued	21,294	21,294
Common stock shares outstanding	21,294	21,294
Kentucky Utilities Co [Member]
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 3	$ 1
Unbilled Revenues, Reserve	$ 0	$ 1
Equity
Common stock no par value	$ 0	$ 0
Common stock shares authorized	80,000	80,000
Common stock shares issued	37,818	37,818
Common stock shares outstanding	37,818	37,818

CONSOLIDATED STATEMENTS OF EQUI

CONSOLIDATED STATEMENTS OF EQUITY - USD ($) shares in Thousands, $ in Millions		Total	Cumulative Effect, Period of Adoption, Adjustment	Common Stock [Member]		Additional Paid-in Capital	Earnings Reinvested	Earnings ReinvestedCumulative Effect, Period of Adoption, Adjustment	Accumulated Other Comprehensive Loss	Treasury Stock	PPL Electric Utilities Corp [Member]		PPL Electric Utilities Corp [Member]Common Stock [Member]		PPL Electric Utilities Corp [Member]Additional Paid-in Capital	PPL Electric Utilities Corp [Member]Earnings Reinvested	Louisville Gas And Electric Co [Member]		Louisville Gas And Electric Co [Member]Common Stock [Member]		Louisville Gas And Electric Co [Member]Additional Paid-in Capital	Louisville Gas And Electric Co [Member]Earnings Reinvested	Kentucky Utilities Co [Member]		Kentucky Utilities Co [Member]Common Stock [Member]		Kentucky Utilities Co [Member]Additional Paid-in Capital	Kentucky Utilities Co [Member]Earnings Reinvested	Kentucky Utilities Co [Member]Accumulated Other Comprehensive Loss
Dividends Declared Per Share of Common Stock		$ 1.65
Balance at beginning of period - shares at Dec. 31, 2018				720,323	[1]								66,368	[2]					21,294	[3]					37,818	[4]
Balance at beginning of period at Dec. 31, 2018		$ 11,657		$ 7		$ 11,021	$ 4,593		$ (3,964)	$ 0	$ 4,461		$ 364		$ 3,158	$ 939	$ 2,687		$ 424		$ 1,795	$ 468	$ 3,442		$ 308		$ 2,661	$ 473	$ 0
Common stock shares issued	[1]			46,910
Common stock issued		1,185		$ 1		1,184
Stock-based compensation		9				9
Net income		1,746					1,746				457	[5]				457	232	[6]				232	293	[7]				293
Capital contributions from parent											400				400		25				25		68				68
Dividends and dividend equivalents		(1,212)					(1,212)
Cash dividends declared on common stock											(486)					(486)	(182)					(182)	(229)					(229)
Other comprehensive income (loss)		(394)							(394)
Balance at end of period - shares at Dec. 31, 2019				767,233	[1]								66,368	[2]					21,294	[3]					37,818	[4]
Balance at end of period at Dec. 31, 2019		$ 12,991		$ 8		12,214	5,127		(4,358)	0	4,832		$ 364		3,558	910	2,762		$ 424		1,820	518	3,574		$ 308		2,729	537	0
Dividends Declared Per Share of Common Stock		$ 1.66
Common stock shares issued	[1]			1,674
Common stock issued		$ 51				51
Stock-based compensation		5				5
Net income		1,469					1,469				497	[5]				497	244	[6]				244	280	[7]				280
Capital contributions from parent											940				940		103				103		128				128
Return of Capital to Parent											(745)				(745)
Dividends and dividend equivalents		(1,279)					(1,279)
Cash dividends declared on common stock											$ (400)					(400)	$ (161)					(161)	$ (200)					(200)
Other comprehensive income (loss)		$ 138							138
Balance at end of period - shares at Dec. 31, 2020		768,907		768,907	[1]						66,368		66,368	[2]			21,294		21,294	[3]			37,818		37,818	[4]
Balance at end of period at Dec. 31, 2020		$ 13,373		$ 8		12,270	5,315		(4,220)	0	$ 5,124		$ 364		3,753	1,007	$ 2,948		$ 424		1,923	601	$ 3,782		$ 308		2,857	617	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest			$ (2)					$ (2)
Dividends Declared Per Share of Common Stock		$ 1.66
Common stock shares issued	[1]			983
Common stock issued		$ 29				29
Treasury stock				(34,778)
Stock-based compensation		4				4
Net income		(1,480)					(1,480)				445	[5]				445	249	[6]				249	296	[7]				296
Capital contributions from parent											1,075				1,075		74				74		100				100
Return of Capital to Parent											(574)				(574)
Dividends and dividend equivalents		(1,263)					(1,263)
Cash dividends declared on common stock											$ (334)					(334)	$ (192)					(192)	$ (250)					(250)
Other comprehensive income (loss)		$ 4,063							4,063
Balance at end of period - shares at Dec. 31, 2021		735,112		735,112	[1]						66,368		66,368	[2]			21,294		21,294	[3]			37,818		37,818	[4]
Balance at end of period at Dec. 31, 2021		$ 13,723		$ 8		$ 12,303	$ 2,572		$ (157)	(1,003)	$ 5,736		$ 364		$ 4,254	$ 1,118	$ 3,079		$ 424		$ 1,997	$ 658	$ 3,928		$ 308		$ 2,957	$ 663	$ 0
Treasury stock acquired		$ (1,003)								$ 1,003
[1]	Shares in thousands. Each share entitles the holder to one vote on any question presented at any shareowners' meeting.
[2]	Shares in thousands. All common shares of PPL Electric stock are owned by PPL.
[3]	Shares in thousands. All common shares of LG&E stock are owned by LKE.
[4]	Shares in thousands. All common shares of KU stock are owned by LKE.
[5]	Net income equals comprehensive income.
[6]	Net income equals comprehensive income.
[7]	Net income equals comprehensive income.

CONSOLIDATED STATEMENTS OF EQ_2

CONSOLIDATED STATEMENTS OF EQUITY (Parenthetical)	12 Months Ended
	Dec. 31, 2021vote$ / shares	Dec. 31, 2020vote$ / shares	Dec. 31, 2019vote$ / shares
Vote per share of PPL's common stock | vote	1	1	1
Current quarterly common stock dividend (in dollars per share) | $ / shares	$ 1.66	$ 1.66	$ 1.65

Quarterly Financial Data (Unaud

Quarterly Financial Data (Unaudited) (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Nov. 30, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Quarterly Financial Information Disclosure [Line Items]
Operating Revenues		$ 5,783	$ 5,474	$ 5,602
Operating income		$ 1,424	$ 1,586	$ 1,526
Net income (loss) available to PPL common shareowners: [Abstract]
Net Income (Loss) Available to PPL Common Shareowners		$ (1.93)	$ 1.91	$ 2.39
Net Income (Loss) Available to PPL Common Shareowners		(1.93)	1.91	2.37
Dividends declared per share of common stock (in dollars per share)	$ 0.415	$ 1.66	$ 1.66	$ 1.65
PPL Electric Utilities Corp [Member]
Quarterly Financial Information Disclosure [Line Items]
Operating Revenues		$ 2,402	$ 2,331	$ 2,358
Operating income		$ 735	$ 817	$ 745

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2021
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	(All Registrants) General Capitalized terms and abbreviations appearing in the combined notes to financial statements are defined in the glossary. Dollars are in millions, except per share data, unless otherwise noted. The specific Registrant to which disclosures are applicable is identified in parenthetical headings in italics above the applicable disclosure or within the applicable disclosure for each Registrants' related activities and disclosures. Within combined disclosures, amounts are disclosed for any Registrant when significant. Business and Consolidation (PPL) PPL is a utility holding company that, through its regulated subsidiaries, is primarily engaged in: 1) the generation, transmission, distribution and sale of electricity and the distribution and sale of natural gas, primarily in Kentucky; and 2) the transmission, distribution and sale of electricity in Pennsylvania. Headquartered in Allentown, PA, PPL's principal subsidiaries are LKE (including its principal subsidiaries, LG&E and KU) and PPL Electric. PPL's corporate level financing subsidiary is PPL Capital Funding. On March 17, 2021, PPL WPD Limited entered into a share purchase agreement to sell PPL's U.K. utility business, which substantially represented PPL's U.K. Regulated segment, to a subsidiary of National Grid plc. The sale was completed on June 14, 2021. The results of operations of the U.K. utility business are classified as Discontinued Operations on PPL's Statements of Income. The assets and liabilities of the U.K. utility business as of December 31, 2020 are classified as assets and liabilities held for sale on PPL's Balance Sheets. PPL has elected to separately report the cash flows of continuing and discontinued operations on the Statements of Cash Flows. Unless otherwise noted, the notes to these financial statements exclude amounts related to discontinued operations and assets and liabilities held for sale for all periods presented. See Note 9 for additional information. On July 1, 2021, LKE redeemed, at par, its $250 million 4.375% Senior Notes due 2021 and on July 9, 2021, LKE filed a Form 15 with the SEC to suspend its duty to file reports under sections 13 and 15(d) of the Securities Exchange Act of 1934. As a result, beginning with the June 30, 2021 Form 10-Q, LKE was no longer reported as a Registrant. (PPL and PPL Electric) PPL Electric is a cost-based rate-regulated utility subsidiary of PPL. PPL Electric's principal business is the transmission and distribution of electricity to serve retail customers in its franchised territory in eastern and central Pennsylvania and the regulated supply of electricity to retail customers in that territory as a PLR. (PPL, LG&E and KU) LG&E and KU are engaged in the generation, transmission, distribution and sale of electricity. LG&E also engages in the distribution and sale of natural gas. LG&E and KU maintain their separate identities and serve customers in Kentucky under their respective names. KU also serves customers in Virginia under the Old Dominion Power name. (All Registrants) The financial statements of the Registrants include each company's own accounts as well as the accounts of all entities in which the company has a controlling financial interest. Entities for which a controlling financial interest is not demonstrated through voting interests are evaluated based on accounting guidance for Variable Interest Entities (VIEs). The Registrants consolidate a VIE when they are determined to have a controlling interest in the VIE and, as a result, are the primary beneficiary of the entity. Amounts consolidated under the VIE guidance are not material to the Registrants. All significant intercompany transactions have been eliminated. The financial statements of PPL, LG&E and KU include their share of any undivided interests in jointly owned facilities, as well as their share of the related operating costs of those facilities. See Note 13 for additional information. Regulation (All Registrants) PPL Electric, LG&E and KU are cost-based rate-regulated utilities for which rates are set by regulators to enable PPL Electric, LG&E and KU to recover the costs of providing electric or gas service, as applicable, and to provide a reasonable return to shareholders. Base rates are generally established based on a future test period. As a result, the financial statements are subject to the accounting for certain types of regulation as prescribed by GAAP and reflect the effects of regulatory actions. Regulatory assets are recognized for the effect of transactions or events where future recovery of underlying costs is probable in regulated customer rates. The effect of such accounting is to defer certain or qualifying costs that would otherwise currently be charged to expense. Regulatory liabilities are recognized for amounts expected to be returned through future regulated customer rates. In certain cases, regulatory liabilities are recorded based on an understanding or agreement with the regulator that rates have been set to recover expected future costs, and the regulated entity is accountable for any amounts charged pursuant to such rates and not yet expended for the intended purpose. The accounting for regulatory assets and regulatory liabilities is based on specific ratemaking decisions or precedent for each transaction or event as prescribed by the FERC or the applicable state regulatory commissions. See Note 7 for additional details regarding regulatory matters. Accounting Records The system of accounts for domestic regulated entities is maintained in accordance with the Uniform System of Accounts prescribed by the FERC and adopted by the applicable state regulatory commissions. Use of Estimates The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Loss Accruals Potential losses are accrued when (1) information is available that indicates it is "probable" that a loss has been incurred, given the likelihood of uncertain future events and (2) the amount of loss can be reasonably estimated. Accounting guidance defines "probable" as cases in which "the future event or events are likely to occur." The Registrants continuously assess potential loss contingencies for environmental remediation, litigation claims, regulatory penalties and other events. Loss accruals for environmental remediation are discounted when appropriate. The accrual of contingencies that might result in gains is not recorded, unless realization is assured. Earnings Per Share (PPL) EPS is computed using the two-class method, which is an earnings allocation method for computing EPS that treats a participating security as having rights to earnings that would otherwise have been available to common shareowners. Share-based payment awards that provide recipients a non-forfeitable right to dividends or dividend equivalents are considered participating securities. Price Risk Management (All Registrants) Interest rate contracts are used to hedge exposure to changes in the fair value of debt instruments and to hedge exposure to variability in expected cash flows associated with existing floating-rate debt instruments or forecasted fixed-rate issuances of debt. Foreign currency exchange contracts are used to hedge foreign currency exposures. Similar derivatives may receive different accounting treatment, depending on management's intended use and documentation. Certain contracts may not meet the definition of a derivative because they lack a notional amount or a net settlement provision. In cases where there is no net settlement provision, markets are periodically assessed to determine whether market mechanisms have evolved to facilitate net settlement. Certain derivative contracts may be excluded from the requirements of derivative accounting treatment because the NPNS has been elected. These contracts are accounted for using accrual accounting. Contracts that have been classified as derivative contracts are reflected on the balance sheets at fair value. The portion of derivative positions that deliver within a year are included in "Current Assets" and "Current Liabilities," while the portion of derivative positions that deliver beyond a year are recorded in "Other Noncurrent Assets" and "Deferred Credits and Other Noncurrent Liabilities." Cash inflows and outflows related to derivative instruments are included as a component of operating, investing or financing activities on the Statements of Cash Flows, depending on the classification of the hedged items. PPL and its subsidiaries have elected not to offset net derivative positions against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements. (PPL) Processes exist that allow for subsequent review and validation of contract information as it relates to interest rate derivatives and foreign currency derivatives. The accounting department provides the treasury department with guidelines on appropriate accounting classifications for various contract types and strategies. Examples of accounting guidelines provided to the treasury department staff include, but are not limited to: • Transactions to lock in an interest rate prior to a debt issuance can be designated as cash flow hedges, to the extent the forecasted debt issuances remain probable of occurring. • Cross-currency transactions to hedge interest and principal repayments can be designated as cash flow hedges. • Transactions to hedge fluctuations in the fair value of existing debt can be designated as fair value hedges. • Transactions to hedge the value of a net investment of foreign operations can be designated as net investment hedges. • Derivative transactions that do not qualify for cash flow or net investment hedge treatment are marked to fair value through earnings. As such, these transactions reduce earnings volatility due solely to changes in foreign currency exchange rates. PPL also hedges anticipated transactions, including the previously completed sale of its U.K utility business and net investments. (All Registrants) Derivative transactions may be marked to fair value through regulatory assets/liabilities at PPL Electric, LG&E and KU, if approved by the appropriate regulatory body. These transactions generally include the effect of interest rate swaps that are included in customer rates. (PPL and PPL Electric) To meet its obligation as a PLR to its customers, PPL Electric has entered into certain contracts that meet the definition of a derivative. However, NPNS has been elected for these contracts. See Notes 17 and 18 for additional information on derivatives. Revenue (All Registrants) Operating revenues are primarily recorded based on energy deliveries through the end of each calendar month. Unbilled retail revenues result because customers' bills are rendered throughout the month, rather than bills being rendered at the end of the month. For LG&E and KU, unbilled revenues for a month are calculated by multiplying an estimate of unbilled kWh or Mcf by the estimated average cents per kWh or Mcf. Any difference between estimated and actual revenues is adjusted the following month when the previous unbilled estimate is reversed and actual billings occur. For PPL Electric, unbilled revenues for a month are calculated by multiplying the actual unbilled volumes by the price per tariff. PPL Electric's, LG&E's and KU's base rates are determined based on cost of service. Some regulators have also authorized the use of additional alternative revenue programs, which enable PPL Electric, LG&E and KU to adjust future rates based on past activities or completed events. Revenues from alternative revenue programs are recognized when the specific events permitting future billings have occurred. Revenues from alternative revenue programs are required to be presented separately from revenues from contracts with customers. These amounts are, however, presented as revenues from contracts with customers, with an offsetting adjustment to alternative revenue program revenue, when they are billed to customers in future periods. See Note 3 for additional information. Financing and Other Receivables (All Registrants) Accounts receivable are reported on the Balance Sheets at the gross outstanding amount adjusted for an allowance for doubtful accounts. Financing receivables include accounts receivable, with the exception of those items within accounts receivable that are not subject to the credit loss model. Financing receivable collectibility is evaluated using a current expected credit loss model, consisting of a combination of factors, including past due status based on contractual terms, trends in write-offs and the age of the receivable. Specific events, such as bankruptcies, are also considered when applicable. Adjustments to the allowance for doubtful accounts are made when necessary based on the results of analysis, the aging of receivables and historical and industry trends. The Registrants periodically evaluate the impact of observable external factors on the collectibility of the financing receivables to determine if adjustments to the allowance for doubtful accounts should be made based on current conditions or reasonable and supportable forecasts. Accounts receivable are written off in the period in which the receivable is deemed uncollectible. (PPL and PPL Electric) PPL Electric has identified one class of financing receivables, “accounts receivable - customer”, which includes financing receivables for all billed and unbilled sales with residential and non-residential customers. All other financing receivables are classified as other. Within the credit loss model for the residential customer accounts receivables, customers are disaggregated based on their projected propensity to pay, which is derived from historical trends and the current activity of the individual customer accounts. Conversely, the non-residential customer accounts receivables are not further segmented due to the varying nature of the individual customers, which lack readily identifiable risk characteristics for disaggregation. (PPL, LG&E and KU) LG&E and KU have identified one class of financing receivables, “accounts receivable - customer”, which includes financing receivables for all billed and unbilled sales with customers. All other financing receivables are classified as other. (All Registrants) The changes in the allowance for doubtful accounts are included in the following table. Amounts relate to financing receivables, except as noted. Additions Balance at Charged to Income Charged to Other Accounts Deductions (b) Balance at PPL 2021 $ 73 $ 26 $ — $ 30 $ 69 (d) 2020 (a) 58 (a) 28 — 13 73 (d) 2019 54 34 3 35 56 PPL Electric 2021 $ 41 $ 13 $ — $ 19 $ 35 (c) 2020 30 (a) 19 — 8 41 (c) 2019 27 26 — 25 28 LG&E 2021 $ 3 $ 4 $ — $ 4 $ 3 2020 1 4 — 2 3 2019 1 2 2 4 1 KU 2021 $ 2 $ 8 $ — $ 7 $ 3 2020 1 4 — 3 2 2019 2 4 1 6 1 (a) Adjusted for $2 million cumulative-effect adjustment upon adoption of current expected credit loss guidance. (b) Primarily related to uncollectible accounts written off. (c) Includes $3 million related to other accounts receivables at December 31, 2021 and 2020. (d) Includes $32 million and $30 million related to other accounts receivables at December 31, 2021 and 2020. Cash (All Registrants) Cash Equivalents All highly liquid investments with original maturities of three months or less are considered to be cash equivalents. (PPL) Restricted Cash and Cash Equivalents Bank deposits and other cash equivalents that are restricted by agreement or that have been clearly designated for a specific purpose are classified as restricted cash and cash equivalents. On the Balance Sheets, the current portion of restricted cash and cash equivalents is included in "Other current assets," while the noncurrent portion is included in "Other noncurrent assets." Reconciliation of Cash, Cash Equivalents and Restricted Cash The following provides a reconciliation of Cash, Cash Equivalents and Restricted Cash reported within the Balance Sheets to the amounts shown on the Statements of Cash Flows: December 31, December 31, Cash and cash equivalents $ 3,571 $ 442 Restricted cash - current 1 1 Total Cash, Cash Equivalents and Restricted Cash $ 3,572 $ 443 (All Registrants) Fair Value Measurements The Registrants value certain financial and nonfinancial assets and liabilities at fair value. Generally, the most significant fair value measurements relate to price risk management assets and liabilities, investments in securities in defined benefit plans, and cash and cash equivalents. PPL and its subsidiaries use, as appropriate, a market approach (generally, data from market transactions), an income approach (generally, present value techniques and option-pricing models) and/or a cost approach (generally, replacement cost) to measure the fair value of an asset or liability. These valuation approaches incorporate inputs such as observable, independent market data and/or unobservable data that management believes are predicated on the assumptions market participants would use to price an asset or liability. These inputs may incorporate, as applicable, certain risks such as nonperformance risk, which includes credit risk. The Registrants classify fair value measurements within one of three levels in the fair value hierarchy. The level assigned to a fair value measurement is based on the lowest level input that is significant to the fair value measurement in its entirety. The three levels of the fair value hierarchy are as follows: • Level 1 - quoted prices (unadjusted) in active markets for identical assets or liabilities that are accessible at the measurement date. Active markets are those in which transactions for the asset or liability occur with sufficient frequency and volume to provide pricing information on an ongoing basis. • Level 2 - inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for substantially the full term of the asset or liability. • Level 3 - unobservable inputs that management believes are predicated on the assumptions market participants would use to measure the asset or liability at fair value. Assessing the significance of a particular input requires judgment that considers factors specific to the asset or liability. As such, the Registrants' assessment of the significance of a particular input may affect how the assets and liabilities are classified within the fair value hierarchy. Investments Generally, the original maturity date of an investment and management's intent and ability to sell an investment prior to its original maturity determine the classification of investments as either short-term or long-term. Investments that would otherwise be classified as short-term, but are restricted as to withdrawal or use for other than current operations or are clearly designated for expenditure in the acquisition or construction of noncurrent assets or for the liquidation of long-term debts, are classified as long-term. Investments in entities in which a company has the ability to exercise significant influence but does not have a controlling financial interest are accounted for under the equity method. All other investments are carried at cost or fair value. These investments are included in "Other noncurrent assets" on the Balance Sheets. Earnings from these investments are recorded in "Other Income (Expense) - net" on the Statements of Income. Short-term investments generally include certain deposits as well as securities that are considered highly liquid or provide for periodic reset of interest rates. Investments with original maturities greater than three months and less than a year, as well as investments with original maturities of greater than a year that management has the ability and intent to sell within a year, are included in "Other current assets" on the Balance Sheets. Long-Lived and Intangible Assets Property, Plant and Equipment (All Registrants) PP&E is recorded at original cost, unless impaired. PP&E acquired in business combinations is recorded at fair value at the time of acquisition. If impaired, the asset is written down to fair value at that time, which becomes the new cost basis of the asset. Original cost for constructed assets includes material, labor, contractor costs, certain overheads and financing costs, where applicable. Included in PP&E are capitalized costs of software projects that were developed or obtained for internal use. The cost of repairs and minor replacements are charged to expense as incurred. The Registrants record costs associated with planned major maintenance projects in the period in which work is performed and costs are incurred. AFUDC is capitalized at PPL Electric as part of the construction costs for cost-based rate-regulated projects for which a return on such costs is recovered after the project is placed in service. The debt component of AFUDC is credited to "Interest Expense" and the equity component is credited to "Other Income (Expense) - net" on the Statements of Income. LG&E and KU generally do not record AFUDC as a return is provided on construction work in progress. (PPL and PPL Electric) PPL and PPL Electric capitalize interest costs as part of construction costs. Capitalized interest, including the debt component of AFUDC, for the years ended December 31 is as follows: 2021 2020 2019 PPL $ 6 $ 7 $ 9 PPL Electric 6 7 8 Depreciation (All Registrants) Depreciation is recorded over the estimated useful lives of property using various methods including the straight-line, composite and group methods. When a component of PP&E that was depreciated under the composite or group method is retired, the original cost is charged to accumulated depreciation. When all or a significant portion of an operating unit that was depreciated under the composite or group method is retired or sold, the property and the related accumulated depreciation account is reduced and any gain or loss is included in income, unless otherwise required by regulators. LG&E and KU accrue costs of removal net of estimated salvage value through depreciation, which is included in the calculation of customer rates over the assets' depreciable lives in accordance with regulatory practices. Cost of removal amounts accrued through depreciation rates are accumulated as a regulatory liability until the removal costs are incurred. For LG&E and KU, all ARO depreciation expenses are reclassified to a regulatory asset or regulatory liability. See "Asset Retirement Obligations" below and Note 7 for additional information. PPL Electric records net costs of removal when incurred as a regulatory asset. The regulatory asset is subsequently amortized through depreciation over a five-year period, which is recoverable in customer rates in accordance with regulatory practices. Following are the weighted-average annual rates of depreciation, for regulated utility plant, for the years ended December 31: 2021 2020 2019 PPL 3.61 % 3.53 % 3.54 % PPL Electric 3.05 % 2.99 % 3.05 % LG&E 3.99 % 4.00 % 3.87 % KU 4.17 % 4.00 % 4.02 % Goodwill and Other Intangible Assets ( All Registrants) Goodwill represents the excess of the purchase price paid over the fair value of the identifiable net assets acquired in a business combination. Other acquired intangible assets are initially measured based on their fair value. Intangibles that have finite useful lives are amortized over their useful lives based upon the pattern in which the economic benefits of the intangible assets are consumed or otherwise used. Costs incurred to obtain an initial license and renew or extend terms of licenses are capitalized as intangible assets. When determining the useful life of an intangible asset, including intangible assets that are renewed or extended, PPL and its subsidiaries consider: • the expected use of the asset; • the expected useful life of other assets to which the useful life of the intangible asset may relate; • legal, regulatory, or contractual provisions that may limit the useful life; • the company's historical experience as evidence of its ability to support renewal or extension; • the effects of obsolescence, demand, competition, and other economic factors; and, • the level of maintenance expenditures required to obtain the expected future cash flows from the asset. Asset Impairment (Excluding Investments) (All Registrants) The Registrants review long-lived assets that are subject to depreciation or amortization, including finite-lived intangibles, for impairment when events or circumstances indicate carrying amounts may not be recoverable. A long-lived asset classified as held and used is impaired when the carrying amount of the asset exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. If impaired, the asset's carrying value is written down to its fair value. A long-lived asset classified as held for sale is impaired when the carrying amount of the asset (disposal group) exceeds its fair value less cost to sell. If impaired, the asset's (disposal group's) carrying value is written down to its fair value less cost to sell. PPL, LG&E and KU review goodwill for impairment at the reporting unit level annually or more frequently when events or circumstances indicate that the carrying amount of a reporting unit may be greater than the unit's fair value. Additionally, goodwill must be tested for impairment in circumstances when a portion of goodwill has been allocated to a business to be disposed. PPL's, LG&E's and KU's reporting units are primarily at the operating segment level. PPL, for its Kentucky Regulated segment and LKE reporting units, and individually LG&E and KU may elect either to initially make a qualitative evaluation about the likelihood of an impairment of goodwill or to bypass the qualitative evaluation and test goodwill for impairment using a quantitative test. If the qualitative evaluation (referred to as step zero) is elected and the assessment results in a determination that it is not more likely than not that the fair value of a reporting unit is less than the carrying amount, the quantitative impairment test is not necessary. However, the quantitative impairment test is required if management concludes it is more likely than not that the fair value of a reporting unit is less than the carrying amount based on the step zero assessment. If the carrying amount of the reporting unit, including goodwill, exceeds its fair value, an impairment loss is recognized in an amount equal to that excess, limited to the total amount of goodwill allocated to that reporting unit. In the fourth quarter of 2021, PPL, for its Kentucky Regulated segment and LKE reporting units, and individually, LG&E and KU, elected to perform qualitative step zero evaluations for their annual goodwill impairment tests, as of October 1, 2021. Based on these evaluations, management concluded it was not "more likely than not" that the fair value of these reporting units was less than their carrying values. As such, quantitative impairment tests were not performed. (PPL) During the three month-period ended June 30, 2021, Safari Energy determined that the carrying value of its solar panel inventory would not be fully recoverable due to a decrease in the net realizable value of the modules. The decrease was due primarily to the combination of the three following factors: (1) a continued decrease in the fair value of the modules on hand due to more efficient modules being available on the market, (2) the federal government's extension of certain investment tax credits which make modules on the open market eligible for those credits at higher levels of credits and (3) an increase in commodity prices for materials used in various types of solar projects, all of which place pressure on the economics of those projects, making the cost of Safari's solar panels uncompetitive. As a result, Safari Energy recorded a loss of $37 million ($28 million after-tax) in June 2021 to record the solar panels at fair value. The loss was recorded to "Other operation and maintenance" expense on the Statement of Income. Solar panel inventories of $32 million are included in "Other noncurrent assets" on PPL's Balance Sheet at December 31, 2021. PPL considered whether the events and circumstances that led to the impairment of Safari Energy's solar panels would more likely than not reduce the fair value of PPL's Distributed Energy Resources reporting unit below its carrying amount. Based on PPL's assessment, a quantitative impairment test was not required as of June 30, 2021. In the fourth quarter of 2021, PPL elected to perform a quantitative goodwill impairment test in conjunction with the annual goodwill impairment assessment for the Distributed Energy Resources reporting unit. The test did not indicate impairment of the reporting unit , however, it is possible that an impairment charge could occur in future periods if any of the assumptions used in determining fair value of the reporting unit are negatively impacted. ( PPL, LG&E and KU ) Asset Retirement Obligations PPL and its subsidiaries record liabilities to reflect various legal obligations associated with the retirement of long-lived assets. Initially, this obligation is measured at fair value and offset with an increase in the value of the capitalized asset, which is depreciated over the asset's useful life. Until the obligation is settled, the liability is increased through the recognition of accretion expense classified within "Other operation and maintenance" on the Statements of Income to reflect changes in the obligation due to the passage of time. For LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, deferred accretion and depreciation expense is recovered through cost of removal. Estimated ARO costs and settlement dates, which affect the carrying value of the ARO and the related capitalized asset, are reviewed periodically to ensure that any material changes are incorporated into the latest estimate of the ARO. Any change to the capitalized asset, positive or negative, is generally amortized over the remaining life of the associated long-lived asset. See Note 7 and Note 20 for additional information on AROs. Compensation and Benefits Defined Benefits (All Registrants) Certain PPL subsidiaries sponsor various defined benefit pension and other postretirement plans. An asset or liability is recorded to recognize the funded status of all defined benefit plans with an offsetting entry to AOCI or, for LG&E, KU and PPL Electric, to regulatory assets or liabilities. Consequently, the funded status of all defined benefit plans is fully recognized on the Balance Sheets. The expected return on plan assets is determined based on a market-related value of plan assets, which is calculated by rolling forward the prior year market-related value with contributions, disbursements and long-term expected return on investments. One-fifth of the difference between the actual value and the expected value is added (or subtracted if negative) to the expected value to determine the new market-related value. PPL uses an accelerated amortization method for the recognition of gains and losses for its defined benefit pension plans. Under the accelerated method, actuarial gains and losses in excess of 30% of the plan's projected benefit obligation are amortized on a straight-line basis over one-half of the required amortization period. Actuarial gains and losses in excess of 10% of the greater of the plan's projected benefit obligation or the market-related value of plan assets and less than 30% of the plan's projected benefit obligation are amortized on a straight-line basis over the full required amortization period. See Note 7 for a discussion of the regulatory treatment of defined benefit costs and Note 12 for a discussion of defined benefits. Stock-Based Compensation (PPL and PPL Electric) PPL has several stock-based compensation plans for purposes of granting stock options, restricted stock, restricted stock units and performance units to certain emplo

Segment and Related Information

Segment and Related Information	12 Months Ended
	Dec. 31, 2021
Segment Reporting [Abstract]
Segment and Related Information	(PPL) PPL is organized into two segments: Kentucky Regulated and Pennsylvania Regulated. PPL's segments are segmented by geographic location. The Kentucky Regulated segment consists primarily of LG&E's and KU's regulated electricity generation, transmission and distribution operations, as well as LG&E's regulated distribution and sale of natural gas. The Pennsylvania Regulated segment includes the regulated electricity transmission and distribution operations of PPL Electric. "Corporate and Other" primarily includes financing costs incurred at the corporate level that have not been allocated or assigned to the segments, certain other unallocated costs, as well as the financial results of Safari Energy, which is presented to reconcile segment information to PPL's consolidated results. For the periods ended December 31, 2020 and 2019, these amounts have been adjusted for certain costs that were previously included in the U.K. Regulated segment. On March 17, 2021, PPL WPD Limited entered into a share purchase agreement to sell PPL's U.K. utility business, which substantially represented PPL's U.K. Regulated segment. As a result, PPL determined segment information for the U.K. Regulated segment would no longer be provided beginning with the March 31, 2021 Form 10-Q. The sale of the U.K. utility business was completed on June 14, 2021. See Note 9 for additional information. Income Statement data for the segments and reconciliation to PPL's consolidated results for the years ended December 31 are as follows: 2021 2020 2019 Operating Revenues from external customers (a) Kentucky Regulated $ 3,348 $ 3,106 $ 3,206 Pennsylvania Regulated 2,402 2,330 2,358 Corporate and Other 33 38 38 Total $ 5,783 $ 5,474 $ 5,602 2021 2020 2019 Depreciation Kentucky Regulated $ 647 $ 606 $ 547 Pennsylvania Regulated 424 403 386 Corporate and Other 11 13 16 Total $ 1,082 $ 1,022 $ 949 Amortization (b) Kentucky Regulated $ 15 $ 19 $ 27 Pennsylvania Regulated 19 26 24 Corporate and Other 5 13 7 Total $ 39 $ 58 $ 58 Interest Expense (c) Kentucky Regulated $ 249 $ 300 $ 298 Pennsylvania Regulated 162 172 169 Corporate and Other (d) 507 162 154 Total $ 918 $ 634 $ 621 Income Before Income Taxes Kentucky Regulated $ 562 $ 516 $ 530 Pennsylvania Regulated 599 664 607 Corporate and Other (640) (226) (218) Total $ 521 $ 954 $ 919 Income Taxes (e) Kentucky Regulated $ 94 $ 98 $ 94 Pennsylvania Regulated 154 167 149 Corporate and Other 255 49 (60) Total $ 503 $ 314 $ 183 Deferred income taxes and investment tax credits (f) Kentucky Regulated $ 272 $ 64 $ 82 Pennsylvania Regulated 79 82 90 Corporate and Other (264) 23 (3) Total $ 87 $ 169 $ 169 Net Income Kentucky Regulated $ 468 $ 418 $ 436 Pennsylvania Regulated 445 497 458 Corporate and Other (d) (895) (275) (158) Discontinued Operations (1,498) 829 1,010 Total $ (1,480) $ 1,469 $ 1,746 (a) See Note 1 and Note 3 for additional information on Operating Revenues. (b) Represents non-cash expense items that include amortization of operating lease right-of-use assets, regulatory assets and liabilities, debt discounts and premiums and debt issuance costs. (c) Beginning in 2021, corporate level financing costs are no longer allocated to the reportable segments and are being reported in Corporate and Other. For the years ended December 31, 2020 and 2019, corporate level financing costs of $32 million, net of $8 million of income taxes, and $32 million, net of $9 million of income taxes, were allocated to the Kentucky Regulated segment. For the years ended December 31, 2020 and 2019, an immaterial amount of financing costs were allocated to the Pennsylvania Regulated segment. (d) 2021 includes losses from the extinguishment of PPL Capital Funding debt. See Note 8 for additional information. (e) Represents both current and deferred income taxes, including investment tax credits. (f) Represents a non-cash expense item that is also included in "Income Taxes." Cash Flow data for the segments and reconciliation to PPL's consolidated results for the years ended December 31 are as follows: 2021 2020 2019 Expenditures for long-lived assets Kentucky Regulated $ 1,026 $ 966 $ 1,097 Pennsylvania Regulated 904 1,154 1,121 Corporate and Other 49 158 32 Total $ 1,979 $ 2,278 $ 2,250 The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated results as of: As of December 31, 2021 2020 Total Assets Kentucky Regulated $ 16,360 $ 15,943 Pennsylvania Regulated 13,336 12,347 Corporate and Other (a) 3,527 843 Assets held for sale (b) — 18,983 Total $ 33,223 $ 48,116 (a) Primarily consists of unallocated items, including cash, PP&E, goodwill, the elimination of inter-segment transactions as well as the assets of Safari Energy. (b) See Note 9 for additional information. (PPL Electric, LG&E and KU) PPL Electric has two operating segments that are aggregated into a single reportable segment. LG&E and KU are individually single operating and reportable segments.

Revenue from Contracts with Cus

Revenue from Contracts with Customers	12 Months Ended
	Dec. 31, 2021
Revenue from Contract with Customer [Abstract]
Revenue from Contract with Customer	(All Registrants) The following is a description of the principal activities from which the Registrants and PPL’s segments generate their revenues. (PPL and PPL Electric) Pennsylvania Regulated Segment Revenue The Pennsylvania Regulated Segment generates substantially all of its revenues from contracts with customers from PPL Electric’s tariff-based distribution and transmission of electricity. Distribution Revenue PPL Electric provides distribution services to residential, commercial, industrial, municipal and governmental end users of energy. PPL Electric satisfies its performance obligation to its distribution customers and revenue is recognized over-time as electricity is delivered and simultaneously consumed by the customer. The amount of revenue recognized is the volume of electricity delivered during the period multiplied by the price per tariff, plus a monthly fixed charge. This method of recognition fairly presents PPL Electric's transfer of electric service to the customer as the calculation is based on actual volumes, and the price per tariff and the monthly fixed charge are set by the PUC. Customers are typically billed monthly and outstanding amounts are normally due within 21 days of the date of the bill. Distribution customers are "at will" customers of PPL Electric with no term contract and no minimum purchase commitment. Performance obligations are limited to the service requested and received to date. Accordingly, there is no unsatisfied performance obligation associated with PPL Electric’s retail account contracts. Transmission Revenue PPL Electric generates transmission revenues from a FERC-approved PJM Open Access Transmission Tariff. An annual revenue requirement for PPL Electric to provide transmission services is calculated using a formula-based rate. This revenue requirement is converted into a daily rate (dollars per day). PPL Electric satisfies its performance obligation to provide transmission services and revenue is recognized over-time as transmission services are provided and consumed. This method of recognition fairly presents PPL Electric's transfer of transmission services as the daily rate is set by a FERC approved formula-based rate. PJM remits payment on a weekly basis. PPL Electric's agreement to provide transmission services contains no minimum purchase commitment. The performance obligation is limited to the service requested and received to date. Accordingly, PPL Electric has no unsatisfied performance obligations. (PPL, LG&E and KU) Kentucky Regulated Segment Revenue The Kentucky Regulated Segment generates substantially all of its revenues from contracts with customers from LG&E's and KU's regulated tariff-based sales of electricity and LG&E's regulated tariff-based sales of natural gas. LG&E and KU are engaged in the generation, transmission, distribution and sale of electricity in Kentucky and, in KU's case, Virginia. LG&E also engages in the distribution and sale of natural gas in Kentucky. Revenue from these activities is generated from tariffs approved by applicable regulatory authorities including the FERC, KPSC and VSCC. LG&E and KU satisfy their performance obligations upon LG&E's and KU's delivery of electricity and LG&E's delivery of natural gas to customers. This revenue is recognized over-time as the customer simultaneously receives and consumes the benefits provided by LG&E and KU. The amount of revenue recognized is the billed volume of electricity or natural gas delivered multiplied by a tariff rate per-unit of energy, plus any applicable fixed charges or additional regulatory mechanisms. Customers are billed monthly and outstanding amounts are typically due within 22 days of the date of the bill. Additionally, unbilled revenues are recognized as a result of customers' bills rendered throughout the month, rather than bills being rendered at the end of the month. Unbilled revenues for a month are calculated by multiplying an estimate of unbilled kWh or Mcf delivered but not yet billed by the estimated average cents per kWh or Mcf. Any difference between estimated and actual revenues is adjusted the following month when the previous unbilled estimate is reversed and actual billings occur. This method of recognition fairly presents LG&E's and KU's transfer of electricity and LG&E's transfer of natural gas to the customer as the amount recognized is based on actual and estimated volumes delivered and the tariff rate per-unit of energy and any applicable fixed charges or regulatory mechanisms as set by the respective regulatory body. LG&E's and KU's customers generally have no minimum purchase commitment. Performance obligations are limited to the service requested and received to date. Accordingly, there is no unsatisfied performance obligation associated with these customers. (All Registrants) The following table reconciles "Operating Revenues" included in each Registrant's Statement of Income with revenues generated from contracts with customers for the years ended December 31: 2021 PPL PPL Electric LG&E KU Operating Revenues (a) $ 5,783 $ 2,402 $ 1,569 $ 1,826 Revenues derived from: Alternative revenue programs (b) 77 83 (3) (3) Other (c) (22) (3) (8) (9) Revenues from Contracts with Customers $ 5,838 $ 2,482 $ 1,558 $ 1,814 2020 PPL PPL Electric LG&E KU Operating Revenues (a) $ 5,474 $ 2,331 $ 1,456 $ 1,690 Revenues derived from: Alternative revenue programs (b) (24) (12) (8) (4) Other (c) (21) (3) (7) (10) Revenues from Contracts with Customers $ 5,429 $ 2,316 $ 1,441 $ 1,676 2019 PPL PPL Electric LG&E KU Operating Revenues (a) $ 5,602 $ 2,358 $ 1,500 $ 1,740 Revenues derived from: Alternative revenue programs (b) (30) (6) (10) (14) Other (c) (31) (10) (9) (12) Revenues from Contracts with Customers $ 5,541 $ 2,342 $ 1,481 $ 1,714 (a) Amounts for PPL Electric represent revenues from external customers reported by the Pennsylvania Regulated segment and amounts for LG&E and KU, net of intercompany power sales and transmission revenues, represent revenues from external customers reported by the Kentucky Regulated segment. See Note 2 for additional information. (b) Alternative revenue programs include the transmission formula rate for PPL Electric, the ECR and DSM programs for LG&E and KU, the GLT and GSC programs for LG&E, and the generation formula rate for KU. For PPL Electric, revenue in 2021 was reduced by $78 million for a reduction in the transmission formula rate return on equity. See Note 7 for additional information. This line item shows the over/under collection of these rate mechanisms with over-collections of revenue shown as positive amounts in the table above and under-collections shown as negative amounts. (c) Represents additional revenues outside the scope of revenues from contracts with customers such as leases and other miscellaneous revenues. The following table shows revenues from contracts with customers disaggregated by customer class for the years ended December 31: 2021 Residential Commercial Industrial Other (a) Wholesale - municipality Wholesale - other (b) Transmission Revenues from Contracts with Customers PPL PA Regulated $ 1,299 $ 350 $ 53 $ 50 $ — $ — $ 730 $ 2,482 KY Regulated 1,416 928 586 305 24 66 — 3,325 Corp and Other — — — 31 — — — 31 Total PPL $ 2,715 $ 1,278 $ 639 $ 386 $ 24 $ 66 $ 730 $ 5,838 PPL Electric $ 1,299 $ 350 $ 53 $ 50 $ — $ — $ 730 $ 2,482 LG&E $ 711 $ 473 $ 180 $ 145 $ — $ 49 $ — $ 1,558 KU $ 705 $ 455 $ 406 $ 160 $ 24 $ 64 $ — $ 1,814 2020 Residential Commercial Industrial Other (a) Wholesale - municipality Wholesale - other (b) Transmission Revenues from Contracts with Customers PPL PA Regulated $ 1,238 $ 314 $ 44 $ 50 $ — $ — $ 670 $ 2,316 KY Regulated 1,347 871 538 261 20 40 — 3,077 Corp and Other — — — 36 — — — 36 Total PPL $ 2,585 $ 1,185 $ 582 $ 347 $ 20 $ 40 $ 670 $ 5,429 PPL Electric $ 1,238 $ 314 $ 44 $ 50 $ — $ — $ 670 $ 2,316 LG&E $ 676 $ 444 $ 173 $ 114 $ — $ 34 $ — $ 1,441 KU $ 671 $ 427 $ 365 $ 147 $ 20 $ 46 $ — $ 1,676 2019 Residential Commercial Industrial Other (a) Wholesale - municipality Wholesale - other (b) Transmission Revenues from Contracts with Customers PPL PA Regulated $ 1,288 $ 349 $ 59 $ 52 $ — $ — $ 594 $ 2,342 KY Regulated 1,322 908 562 277 43 49 — 3,161 Corp and Other — — — 38 — — — 38 Total PPL $ 2,610 $ 1,257 $ 621 $ 367 $ 43 $ 49 $ 594 $ 5,541 PPL Electric $ 1,288 $ 349 $ 59 $ 52 $ — $ — $ 594 $ 2,342 LG&E $ 668 $ 466 $ 180 $ 121 $ — $ 46 $ — $ 1,481 KU $ 654 $ 442 $ 382 $ 156 $ 43 $ 37 $ — $ 1,714 (a) Primarily includes revenues from pole attachments, street lighting, other public authorities and other non-core businesses. (b) Includes wholesale power and transmission revenues. LG&E and KU amounts include intercompany power sales and transmission revenues, which are eliminated upon consolidation at PPL. As discussed in Note 2, PPL segments its business by geographic location. Revenues from external customers for each segment/geographic location are reconciled to revenues from contracts with customers in the footnotes to the tables above. PPL Electric's revenues from contracts with customers are further disaggregated by distribution and transmission as indicated in the above tables. Contract receivables from customers are primarily included in "Accounts receivable - Customer" and "Unbilled revenues" on the Balance Sheets. The following table shows the accounts receivable and unbilled revenues balances that were impaired for the year ended December 31: 2021 2020 2019 PPL $ 22 $ 25 $ 27 PPL Electric 10 17 21 LG&E 4 4 2 KU 8 4 4 The following table shows the balances and certain activity of contract liabilities resulting from contracts with customers: PPL PPL Electric LG&E KU Contract liabilities as of December 31, 2021 $ 42 $ 25 $ 6 $ 6 Contract liabilities as of December 31, 2020 40 23 5 6 Revenue recognized during the year ended December 31, 2021 that was included in the contract liability balance at December 31, 2020 24 11 5 6 Contract liabilities as of December 31, 2020 $ 40 $ 23 $ 5 $ 6 Contract liabilities as of December 31, 2019 37 21 5 4 Revenue recognized during the year ended December 31, 2020 that was included in the contract liability balance at December 31, 2019 22 9 5 4 Contract liabilities as of December 31, 2019 $ 37 $ 21 $ 5 $ 4 Contract liabilities as of December 31, 2018 40 23 5 4 Revenue recognized during the year ended December 31, 2019 that was included in the contract liability balance at December 31, 2018 25 11 5 4 Contract liabilities result from recording contractual billings in advance for customer attachments to the Registrants' infrastructure and payments received in excess of revenues earned to date. Advanced billings for customer attachments are recognized as revenue ratably over the billing period. Payments received in excess of revenues earned to date are recognized as revenue as services are delivered in subsequent periods. At December 31, 2021, PPL had $46 million of performance obligations attributable to Corporate and Other that have not been satisfied. Of this amount, PPL expects to recognize approximately $41 million within the next 12 months.

Preferred Securities

Preferred Securities	12 Months Ended
	Dec. 31, 2021
Preferred Securities [Line Items]
Preferred Securities	(PPL) PPL is authorized to issue up to 10 million shares of preferred stock. No PPL preferred stock was issued or outstanding in 2021, 2020 or 2019. (PPL Electric) PPL Electric is authorized to issue up to 20,629,936 shares of preferred stock. No PPL Electric preferred stock was issued or outstanding in 2021, 2020 or 2019. (LG&E) LG&E is authorized to issue up to 1,720,000 shares of preferred stock at a $25 par value and 6,750,000 shares of preferred stock without par value. LG&E had no preferred stock issued or outstanding in 2021, 2020 or 2019. (KU) KU is authorized to issue up to 5,300,000 shares of preferred stock and 2,000,000 shares of preference stock without par value. KU had no preferred or preference stock issued or outstanding in 2021, 2020 or 2019.
PPL Electric Utilities Corp [Member]
Preferred Securities [Line Items]
Preferred Securities	(PPL) PPL is authorized to issue up to 10 million shares of preferred stock. No PPL preferred stock was issued or outstanding in 2021, 2020 or 2019. (PPL Electric) PPL Electric is authorized to issue up to 20,629,936 shares of preferred stock. No PPL Electric preferred stock was issued or outstanding in 2021, 2020 or 2019. (LG&E) LG&E is authorized to issue up to 1,720,000 shares of preferred stock at a $25 par value and 6,750,000 shares of preferred stock without par value. LG&E had no preferred stock issued or outstanding in 2021, 2020 or 2019. (KU) KU is authorized to issue up to 5,300,000 shares of preferred stock and 2,000,000 shares of preference stock without par value. KU had no preferred or preference stock issued or outstanding in 2021, 2020 or 2019.
Louisville Gas And Electric Co [Member]
Preferred Securities [Line Items]
Preferred Securities	(PPL) PPL is authorized to issue up to 10 million shares of preferred stock. No PPL preferred stock was issued or outstanding in 2021, 2020 or 2019. (PPL Electric) PPL Electric is authorized to issue up to 20,629,936 shares of preferred stock. No PPL Electric preferred stock was issued or outstanding in 2021, 2020 or 2019. (LG&E) LG&E is authorized to issue up to 1,720,000 shares of preferred stock at a $25 par value and 6,750,000 shares of preferred stock without par value. LG&E had no preferred stock issued or outstanding in 2021, 2020 or 2019. (KU) KU is authorized to issue up to 5,300,000 shares of preferred stock and 2,000,000 shares of preference stock without par value. KU had no preferred or preference stock issued or outstanding in 2021, 2020 or 2019.
Kentucky Utilities Co [Member]
Preferred Securities [Line Items]
Preferred Securities	(PPL) PPL is authorized to issue up to 10 million shares of preferred stock. No PPL preferred stock was issued or outstanding in 2021, 2020 or 2019. (PPL Electric) PPL Electric is authorized to issue up to 20,629,936 shares of preferred stock. No PPL Electric preferred stock was issued or outstanding in 2021, 2020 or 2019. (LG&E) LG&E is authorized to issue up to 1,720,000 shares of preferred stock at a $25 par value and 6,750,000 shares of preferred stock without par value. LG&E had no preferred stock issued or outstanding in 2021, 2020 or 2019. (KU) KU is authorized to issue up to 5,300,000 shares of preferred stock and 2,000,000 shares of preference stock without par value. KU had no preferred or preference stock issued or outstanding in 2021, 2020 or 2019.

Earnings Per Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2021
Earnings Per Share [Abstract]
Earnings Per Share	(PPL) Basic EPS is computed by dividing income available to PPL common shareowners by the weighted-average number of common shares outstanding during the applicable period. Diluted EPS is computed by dividing income available to PPL common shareowners by the weighted-average number of common shares outstanding, increased by incremental shares that would be outstanding if potentially dilutive non-participating securities were converted to common shares as calculated using the Treasury Stock Method. Incremental non-participating securities that have a dilutive impact are detailed in the table below. These securities also included the remaining shares of PPL common stock forward sale agreements, which were settled in 2019. The forward sale agreements were dilutive under the Treasury Stock Method to the extent the average stock price of PPL's common shares exceeded the forward sale price prescribed in the agreements. Reconciliations of the amounts of income and shares of PPL common stock (in thousands) for the periods ended December 31, used in the EPS calculation are: 2021 2020 2019 Income (Numerator) Income from continuing operations after income taxes $ 18 $ 640 $ 736 Less amounts allocated to participating securities — 1 1 Income from continuing operations after income taxes available to PPL common shareowners - Basic and Diluted $ 18 $ 639 $ 735 Income (loss) from discontinued operations (net of income taxes) available to PPL common shareowners - Basic and Diluted $ (1,498) $ 829 $ 1,010 Net income (loss) attributable to PPL $ (1,480) $ 1,469 1,746 Less amounts allocated to participating securities — 1 1 Net income (loss) available to PPL common shareowners - Basic and Diluted $ (1,480) $ 1,468 $ 1,745 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 762,902 768,590 728,512 Add incremental non-participating securities: Add: Dilutive share-based payment awards (a) 1,917 794 1,101 Add: Forward sale agreements — — 7,141 Weighted-average shares - Diluted EPS 764,819 769,384 736,754 Basic EPS Available to PPL common shareowners: Income from continuing operations after income taxes $ 0.03 $ 0.83 $ 1.01 Income (loss) from discontinued operations (net of income taxes) (1.96) 1.08 1.38 Net Income (Loss) available to PPL common shareowners $ (1.93) $ 1.91 $ 2.39 Diluted EPS Available to PPL common shareowners: Income from continuing operations after income taxes $ 0.03 $ 0.83 $ 1.00 Income (loss) from discontinued operations (net of income taxes) (1.96) 1.08 1.37 Net Income (Loss) available to PPL common shareowners $ (1.93) $ 1.91 $ 2.37 (a) The Treasury Stock Method was applied to non-participating share-based payment awards. For the years ended December 31, PPL issued common stock related to stock-based compensation plans and DRIP as follows (in thousands): 2021 2020 Stock-based compensation plans (a) 983 731 DRIP — 943 (a) Includes stock options exercised, vesting of performance units, vesting of restricted stock and restricted stock units and conversion of stock units granted to directors. For the years ended December 31, the following shares (in thousands) were excluded from the computations of diluted EPS because the effect would have been antidilutive: 2021 2020 2019 Stock-based compensation awards 1,783 452 8

Income and Other Taxes

Income and Other Taxes	12 Months Ended
	Dec. 31, 2021
Income Tax Disclosure [Abstract]
Income and Other Taxes	6. Income and Other Taxes (PPL) "Income (Loss) from Continuing Operations Before Income Taxes" is from domestic operations. Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for accounting purposes and their basis for income tax purposes and the tax effects of net operating loss and tax credit carryforwards. The provision for PPL's deferred income taxes for regulated assets and liabilities is based upon the ratemaking principles of the applicable jurisdiction. See Notes 1 and 7 for additional information. Net deferred tax assets have been recognized based on management's estimates of future taxable income. Significant components of PPL's deferred income tax assets and liabilities were as follows: 2021 2020 Deferred Tax Assets Deferred investment tax credits $ 30 $ 30 Regulatory liabilities 94 68 Income taxes due to customers 422 444 Accrued pension and postretirement costs 75 106 Federal loss carryforwards (a) — 234 State loss carryforwards 483 448 Federal and state tax credit carryforwards (a) 15 401 Leases 67 68 Contributions in aid of construction 120 115 Other 84 68 Valuation allowances (462) (536) Total deferred tax assets 928 1,446 Deferred Tax Liabilities Plant - net 3,812 3,700 Regulatory assets 180 195 Other 75 70 Total deferred tax liabilities 4,067 3,965 Net deferred tax liability $ 3,139 $ 2,519 (a) PPL utilized federal net operating losses of $1,115 million and tax credit carryforwards of $272 million in June 2021 as a result of the completion of the sale of the U.K. utility business on June 14, 2021. The related deferred tax assets decreased by approximately $506 million, with a corresponding reduction in current income taxes. State deferred taxes are determined by entity and by jurisdiction. As a result, $12 million and $17 million of net deferred tax assets are shown as "Other noncurrent assets" on the Balance Sheets for 2021 and 2020. At December 31, 2021, PPL had the following loss and tax credit carryforwards, related deferred tax assets and valuation allowances recorded against the deferred tax assets: Gross Deferred Tax Asset Valuation Allowance Expiration Loss and other carryforwards State net operating losses $ 6,468 $ 483 $ (459) 2022-2041 Credit carryforwards State recycling credit 14 — 2028 State - other 1 — Indefinite Valuation allowances have been established for the amount that, more likely than not, will not be realized. The changes in deferred tax valuation allowances were as follows: Additions Balance at Charged Charged to Deductions Balance 2021 $ 536 $ 48 (a) $ — $ 122 (b) $ 462 2020 514 26 — 4 536 2019 495 24 — 5 514 (a) In 2021, PPL recorded a $31 million increase in a valuation allowance on a state net operating loss carryforward in connection with the loss on extinguishment associated with a tender offer to purchase and retire PPL Capital Funding's outstanding Senior Notes. See Note 8 for additional information on the tender offer. (b) In light of the disposition of PPL's U.K. utility business, there was a decrease in the valuation allowance of approximately $113 million. A U.S. based company with foreign subsidiaries may be required to record deferred taxes associated with the differences in the outside book-tax basis of those subsidiaries. The primary component of such outside basis differences is ordinarily accumulated unremitted earnings. In anticipation of the WPD sale, indefinite reinvestment of accumulated unremitted earnings of WPD was no longer relevant and, in the first quarter of 2021, PPL recorded a deferred tax liability reflecting the expected tax cost associated with the realization of the outside book-tax basis difference in the investment in WPD. In the second quarter of 2021, following completion of the WPD sale, that deferred tax was recorded to current tax expense. Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows: 2021 2020 2019 Income Tax Expense (Benefit) Current - Federal $ (1) $ (8) $ (10) Current - State 36 24 19 Current - Foreign (1) (2) — Total Current Expense (Benefit) 34 14 9 Deferred - Federal 28 135 141 Deferred - State 105 94 76 Deferred - Foreign (a) 383 101 (14) Total Deferred Expense (Benefit), excluding operating loss carryforwards 516 330 203 Amortization of investment tax credit (3) (3) (3) Tax expense (benefit) of operating loss carryforwards Deferred - Federal 12 6 7 Deferred - State (56) (33) (33) Total Tax Expense (Benefit) of Operating Loss Carryforwards (44) (27) (26) Total income tax expense (benefit) $ 503 $ 314 $ 183 Total income tax expense (benefit) - Federal $ 36 $ 130 $ 135 Total income tax expense (benefit) - State 85 85 62 Total income tax expense (benefit) - Foreign 382 99 (14) Total income tax expense (benefit) $ 503 $ 314 $ 183 (a) In 2021, the U.K. Finance Act 2021 increased the U.K. corporation tax rate from 19% to 25%, effective April 1, 2023. The primary impact of the corporation tax rate increase was an increase in deferred tax liabilities of the U.K. utility business, which was sold on June 14, 2021, and a corresponding deferred tax expense of $383 million, which was recognized in continuing operations in the second quarter of 2021. In 2020, the U.K. Finance Act 2020 cancelled the tax rate reduction from 19% to 17%. The primary impact of the cancellation of the corporation tax rate reduction was an increase in deferred tax liabilities and a corresponding deferred tax expense of $106 million. In the table above, the following income tax expense (benefit) are excluded from income taxes: 2021 2020 2019 Discontinued operations - PPL U.K. utility business $ 759 $ 188 $ 226 Reclassification from AOCI due to sale of UK utility business 660 — — Other comprehensive income 150 (19) (93) Total $ 1,569 $ 169 $ 133 2021 2020 2019 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 109 $ 200 $ 193 State income taxes, net of federal income tax benefit 23 48 45 Valuation allowance adjustments (a) 48 24 22 Federal and state income tax return adjustments (3) (9) 1 Impact of the U.K. Finance Acts on deferred tax balances (b) 383 101 (14) Depreciation and other items not normalized (5) (5) (10) Amortization of excess deferred federal and state income taxes (54) (43) (40) Non-deductible officer's salary 6 7 4 Kentucky recycling credit, net of federal income tax expense (c) — — (18) Other (4) (9) — Total increase (decrease) 394 114 (10) Total income tax expense (benefit) $ 503 $ 314 $ 183 Effective income tax rate 96.5% 32.9% 19.9% (a) In 2021, PPL recorded a $31 million state deferred tax benefit on a net operating loss and an offsetting valuation allowance in connection with the loss on extinguishment associated with a tender offer to purchase and retire PPL Capital Funding's outstanding Senior Notes. See Note 8 for additional information on the tender offer. In 2021, 2020, and 2019, PPL recorded deferred income tax expense of $15 million, $24 million and $25 million for valuation allowances primarily related to increased Pennsylvania net operating loss carryforwards expected to be unutilized. (b) In 2020, the U.K. Finance Act 2020 cancelled the tax rate reduction to 17%, thereby maintaining the corporation tax rate at 19% for financial years 2020 and 2021. The primary impact of the cancellation of the corporation tax rate reduction was an increase in deferred tax liabilities and a corresponding deferred tax expense of $106 million. In 2021, the U.K. Finance Act 2021 increased the U.K. corporation tax rate from 19% to 25%, effective April 1, 2023. The primary impact of the corporation tax rate increase was an increase in deferred tax liabilities of the U.K. utility business, which was sold on June 14, 2021, and a corresponding deferred tax expense of $383 million, which was recognized in continuing operations in the second quarter of 2021. (c) In 2019, LG&E recorded a deferred income tax benefit associated with two projects placed into service that prepare a generation waste material for reuse and, as a result, qualify for a Kentucky recycling credit. The applicable credit provides tax benefits for a portion of the equipment costs for major recycling projects in Kentucky. 2021 2020 2019 Taxes, other than income State gross receipts $ 113 $ 100 $ 107 Domestic - other 94 80 79 Total $ 207 $ 180 $ 186 (PPL Electric) The provision for PPL Electric's deferred income taxes for regulated assets and liabilities is based upon the ratemaking principles reflected in rates established by the PUC and the FERC. The difference in the provision for deferred income taxes for regulated assets and liabilities and the amount that otherwise would be recorded under GAAP is deferred and included in "Regulatory assets" or "Regulatory liabilities" on the Balance Sheets. Significant components of PPL Electric's deferred income tax assets and liabilities were as follows: 2021 2020 Deferred Tax Assets Accrued pension and postretirement costs $ 14 $ 25 Contributions in aid of construction 95 91 Regulatory liabilities 52 24 Income taxes due to customers 154 162 Federal loss carryforwards (a) — 52 Other 21 29 Total deferred tax assets 336 383 Deferred Tax Liabilities Electric utility plant - net 1,891 1,826 Regulatory assets 74 86 Other 39 30 Total deferred tax liabilities 2,004 1,942 Net deferred tax liability $ 1,668 $ 1,559 (a) PPL Electric utilized their remaining federal net operating losses and recorded the related deferred tax assets to current expense in June 2021 as a result of the completion of the sale of the U.K. utility business on June 14, 2021. PPL Electric expects to have adequate levels of taxable income to realize its recorded deferred income tax assets. Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows: 2021 2020 2019 Income Tax Expense (Benefit) Current - Federal $ 40 $ 61 $ 44 Current - State 35 23 15 Total Current Expense (Benefit) 75 84 59 Deferred - Federal 59 45 51 Deferred - State 20 38 39 Total Deferred Expense (Benefit), excluding operating loss carryforwards 79 83 90 Total income tax expense (benefit) $ 154 $ 167 $ 149 Total income tax expense (benefit) - Federal $ 99 $ 106 $ 95 Total income tax expense (benefit) - State 55 61 54 Total income tax expense (benefit) $ 154 $ 167 $ 149 2021 2020 2019 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 126 $ 139 $ 127 Increase (decrease) due to: State income taxes, net of federal income tax benefit 46 52 47 Federal and state income tax return adjustments — (4) 1 Depreciation and other items not normalized (5) (5) (10) Amortization of excess deferred federal income taxes (a) (14) (16) (18) Other 1 1 2 Total increase (decrease) 28 28 22 Total income tax expense (benefit) $ 154 $ 167 $ 149 Effective income tax rate 25.7% 25.2% 24.6% (a) In 2021, 2020 and 2019, PPL Electric recorded lower income tax expense for the amortization of excess deferred taxes that primarily resulted from the U.S. federal corporate income tax rate reduction from 35% to 21% enacted by the TCJA. This amortization represents each year's refund amount, prior to a tax gross-up, to be paid to customers for previously collected deferred taxes at higher income tax rates. 2021 2020 2019 Taxes, other than income State gross receipts $ 113 $ 100 $ 107 Property and other 7 7 5 Total $ 120 $ 107 $ 112 (LG&E) The provision for LG&E's deferred income taxes for regulated assets and liabilities is based upon the ratemaking principles reflected in rates established by the KPSC and the FERC. The difference in the provision for deferred income taxes for regulated assets and liabilities and the amount that otherwise would be recorded under GAAP is deferred and included in "Regulatory assets" or "Regulatory liabilities" on the Balance Sheets. Significant components of LG&E's deferred income tax assets and liabilities were as follows: 2021 2020 Deferred Tax Assets Contributions in aid of construction $ 15 $ 15 Regulatory liabilities 18 20 Deferred investment tax credits 8 8 Income taxes due to customers 125 132 State tax credit carryforwards 11 12 Lease liabilities 4 5 Valuation allowances (11) (12) Other 11 11 Total deferred tax assets 181 191 Deferred Tax Liabilities Plant - net 854 833 Regulatory assets 65 66 Lease right-of-use assets 4 4 Other 9 4 Total deferred tax liabilities 932 907 Net deferred tax liability $ 751 $ 716 At December 31, 2021 LG&E had $11 million of state credit carryforwards that expire in 2028 and an $11 million valuation allowance related to state credit carryforwards due to insufficient projected Kentucky taxable income. Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were: 2021 2020 2019 Income Tax Expense (Benefit) Current - Federal $ 41 $ 53 $ 4 Current - State 5 7 4 Total Current Expense (Benefit) 46 60 8 Deferred - Federal 1 (4) 46 Deferred - State 8 7 10 Total Deferred Expense (Benefit) 9 3 56 Amortization of investment tax credit - Federal (1) (1) (1) Total income tax expense (benefit) $ 54 $ 62 $ 63 Total income tax expense (benefit) - Federal $ 41 $ 48 $ 49 Total income tax expense (benefit) - State 13 14 14 Total income tax expense (benefit) $ 54 $ 62 $ 63 2021 2020 2019 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 64 $ 64 $ 62 Increase (decrease) due to: State income taxes, net of federal income tax benefit 12 12 12 Amortization of excess deferred federal and state income taxes (20) (11) (10) Kentucky recycling credit, net of federal income tax expense (a) — — (14) Valuation allowance adjustments (a) — — 14 Other (2) (3) (1) Total increase (decrease) (10) (2) 1 Total income tax expense (benefit) $ 54 $ 62 $ 63 Effective income tax rate 17.8% 20.3% 21.4% (a) In 2019, LG&E recorded a deferred income tax benefit associated with two projects placed into service that prepare a generation waste material for reuse and, as a result, qualify for a Kentucky recycling credit. The applicable credit provides tax benefits for a portion of the equipment costs for major recycling projects in Kentucky. This amount has been reserved due to insufficient Kentucky taxable income projected at LG&E. 2021 2020 2019 Taxes, other than income Property and other $ 46 $ 40 $ 39 Total $ 46 $ 40 $ 39 (KU) The provision for KU's deferred income taxes for regulated assets and liabilities is based upon the ratemaking principles reflected in rates established by the KPSC, VSCC and the FERC. The difference in the provision for deferred income taxes for regulated assets and liabilities and the amount that otherwise would be recorded under GAAP is deferred and included in "Regulatory assets" or "Regulatory liabilities" on the Balance Sheets. Significant components of KU's deferred income tax assets and liabilities were as follows: 2021 2020 Deferred Tax Assets Contributions in aid of construction $ 9 $ 8 Regulatory liabilities 23 23 Deferred investment tax credits 22 22 Income taxes due to customers 143 150 State tax credit carryforwards 4 5 Lease liabilities 7 8 Valuation allowances (3) (4) Other 4 4 Total deferred tax assets 209 216 Deferred Tax Liabilities Plant - net 1,012 992 Regulatory assets 41 43 Pension and postretirement costs 13 8 Lease right-of-use assets 6 7 Other 2 1 Total deferred tax liabilities 1,074 1,051 Net deferred tax liability $ 865 $ 835 At December 31, 2021 KU had $4 million of state credit carryforwards of which $3 million will expire in 2028 and $1 million that has an indefinite carryforward period. At December 31, 2021 KU had a $3 million valuation allowance related to state credit carryforwards due to insufficient projected Kentucky taxable income. Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were: 2021 2020 2019 Income Tax Expense (Benefit) Current - Federal $ 58 $ 40 $ 35 Current - State 8 3 5 Total Current Expense (Benefit) 66 43 40 Deferred - Federal (4) 11 28 Deferred - State 7 11 13 Total Deferred Expense (Benefit) 3 22 41 Amortization of investment tax credit - Federal (2) (2) (2) Total income tax expense (benefit) $ 67 $ 63 $ 79 Total income tax expense (benefit) - Federal $ 52 $ 49 $ 61 Total income tax expense (benefit) - State 15 14 18 Total income tax expense (benefit) $ 67 $ 63 $ 79 2021 2020 2019 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 76 $ 72 $ 78 Increase (decrease) due to: State income taxes, net of federal income tax benefit 14 14 15 Amortization of investment tax credit (2) (2) (2) Amortization of excess deferred federal and state income taxes (20) (17) (13) Kentucky recycling credit, net of federal income tax expense (a) — — (4) Valuation allowance adjustments (a) — — 4 Other (1) (4) 1 Total increase (decrease) (9) (9) 1 Total income tax expense (benefit) $ 67 $ 63 $ 79 Effective income tax rate 18.4% 18.4% 21.2% (a) In 2019, KU recorded a deferred income tax benefit associated with a project placed into service that prepare a generation waste material for reuse and, as a result, qualify for a Kentucky recycling credit. The applicable credit provides tax benefits for a portion of the equipment costs for major recycling projects in Kentucky. This amount has been reserved due to insufficient Kentucky taxable income projected at KU. 2021 2020 2019 Taxes, other than income Property and other $ 41 $ 37 $ 35 Total $ 41 $ 37 $ 35 (All Registrants) Unrecognized Tax Benefits PPL or its subsidiaries file tax returns in four major tax jurisdictions. The income tax provisions for PPL Electric, LG&E and KU are calculated in accordance with an intercompany tax sharing agreement, which provides that taxable income be calculated as if each domestic subsidiary filed a separate consolidated return. PPL Electric or its subsidiaries indirectly or directly file tax returns in two major tax jurisdictions, and LG&E and KU indirectly or directly file tax returns in two major tax jurisdictions. With few exceptions, at December 31, 2021, these jurisdictions, as well as the tax years that are no longer subject to examination, were as follows. PPL PPL Electric LG&E KU U.S. (federal) 2017 and prior 2017 and prior 2017 and prior 2017 and prior Pennsylvania (state) 2017 and prior 2017 and prior Kentucky (state) 2014 and prior 2014 and prior 2014 and prior U.K. (foreign) 2019 and prior

Utility Rate Regulation

Utility Rate Regulation	12 Months Ended
	Dec. 31, 2021
Utility Rate Regulation [Line Items]
Utility Rate Regulation	7. Utility Rate Regulation Regulatory Assets and Liabilities (All Registrants) PPL, PPL Electric, LG&E and KU reflect the effects of regulatory actions in the financial statements for their cost-based rate-regulated utility operations. Regulatory assets and liabilities are classified as current if, upon initial recognition, the entire amount related to an item will be recovered or refunded within a year of the balance sheet date. (PPL, LG&E and KU) LG&E is subject to the jurisdiction of the KPSC and FERC, and KU is subject to the jurisdiction of the KPSC, FERC and VSCC. LG&E's and KU's Kentucky base rates are calculated based on recovery of costs as well as a return on capitalization (common equity, long-term debt and short-term debt) including adjustments for certain net investments and costs recovered separately through other means. As such, LG&E and KU generally earn a return on regulatory assets. (PPL and KU) KU's Virginia base rates are calculated based on recovery of costs as well as a return on rate base (net utility plant plus working capital less accumulated deferred income taxes and miscellaneous deductions). As all regulatory assets and liabilities, except for regulatory assets and liabilities related to the levelized fuel factor, accumulated deferred income taxes, pension and postretirement benefits, and AROs related to certain CCR impoundments, are excluded from the return on rate base utilized in the calculation of Virginia base rates, no return is earned on the related assets. KU's rates to municipal customers for wholesale power requirements are calculated based on annual updates to a formula rate that utilizes a return on rate base (net utility plant plus working capital less accumulated deferred income taxes and miscellaneous deductions). As all regulatory assets and liabilities, except accumulated deferred income taxes, are excluded from the return on rate base utilized in the development of municipal rates, no return is earned on the related assets. (PPL and PPL Electric) PPL Electric's distribution base rates are calculated based on recovery of costs as well as a return on distribution rate base (net utility plant plus a working capital allowance less plant-related deferred taxes and other miscellaneous additions and deductions). PPL Electric's transmission revenues are billed in accordance with a FERC tariff that allows for recovery of transmission costs incurred, a return on transmission-related rate base (net utility plant plus a working capital allowance less plant-related deferred taxes and other miscellaneous additions and deductions) and an automatic annual update. See "Transmission Formula Rate" below for additional information on this tariff. All regulatory assets and liabilities are excluded from distribution and transmission return on investment calculations; therefore, generally no return is earned on PPL Electric's regulatory assets. (All Registrants) The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations at December 31: PPL PPL Electric 2021 2020 2021 2020 Current Regulatory Assets: Plant outage costs $ — $ 46 $ — $ — Gas supply clause 21 4 — — Smart meter rider 11 17 11 17 Transmission formula rate 6 15 6 15 Storm costs — 7 — 7 Fuel adjustment clause 11 — — — Other 15 10 5 1 Total current regulatory assets (a) $ 64 $ 99 $ 22 $ 40 Noncurrent Regulatory Assets: Defined benefit plans $ 523 $ 570 $ 256 $ 290 Plant outage cost 54 — — — Storm costs 11 17 — — Unamortized loss on debt 24 30 4 8 Interest rate swaps 18 23 — — Terminated interest rate swaps 70 75 — — Accumulated cost of removal of utility plant 228 240 228 240 AROs 302 300 — — Other 6 7 — 3 Total noncurrent regulatory assets $ 1,236 $ 1,262 $ 488 $ 541 PPL PPL Electric 2021 2020 2021 2020 Current Regulatory Liabilities: Generation supply charge $ 10 $ 21 $ 10 $ 21 Transmission service charge 21 1 21 1 Universal service rider 17 22 17 22 TCJA customer refund 22 11 22 11 Act 129 compliance rider 10 7 10 7 Transmission formula rate return on equity (b) 73 — 73 — Economic relief billing rate 27 — — — Other 2 17 — 6 Total current regulatory liabilities $ 182 $ 79 $ 153 $ 68 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 639 $ 653 $ — $ — Power purchase agreement - OVEC 35 43 — — Net deferred taxes 1,591 1,690 531 560 Defined benefit plans 95 60 28 18 Terminated interest rate swaps 62 66 — — Other — 18 — — Total noncurrent regulatory liabilities $ 2,422 $ 2,530 $ 559 $ 578 LG&E KU 2021 2020 2021 2020 Current Regulatory Assets: Gas supply clause $ 21 $ 4 $ — $ — Fuel adjustment clause 4 — 7 — Gas line tracker 3 4 — — Generation formula rate — — 2 2 Plant outage costs — 12 — 34 Other 5 3 — — Total current regulatory assets $ 33 $ 23 $ 9 $ 36 Noncurrent Regulatory Assets: Defined benefit plans $ 164 $ 174 $ 103 $ 106 Storm costs 8 11 3 6 Unamortized loss on debt 12 13 8 9 Interest rate swaps 18 23 — — Terminated interest rate swaps 41 44 29 31 AROs 75 85 227 215 Plant outage costs 15 — 39 — Other 4 1 2 3 Total noncurrent regulatory assets $ 337 $ 351 $ 411 $ 370 LG&E KU 2021 2020 2021 2020 Current Regulatory Liabilities: Economic relief billing credit $ 21 $ — $ 6 $ — Fuel adjustment clauses — — — 5 Environmental cost recovery — — — 4 Other — — 2 2 Total current regulatory liabilities $ 21 $ — $ 8 $ 11 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 262 $ 274 $ 377 $ 379 Power purchase agreement - OVEC 24 30 11 13 Net deferred taxes 491 528 569 602 Defined benefit plans 10 — 57 42 Terminated interest rate swaps 31 33 31 33 Other — 17 — 1 Total noncurrent regulatory liabilities $ 818 $ 882 $ 1,045 $ 1,070 (a) For PPL, these amounts are included in "Other current assets" on the Balance Sheets. (b) See “Regulatory Matters - Federal Matters - PPL Electric Transmission Formula Rate Return on Equity” below for additional information. Following is an overview of selected regulatory assets and liabilities detailed in the preceding tables. Specific developments with respect to certain of these regulatory assets and liabilities are discussed in "Regulatory Matters." Defined Benefit Plans (All Registrants) Defined benefit plan regulatory assets and liabilities represent prior service cost and net actuarial gains and losses that will be recovered in defined benefit plans expense through future base rates based upon established regulatory practices and, generally, are amortized over the average remaining service lives of plan participants. These regulatory assets and liabilities are adjusted at least annually or whenever the funded status of defined benefit plans is remeasured. (PPL, LG&E and KU) As a result of previous rate case settlements and orders, the difference between pension cost calculated in accordance with LG&E's and KU's pension accounting policy and pension cost calculated using a 15-year amortization period for actuarial gains and losses and settlements are recorded as a regulatory asset. As of December 31, 2021, the balances were $98 million for PPL, $54 million for LG&E and $44 million for KU. As of December 31, 2020, the balances were $79 million for PPL, $44 million for LG&E and $35 million for KU. (All Registrants) Storm Costs PPL Electric, LG&E and KU have the ability to request from the PUC, KPSC and VSCC, as applicable, the authority to treat expenses related to specific extraordinary storms as a regulatory asset and defer such costs for regulatory accounting and reporting purposes. Once such authority is granted, LG&E and KU can request recovery of those expenses in a base rate case and begin amortizing the costs when recovery starts. PPL Electric can recover qualifying expenses caused by major storm events, as defined in its retail tariff, over three years through the Storm Damage Expense Rider commencing in the application year after the storm occurred. Storm costs incurred in PPL Electric's territory from a March 2018 storm were amortized through 2021. LG&E's and KU's regulatory assets for storm costs are being amortized through various dates ending in 2031. Unamortized Loss on Debt Unamortized loss on reacquired debt represents losses on long-term debt refinanced, reacquired or redeemed that have been deferred and will be amortized and recovered over either the original life of the extinguished debt or the life of the replacement debt (in the case of refinancing). Such costs are being amortized through 2029 for PPL Electric, through 2042 for KU, and through 2044 for LG&E. Accumulated Cost of Removal of Utility Plant LG&E and KU charge costs of removal through depreciation expense with an offsetting credit to a regulatory liability. The regulatory liability is relieved as costs are incurred. PPL Electric does not accrue for costs of removal. When costs of removal are incurred, PPL Electric records the costs as a regulatory asset. Such deferral is included in rates and amortized over the subsequent five Net Deferred Taxes Regulatory liabilities associated with net deferred taxes represent the future revenue impact from the adjustment of deferred income taxes required primarily for excess deferred taxes and unamortized investment tax credits, largely a result of the TCJA enacted in 2017. (PPL and PPL Electric) Generation Supply Charge (GSC) The GSC is a cost recovery mechanism that permits PPL Electric to recover costs incurred to provide generation supply to PLR customers who receive basic generation supply service. The recovery includes charges for generation supply, as well as administration of the acquisition process. In addition, the GSC contains a reconciliation mechanism whereby any over- or under-recovery from prior periods is refunded to, or recovered from, customers through the adjustment factor determined for the subsequent rate filing period. Transmission Service Charge (TSC) PPL Electric is charged by PJM for transmission service-related costs applicable to its PLR customers. PPL Electric passes these costs on to customers, who receive basic generation supply service through the PUC-approved TSC cost recovery mechanism. The TSC contains a reconciliation mechanism whereby any over- or under-recovery from customers is either refunded to, or recovered from, customers through the adjustment factor determined for the subsequent year. Transmission Formula Rate PPL Electric's transmission revenues are billed in accordance with a FERC-approved Open Access Transmission Tariff that utilizes a formula-based rate recovery mechanism. Under this formula, rates are put into effect in June of each year based upon prior year actual expenditures and current year forecasted capital additions. Rates are then adjusted the following year to reflect actual annual expenses and capital additions, as reported in PPL Electric's annual FERC Form 1, filed under the FERC's Uniform System of Accounts. Any difference between the revenue requirement in effect for the prior year and actual expenditures incurred for that year is recorded as a regulatory asset or regulatory liability. Storm Damage Expense Rider (SDER) The SDER is a reconcilable automatic adjustment clause under which PPL Electric annually will compare actual storm costs to storm costs allowed in base rates and refund or recover any differences from customers. In the 2015 rate case settlement approved by the PUC in November 2015, it was determined that reportable storm damage expenses to be recovered annually through base rates will be set at $20 million. The SDER will recover from or refund to customers the applicable expenses from reportable storms as compared to the $20 million recovered annually through base rates. Act 129 Compliance Rider In compliance with Pennsylvania's Act 129 of 2008 and implementing regulations, PPL Electric is currently in Phase IV of the energy efficiency and conservation plan which was approved in March 2021. Phase IV allows PPL Electric to recover the maximum $313 million over the five Smart Meter Rider (SMR) Act 129 requires each electric distribution company (EDC) with more than 100,000 customers to have a PUC approved Smart Meter Technology Procurement and Installation Plan (SMP). As of December 31, 2019, PPL Electric replaced substantially all of its old meters with meters that meet the Act 129 requirements under its SMP. In accordance with Act 129, EDCs are able to recover the costs and earn a return on capital of providing smart metering technology. PPL Electric uses the SMR to recover the costs to implement its SMP. The SMR is a reconciliation mechanism whereby any over- or under-recovery from prior years is refunded to, or recovered from, customers through the adjustment factor determined for the subsequent quarters. Universal Service Rider (USR) The USR provides for recovery of costs associated with universal service programs, OnTrack and Winter Relief Assistance Program (WRAP), provided by PPL Electric to residential customers. OnTrack is a special payment program for low-income households and WRAP provides low-income customers a means to reduce electric bills through energy saving methods. The USR rate is applied to residential customers who receive distribution service. The actual program costs are reconcilable, and any over- or under-recovery from customers will be refunded or recovered annually in the subsequent year. TCJA Customer Refund As a result of the reduced U.S federal corporate income tax rate as enacted by the TCJA, the PUC ruled that these tax benefits should be refunded to customers. Timing differences between the recognition of these tax benefits and the refund of the benefit to the customer creates a regulatory liability. PPL Electric's liability is being credited back to distribution customers through a temporary negative surcharge and remains in place until PPL Electric files and the PUC approves new base rates. The TCJA is reconcilable, and any over- or under-recovery from customers will be refunded or recovered annually in the subsequent year. (PPL, LG&E and KU) Environmental Cost Recovery Kentucky law permits LG&E and KU to recover the costs, including a return of operating expenses and a return of and on capital invested, of complying with the Clean Air Act and those federal, state or local environmental requirements, which apply to coal combustion wastes and by-products from coal-fired electricity generating facilities. The KPSC requires reviews of the past operations of the environmental surcharge for six-month and two-year billing periods to evaluate the related charges, credits and rates of return, as well as to provide for the roll-in of ECR amounts to base rates each two-year period. The KPSC has authorized return on equity of 9.35% for existing approved ECR projects. The ECR regulatory asset or liability represents the amount that has been under- or over-recovered due to timing or adjustments to the mechanism and is typically recovered or refunded within 12 months. Fuel Adjustment Clauses LG&E's and KU's retail electric rates contain a fuel adjustment clause, whereby variances in power purchases and the cost of fuel to generate electricity, including transportation costs, from the costs embedded in base rates are adjusted in LG&E's and KU's rates. The KPSC requires formal reviews at six-month intervals to examine past fuel adjustments and at two-year intervals to review past operations of the fuel adjustment clause and, to the extent appropriate, may conduct public hearings and reestablish the fuel charge included in base rates. The regulatory assets or liabilities represent the amounts that have been under- or over-recovered due to timing or adjustments to the mechanism and are typically recovered within 12 months. KU also employs a levelized fuel factor mechanism for Virginia customers using an average fuel cost factor based primarily on projected fuel costs and load for the fuel year (12 months ending March 31). The Virginia levelized fuel factor allows fuel recovery based on projected fuel costs for the fuel year plus an adjustment for any under- or over-recovery of fuel expenses from the prior fuel year. The regulatory assets or liabilities represent the amounts that have been under- or over-recovered due to timing or adjustments to the mechanism and are typically recovered or refunded within 12 months. Economic Relief Billing Credit The Economic Relief Billing Credit represents regulatory liabilities to be returned to customers through June 30, 2022, as agreed to in the Kentucky rate case in recognition of the economic impact of COVID-19. See "Regulatory Matters - Kentucky Activities - Rate Case Proceedings" below for additional information . AROs As discussed in Note 1, for LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, deferred accretion and depreciation expense is recovered through cost of removal. Power Purchase Agreement - OVEC As a result of purchase accounting associated with PPL's acquisition of LG&E and KU, the fair values of the OVEC power purchase agreement were recorded on the balance sheets of LG&E and KU with offsets to regulatory liabilities. The regulatory liabilities are being amortized using the units-of-production method until March 2026, the expiration date of the agreement at the date of the acquisition. LG&E's and KU's customer rates continue to reflect the original contracts. See Notes 14 and 19 for additional discussion of the power purchase agreement. Interest Rate Swaps LG&E's unrealized gains and losses are recorded as regulatory assets or regulatory liabilities until they are realized as interest expense. Interest expense from existing swaps is realized and recovered over the terms of the associated debt, which matures in 2033. Terminated Interest Rate Swaps Net realized gains and losses on all interest rate swaps are recovered through regulated rates. As such, any gains and losses on these derivatives are included in regulatory assets or liabilities and are primarily recognized in "Interest Expense" on the Statements of Income over the life of the associated debt. Plant Outage Costs From July 1, 2017 through June 30, 2021, plant outage costs in Kentucky were normalized for ratemaking purposes based on an average level of expenses. Plant outage expenses that were greater or less than the average will be collected from or returned to customers, through future base rates. Effective July 1, 2021 under-recovered plant outage costs are being amortized through 2029 for LG&E and KU. Gas Supply Clause (PPL and LG&E) LG&E's natural gas rates contain a gas supply clause, whereby the expected cost of natural gas supply and variances between actual and expected costs and customer usage from prior periods are adjusted quarterly in LG&E's rates, subject to approval by the KPSC. The gas supply clause also includes a separate natural gas procurement incentive mechanism, which allows LG&E's rates to be adjusted annually to share savings between the actual cost of gas purchases and market indices, with the shareholders and the customers during each performance-based rate year (12 months ending October 31). The regulatory assets or liabilities represent the total amounts that have been under- or over-recovered due to timing or adjustments to the mechanisms and are typically recovered or refunded within 18 months. Regulatory Matters Kentucky Activities (PPL, LG&E and KU) Rate Case Proceedings On November 25, 2020, LG&E and KU filed requests with the KPSC for an increase in annual electricity and gas revenues of approximately $331 million ($131 million and $170 million in electricity revenues at LG&E and KU and $30 million in gas revenues at LG&E). The revenue increases represented an increase of 11.6% and 10.4% in electricity revenues at LG&E and KU, and an increase of 8.3% in gas revenues at LG&E. In recognition of the economic impact of COVID-19, LG&E and KU requested approval of a one-year billing credit which will credit customers approximately $53 million ($41 million at LG&E and $12 million at KU). The billing credit represents the return to customers of certain regulatory liabilities on LG&E’s and KU’s Balance Sheets and serves to partially mitigate the rate increases during the first year in which the new rates are in effect. LG&E’s and KU’s applications also included a request for a CPCN to deploy Advanced Metering Infrastructure across LG&E’s and KU’s service territories in Kentucky. The applications were based on a forecasted test year of July 1, 2021 through June 30, 2022 and requested an authorized return on equity of 10.0%. On April 19, 2021, LG&E and KU entered into an agreement with all intervening parties to the proceedings resolving all matters in their applications, with the explicit exception of LG&E's and KU's net metering proposals. On June 30, 2021 and December 6, 2021, the KPSC issued orders approving the proposed agreement filed in April 2021, with certain modifications. The orders provided for increases in annual revenues of $207 million ($74 million and $110 million in electricity revenues at LG&E and KU and $23 million in gas revenues at LG&E) based on an authorized return on equity of 9.425%. The orders grant an authorized 9.35% return on equity for the ECR and GLT mechanisms and do not modify the requested one-year billing credit. The orders approved the CPCN to deploy Advanced Metering Infrastructure and provide regulatory asset treatment for the remaining net book value of legacy meters upon full implementation of the Advanced Metering Infrastructure program. The orders also approved the establishment of a Retired Asset Recovery (RAR) rider to provide for recovery of and return on the remaining investment in certain electric generating units upon their retirement over a ten-year period following retirement. In respect of the RAR rider, LG&E and KU continue to use currently approved depreciation rates for Mill Creek Units 1 and 2 and Brown Unit 3. The orders also approved a four-year "stay out" commitment from LG&E and KU to refrain from effective base rate increases before July 1, 2025, subject to certain exceptions. On September 24, 2021, the KPSC issued orders providing adjustments to previous net metering proposals. These adjustments did not impact the annual revenue increases. Pennsylvania Activities (PPL and PPL Electric) Act 129 Act 129 requires Pennsylvania Electric Distribution Companies (EDCs) to meet, by specified dates, specified goals for reduction in customer electricity usage and peak demand. EDCs not meeting the requirements of Act 129 are subject to significant penalties. PPL Electric filed with the PUC its Act 129 Phase IV Energy Efficiency and Conservation Plan on November 30, 2020, for the five-year period starting June 1, 2021 and ending on May 31, 2026. PPL Electric's Phase IV Act 129 Plan was approved by the PUC at its March 25, 2021, public meeting. Act 129 also requires EDCs to act as a default service provider (DSP), which provides electricity generation supply service to customers pursuant to a PUC-approved default service procurement plan. A DSP is able to recover the costs associated with its default service procurement plan. Federal Matters PPL Electric Transmission Formula Rate Return on Equity (PPL and PPL Electric) On May 21, 2020, PP&L Industrial Customer Alliance (PPLICA) filed a complaint with the FERC alleging that PPL Electric's base return on equity (ROE) of 11.18% used to determine PPL Electric's formula transmission rate was unjust and unreasonable. On August 20, 2021, PPL Electric entered into a settlement agreement (the Settlement) with PPLICA and all other parties, including intervenors, with respect to the complaint filed by PPLICA on May 21, 2020. The key aspects of the Settlement include: • changes to PPL Electric’s base ROE: ◦ beginning as of May 21, 2020 and continuing through May 31, 2022, the ROE shall be 9.90%; ◦ beginning on June 1, 2022 and continuing through May 31, 2023, the ROE shall be 9.95%; ◦ beginning on June 1, 2023, the ROE shall be 10.00%, which shall continue in effect unless and until changed as permitted by the terms of the Settlement; • changes the equity component of PPL Electric’s capital structure to be the lower of (i) PPL Electric’s actual equity component, calculated in accordance with the formula rate template, or (ii) 56.00%; • allows modification of the current rate year of June 1 to May 31 to a calendar year of January 1 to December 31; and • allows modification of the current formula rate based on a historic test year to a projected test year. In 2021, PPL Electric recorded a revenue reduction of $78 million ($55 million after-tax), of which $73 million ($52 million after-tax) represents revenue subject to refund for the period May 21, 2020 through November 30, 2021. The reduction recorded includes $28 million ($20 million after-tax) related to the period from May 21, 2020 to December 31, 2020. The $73 million of revenue to be refunded will be returned to customers from January 1, 2022 through May 31, 2022 and is based on the difference between charges that were calculated using the ROE in effect at the time and charges calculated using the revised ROE provided for the Settlement, plus interest at the FERC interest rate. The FERC approved the Settlement on November 5, 2021. Interim rates reflecting the agreed-to-base ROE in the Settlement were effective December 1, 2021. (PPL, LG&E and KU) FERC Transmission Rate Filing In 2018, LG&E and KU applied to the FERC requesting elimination of certain on-going credits to a sub-set of transmission customers relating to the 1998 merger of LG&E's and KU's parent entities and the 2006 withdrawal of LG&E and KU from the Midcontinent Independent System Operator, Inc. (MISO), a regional transmission operator and energy market. The application sought termination of LG&E's and KU's commitment to provide certain Kentucky municipalities mitigation for certain horizontal market power concerns arising out of the 1998 LG&E and KU merger and 2006 MISO withdrawal. The amounts at issue are generally waivers or credits granted to a limited number of Kentucky municipalities for either certain LG&E and KU or MISO transmission charges incurred for transmission service received. In 2019, the FERC granted LG&E's and KU's request to remove the ongoing credits, conditioned upon the implementation by LG&E and KU of a transition mechanism for certain existing power supply arrangements, which was subsequently filed, modified, and approved by the FERC in 2020 and 2021. In 2020, LG&E and KU and other parties filed appeals with the D.C. Circuit Court of Appeals regarding FERC's orders on the elimination of the mitigation and required transition mechanism. Oral arguments in the appellate proceeding occurred on February 14, 2022. LG&E and KU cannot predict the outcome of the respective appellate and FERC proceedings. LG&E and KU currently receive recovery of the waivers and credits provided through other rate mechanisms and such rate recovery would be anticipated to be adjusted consistent with potential changes or terminations of the waivers and credits, as such become effective. Other Purchase of Receivables Program (PPL and PPL Electric) In accordance with a PUC-approved purchase of accounts receivable program, PPL Electric purchases certain accounts receivable from alternative electricity suppliers at a discount, which reflects a provision for uncollectible accounts. The alternative electricity suppliers have no continuing involvement or interest in the purchased accounts receivable. Accounts receivable that are acquired are initially recorded at fair value on the date of acquisition. During 2021, 2020 and 2019, PPL Electric purchased $1.2 billion, $1.1 billion and $1.2 billion of accounts receivable from alternative suppliers.

Financing Activities

Financing Activities	12 Months Ended
	Dec. 31, 2021
Debt Disclosure [Abstract]
Financing Activities	Credit Arrangements and Short-term Debt (All Registrants) The Registrants maintain credit facilities to enhance liquidity, provide credit support and provide a backstop to commercial paper programs. For reporting purposes, on a consolidated basis, the credit facilities and commercial paper programs of PPL Electric, LG&E and KU also apply to PPL. The amounts listed in the borrowed column below are recorded as "Short-term debt" on the Balance Sheets except for borrowings under PPL Capital Funding's term loan agreement due March 2022, which are reflected in "Long-term debt" at December 31, 2020. The following credit facilities were in place at: December 31, 2021 December 31, 2020 Expiration Capacity Borrowed Letters of Unused Capacity Borrowed Letters of PPL PPL Capital Funding Syndicated Credit Facility (a) (b) Dec 2026 $ 1,250 $ — $ — $ 1,250 $ — $ 402 Bilateral Credit Facility (a) (b) Mar 2022 50 — — 50 — — Bilateral Credit Facility (a) (b) Mar 2022 50 — 15 35 — 15 Term Loan Credit Facility (a) (b) Mar 2021 — — — — 200 — Term Loan Credit Facility (a) (b) Mar 2021 — — — — 100 — Term Loan Credit Facility (a) (b) Mar 2022 — — — — 100 — Total PPL Capital Funding Credit Facilities $ 1,350 $ — $ 15 $ 1,335 $ 400 $ 417 PPL Electric Syndicated Credit Facility (a) (b) Dec 2026 $ 650 $ — $ 1 $ 649 $ — $ 1 LG&E Syndicated Credit Facility (a) (b) Dec 2026 $ 500 $ — $ 69 $ 431 $ — $ 262 KU Syndicated Credit Facility (a) (b) Dec 2026 $ 400 $ — $ — $ 400 $ — $ 203 (a) Each company pays customary fees under its respective facility and borrowings generally bear interest at LIBOR-based rates plus an applicable margin. (b) The facilities contain a financial covenant requiring debt to total capitalization not to exceed 70% for PPL Capital Funding, PPL Electric, LG&E and KU, as calculated in accordance with the facilities and other customary covenants. Additionally, subject to certain conditions, PPL Capital Funding may request that the capacity of one of its bilateral credit facilities expiring in March 2022 be increased by up to $30 million and PPL Capital Funding, PPL Electric, LG&E and KU may each request up to a $250 million increase in its syndicated credit facility's capacity. Participation in any such increase is at the sole discretion of each lender. (PPL) In December 2021, PPL Capital Funding amended and restated its existing $1.450 billion revolving credit facility to extend the termination date from January 26, 2024 to December 6, 2026, to decrease the borrowing capacity to $1.250 billion and to provide for the option to add Narragansett Electric as an additional borrower upon acquisition by PPL Rhode Island Holdings, LLC. (PPL and PPL Electric) In December 2021, PPL Electric Utilities Corporation amended and restated its existing $650 million revolving credit facility to extend the termination date from January 26, 2024 to December 6, 2026. (PPL and LG&E) In December 2021, LG&E amended and restated its existing $500 million revolving credit facility to extend the termination date from January 26, 2024 to December 6, 2026. (PPL and KU) In December 2021, KU amended and restated its existing $400 million revolving credit facility to extend the termination date from January 26, 2024 to December 6, 2026. (All Registrants) PPL, PPL Electric, LG&E and KU maintain commercial paper programs to provide an additional financing source to fund short-term liquidity needs. Commercial paper issuances, included in "Short-term debt" on the Balance Sheets, are supported by the respective Registrant's credit facilities. The following commercial paper programs were in place at: December 31, 2021 December 31, 2020 Weighted - Capacity Commercial Unused Weighted - Commercial PPL Capital Funding $ 1,500 $ — $ 1,500 0.25% $ 402 PPL Electric 650 — 650 — LG&E (a) 0.31% 425 69 356 0.28% 262 KU 350 — 350 0.28% 203 Total $ 2,925 $ 69 $ 2,856 $ 867 (a) In March 2021, the capacity for the LG&E commercial paper program was increased from $350 million to $425 million. (PPL Electric, LG&E and KU) See Note 15 for a discussion of intercompany borrowings. Long-term Debt (All Registrants) December 31, Weighted-Average Maturities (d) 2021 2020 PPL Senior Unsecured Notes 3.81 % 2026 - 2047 $ 1,566 $ 4,850 Senior Secured Notes/First Mortgage Bonds (a) (b) (c) 3.59 % 2022 - 2050 9,205 8,955 Junior Subordinated Notes 2.89 % 2067 480 930 Term Loan Credit Facility — 100 Total Long-term Debt before adjustments 11,251 14,835 Unamortized premium and (discount), net (34) (40) Unamortized debt issuance costs (77) (106) Total Long-term Debt 11,140 14,689 Less current portion of Long-term Debt 474 1,074 Total Long-term Debt, noncurrent $ 10,666 $ 13,615 December 31, Weighted-Average Maturities (d) 2021 2020 PPL Electric Senior Secured Notes/First Mortgage Bonds (a) (b) 3.37 % 2022 - 2049 $ 4,539 $ 4,289 Total Long-term Debt Before Adjustments 4,539 4,289 Unamortized discount (22) (23) Unamortized debt issuance costs (33) (30) Total Long-term Debt 4,484 4,236 Less current portion of Long-term Debt 474 400 Total Long-term Debt, noncurrent $ 4,010 $ 3,836 LG&E First Mortgage Bonds (a) (c) 3.59 % 2025 - 2049 $ 2,024 $ 2,024 Total Long-term Debt Before Adjustments 2,024 2,024 Unamortized discount (4) (4) Unamortized debt issuance costs (14) (13) Total Long-term Debt 2,006 2,007 Less current portion of Long-term Debt — 292 Total Long-term Debt, noncurrent $ 2,006 $ 1,715 KU First Mortgage Bonds (a) (c) 3.97 % 2023 - 2050 $ 2,642 $ 2,642 Total Long-term Debt Before Adjustments 2,642 2,642 Unamortized premium 5 5 Unamortized discount (9) (9) Unamortized debt issuance costs (20) (20) Total Long-term Debt 2,618 2,618 Less current portion of Long-term Debt — 132 Total Long-term Debt, noncurrent $ 2,618 $ 2,486 (a) Includes PPL Electric's senior secured and first mortgage bonds that are secured by the lien of PPL Electric's 2001 Mortgage Indenture, which covers substantially all of PPL Electric’s tangible distribution properties and certain of its tangible transmission properties located in Pennsylvania, subject to certain exceptions and exclusions. The carrying value of PPL Electric's property, plant and equipment was approximately $11.3 billion and $10.8 billion at December 31, 2021 and 2020. Includes LG&E's first mortgage bonds that are secured by the lien of the LG&E 2010 Mortgage Indenture which creates a lien, subject to certain exceptions and exclusions, on substantially all of LG&E's real and tangible personal property located in Kentucky and used or to be used in connection with the generation, transmission and distribution of electricity and the storage and distribution of natural gas. The aggregate carrying value of the property subject to the lien was $5.7 billion and $5.5 billion at December 31, 2021 and 2020. Includes KU's first mortgage bonds that are secured by the lien of the KU 2010 Mortgage Indenture which creates a lien, subject to certain exceptions and exclusions, on substantially all of KU's real and tangible personal property located in Kentucky and used or to be used in connection with the generation, transmission and distribution of electricity. The aggregate carrying value of the property subject to the lien was $6.9 billion and $6.7 billion at December 31, 2021 and 2020. (b) Includes PPL Electric's series of senior secured bonds that secure its obligations to make payments with respect to each series of Pollution Control Bonds that were issued by the LCIDA and the PEDFA on behalf of PPL Electric. These senior secured bonds were issued in the same principal amount, contain payment and redemption provisions that correspond to and bear the same interest rate as such Pollution Control Bonds. These senior secured bonds were issued under PPL Electric's 2001 Mortgage Indenture and are secured as noted in (a) above. This amount includes $224 million of which PPL Electric is allowed to convert the interest rate mode on the bonds from time to time to a commercial paper rate, daily rate, weekly rate, or term rate of at least one year and $90 million which is subject to mandatory redemption upon determination that the interest rate on the bonds would be included in the holders' gross income for federal tax purposes. Includes $250 million of notes that may be called on or after September 28, 2021 and $650 million of notes that may be called on or after June 24, 2022, at a redemption price equal to 100% of the principal amount of the bonds, plus accrued and unpaid interest to, but excluding, such redemption date. (c) Includes LG&E's and KU's series of first mortgage bonds that were issued to the respective trustees of tax-exempt revenue bonds to secure its respective obligations to make payments with respect to each series of bonds. The first mortgage bonds were issued in the same principal amounts, contain payment and redemption provisions that correspond to and bear the same interest rate as such tax-exempt revenue bonds. These first mortgage bonds were issued under the LG&E 2010 Mortgage Indenture and the KU 2010 Mortgage Indenture and are secured as noted in (a) above. The related tax-exempt revenue bonds were issued by various governmental entities, principally counties in Kentucky, on behalf of LG&E and KU. The related revenue bond documents allow LG&E and KU to convert the interest rate mode on the bonds from time to time to a commercial paper rate, daily rate, weekly rate, term rate of at least one year or, in some cases, an auction rate or a LIBOR index rate. At December 31, 2021, the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a term rate mode totaled $782 million for PPL, comprised of $473 million and $309 million for LG&E and KU. At December 31, 2021, the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a variable rate mode totaled $66 million and $33 million for LG&E and KU. These variable rate tax-exempt revenue bonds are subject to tender for purchase by LG&E and KU at the option of the holder and to mandatory tender for purchase by LG&E and KU upon the occurrence of certain events. (d) The table reflects principal maturities only, based on stated maturities or earlier put dates, and the weighted-average rates as of December 31, 2021. None of the outstanding debt securities noted above have sinking fund requirements. The aggregate maturities of long-term debt, based on stated maturities or earlier put dates, for the periods 2022 through 2026 and thereafter are as follows: PPL PPL LG&E KU 2022 $ 474 $ 474 $ — $ — 2023 353 340 — 13 2024 650 650 — — 2025 550 — 300 250 2026 904 — 90 164 Thereafter 8,320 3,075 1,634 2,215 Total $ 11,251 $ 4,539 $ 2,024 $ 2,642 (PPL) In April 2021, PPL Capital Funding repaid its $100 million term loan expiring in March 2022. In June 2021, PPL Capital Funding commenced a tender offer to purchase for cash and retire (1) any and all of its outstanding 4.20% Senior Notes due 2022, 3.50% Senior Notes due 2022, 3.40% Senior Notes due 2023 and 3.95% Senior Notes due 2024 and (2) up to $1 billion aggregate purchase price of its outstanding 4.70% Senior Notes due 2043, 5.00% Senior Notes due 2044, 4.00% Senior Notes due 2047, 4.125% Senior Notes due 2030 and 3.10% Senior Notes due 2026. In June 2021, in connection with the tender offer, PPL Capital Funding retired $1,962 million combined aggregate principal amount of its outstanding Senior Notes for $2,293 million aggregate cash purchase price that included the tender premium and accrued interest. These Senior Notes had a weighted average interest rate of 4.14%. The loss on extinguishment associated with the transaction was $322 million, which included the tender premium, bank fees and unamortized fees, hedges and discounts. This loss on extinguishment was recorded to "Interest Expense" on the Statements of Income. In July 2021, PPL Capital Funding redeemed the remaining $1,072 million combined aggregate principal amount of its outstanding 4.20% Senior Notes due 2022, 3.50% Senior Notes due 2022, 3.40% Senior Notes due 2023 and 3.95% Senior Notes due 2024 that had not been validly tendered for an aggregate cash purchase price of $1,133 million, which included make-whole premiums and accrued interest. These Senior Notes had a weighted average interest rate of 3.71%. The loss on extinguishment associated with the transaction was $58 million, which included make-whole premiums, unamortized fees, hedges and discounts. PPL Capital Funding also redeemed its $450 million of 5.90% Junior Subordinated Notes due in 2073 at par. The loss on extinguishment associated with this transaction was $15 million, which included unamortized fees. In July 2021, LKE redeemed at par the $250 million 4.375% Senior Notes due 2021. PPL has guaranteed PPL Capital Funding's obligations under the credit agreement and notes. (PPL and PPL Electric) In June 2021, PPL Electric issued $650 million of First Mortgage Bonds, Floating Rate Series due 2024. PPL Electric received proceeds of $647 million, net of underwriting fees, which were used to redeem its $400 million outstanding First Mortgage Bonds, 3% Series due 2021 in July 2021 and for general corporate purposes. (PPL and LG&E) In April 2021, the Louisville/Jefferson County Metro Government of Kentucky remarketed $128 million of Pollution Control Revenue Bonds, 2003 Series A due 2033 previously issued on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at 2.00% through their maturity date of October 1, 2033. In May 2021, the County of Trimble, Kentucky remarketed $35 million of Pollution Control Revenue Bonds, 2001 Series B due 2027 previously issued on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at 1.35% through their maturity date of November 1, 2027. In May 2021, the Louisville/Jefferson County Metro Government of Kentucky remarketed $35 million of Pollution Control Revenue Bonds, 2001 Series B due 2027 previously issued on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at 1.35% through their maturity date of November 1, 2027. In June 2021, LG&E converted the $31 million of Louisville/Jefferson County Metro Government of Kentucky Environmental Facilities Revenue Refunding Bonds, 2007 Series A issued on its behalf to a weekly interest rate. The bonds mature on June 1, 2033. In June 2021, LG&E converted the $35 million of Louisville/Jefferson County Metro Government, of Kentucky Environmental Facilities Revenue Refunding Bonds, 2007 Series B issued on its behalf to a weekly interest rate. The bonds mature on June 1, 2033. In September 2021, the County of Trimble, Kentucky remarketed $28 million of Pollution Control Revenue Bonds, 2001 Series A due 2026, previously issued on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at 0.625% through their maturity date of September 1, 2026. (PPL and KU) In June 2021, the County of Carroll, Kentucky remarketed $54 million of Environmental Facilities Revenue Refunding Bonds, 2006 Series B due 2034 previously issued on behalf of KU. The bonds were remarketed at a long-term rate and will bear interest at 2.125% though their maturity date of October 1, 2034. In June 2021, the County of Carroll, Kentucky remarketed $78 million of Environmental Facilities Revenue Bonds 2008 Series A due 2032 previously issued on behalf of KU. The bonds were remarketed at a long-term rate and will bear interest at 2.00% through their maturity date of February 1, 2032. See Note 15 for additional information related to intercompany borrowings. Legal Separateness (All Registrants) The subsidiaries of PPL are separate legal entities. PPL's subsidiaries are not liable for the debts of PPL. Accordingly, creditors of PPL may not satisfy their debts from the assets of PPL's subsidiaries absent a specific contractual undertaking by a subsidiary to pay PPL's creditors or as required by applicable law or regulation. Similarly, PPL is not liable for the debts of its subsidiaries, nor are its subsidiaries liable for the debts of one another. Accordingly, creditors of PPL's subsidiaries may not satisfy their debts from the assets of PPL or its other subsidiaries absent a specific contractual undertaking by PPL or its other subsidiaries to pay the creditors or as required by applicable law or regulation. Similarly, the subsidiaries of PPL Electric are each separate legal entities. These subsidiaries are not liable for the debts of PPL Electric. Accordingly, creditors of PPL Electric may not satisfy its debts from the assets of its subsidiaries absent a specific contractual undertaking by a subsidiary to pay the creditors or as required by applicable law or regulation. Similarly, PPL Electric is not liable for the debts of its subsidiaries, nor are its subsidiaries liable for the debts of one another. Accordingly, creditors of these subsidiaries may not satisfy their debts from the assets of PPL Electric (or its other subsidiaries) absent a specific contractual undertaking by PPL Electric or any such other subsidiary to pay such creditors or as required by applicable law or regulation. (PPL) Equity Securities Share Repurchases In August 2021, PPL's Board of Directors authorized share repurchases of up to $3 billion of PPL common shares. The actual amount repurchased will depend on various factors, including PPL’s share price, market conditions, and the determination of other uses for the proceeds from the sale of the U.K. utility business, including for incremental capital expenditures. PPL may purchase shares on each trading day subject to market conditions and principles of best execution. During the year ended December 31, 2021, PPL repurchased 34.8 million shares at a cost of $1.0 billion. Commission fees incurred, which have been included in the cost of repurchases above, were insignificant through December 31, 2021. ATM Program In February 2018, PPL entered into an equity distribution agreement, pursuant to which PPL may sell, from time to time, up to an aggregate of $1.0 billion of its common stock through an at-the-market offering program, including a forward sales component. The compensation paid to the selling agents by PPL may be up to 2% of the gross offering proceeds of the shares. There were no issuances under the ATM program for the twelve months ended December 31, 2021 and 2020. The ATM program expired in February 2021. Distributions and Related Restrictions In November 2021, PPL declared its quarterly common stock dividend, payable January 3, 2022, at 41.50 cents per share (equivalent to $1.66 per annum). On February 18, 2022, PPL announced a quarterly common stock dividend of 20.00 cents per share, payable April 1, 2022, to shareowners of record as of March 10, 2022. Future dividends will be declared at the discretion of the Board of Directors and will depend upon future earnings, cash flows, financial and legal requirements and other factors. Neither PPL Capital Funding nor PPL may declare or pay any cash dividend or distribution on its capital stock during any period in which PPL Capital Funding defers interest payments on its 2007 Series A Junior Subordinated Notes due 2067. At December 31, 2021, no interest payments were deferred. (All Registrants) PPL relies on dividends or loans from its subsidiaries to fund PPL's dividends to its common shareholders. The net assets of certain PPL subsidiaries are subject to legal restrictions. LG&E, KU and PPL Electric are subject to Section 305(a) of the Federal Power Act, which makes it unlawful for a public utility to make or pay a dividend from any funds "properly included in capital account." The meaning of this limitation has never been clarified under the Federal Power Act. LG&E, KU and PPL Electric believe, however, that this statutory restriction, as applied to their circumstances, would not be construed or applied by the FERC to prohibit the payment from retained earnings of dividends that are not excessive and are for lawful and legitimate business purposes. In February 2012, LG&E and KU petitioned the FERC requesting authorization to pay dividends in the future based on retained earnings balances calculated without giving effect to the impact of purchase accounting adjustments for PPL's 2010 acquisition of LG&E and KU. In May 2012, the FERC approved the petitions with the further condition that each utility may not pay dividends if such payment would cause its adjusted equity ratio to fall below 30% of total capitalization. Accordingly, at December 31, 2021, net assets of $1.4 billion for LG&E and $1.9 billion for KU were restricted for purposes of paying dividends to LKE, and net assets of $1.7 billion for LG&E and $2.0 billion for KU were available for payment of dividends to LKE. LG&E and KU believe they will not be required to change their current dividend practices as a result of the foregoing requirement. In addition, under Virginia law, KU is prohibited from making loans to affiliates without the prior approval of the VSCC. There are no comparable statutes under Kentucky law applicable to LG&E and KU, or under Pennsylvania law applicable to PPL Electric. However, orders from the KPSC require LG&E and KU to obtain prior consent or approval before lending amounts to PPL.

Acquisitions, Development and D

Acquisitions, Development and Divestitures	12 Months Ended
	Dec. 31, 2021
Contractors [Abstract]
Mergers, Acquisitions and Dispositions Disclosures	9. Acquisitions, Development and Divestitures (PPL) Discontinued Operations Sale of the U.K. Utility Business On March 17, 2021, PPL WPD Limited (WPD Limited) entered into a share purchase agreement (WPD SPA) to sell PPL's U.K. utility business to National Grid Holdings One plc (National Grid U.K.), a subsidiary of National Grid plc. Pursuant to the WPD SPA, National Grid U.K. would acquire 100% of the issued share capital of PPL WPD Investments Limited (WPD Investments) for £7.8 billion in cash. WPD Limited would also receive an additional amount of £548,000 for each day during the period from January 1, 2021 to the closing date if the dividends usually declared by WPD Investments to WPD Limited were not paid for that period. On June 14, 2021, the sale of the U.K. utility business was completed. The transaction resulted in cash proceeds of $10.7 billion inclusive of foreign currency hedges executed by PPL. PPL received net proceeds, after taxes and fees, of $10.4 billion. WPD Limited and National Grid U.K. each made customary representations and warranties in the WPD SPA. National Grid U.K., at its expense, purchased warranty and indemnity insurance. WPD Limited agreed to indemnify National Grid U.K. for certain tax related matters. See Note 14 for additional information. PPL has not had and will not have any significant involvement with the U.K. utility business after completion of the sale. Loss on Sale The following table summarizes the pre-tax loss recorded upon completion of the sale. Loss on sale for the year ended December 31, 2021 Sales proceeds, net of realized foreign currency hedge losses (a) $ 10,732 Unrealized foreign currency hedge losses recognized in 2020 125 Less: Costs to sell (b) 69 Less: Carrying value (c) 12,397 Loss on sale $ (1,609) (a) Includes the fixed and additional consideration of £7,881 million specified in the WPD SPA, converted at a spot rate of $1.4107 per GBP, offset by $386 million of realized foreign currency hedge losses to hedge the proceeds from the sale. (b) I ncludes bank advisory, legal and accounting fees to facilitate the transaction. (c) Represents the carrying value of the U.K. utility business at the time of sale and includes the realization of AOCI of $3.6 billion, which arose primarily from currency translation adjustments and defined benefit plans associated with the U.K. utility business. Summarized Results of Discontinued Operations The operations of the U.K. utility business are included in "Income (Loss) from Discontinued Operations (net of income taxes)" on the Statements of Income. Following are the components of discontinued operations in the Statements of Income for the years ended December 31: 2021 2020 2019 Operating Revenues $ 1,344 $ 2,133 $ 2,167 Operating Expenses 467 916 853 Other Income (Expense) - net 202 167 295 Interest Expense (a) 209 367 373 Income before income taxes 870 1,017 1,236 Loss on sale (1,609) — — Income Taxes 759 188 226 Income (Loss) from Discontinued Operations (net of income taxes) $ (1,498) $ 829 $ 1,010 (a) No interest from corporate level debt was allocated to discontinued operations. Summarized Assets and Liabilities Held for Sale The following major classes of assets and liabilities of the U.K. utility business were reclassified on PPL's Balance Sheet to "Current assets held for sale" and "Current liabilities held for sale" as of December 31, 2020: Held for Sale at December 31, 2020 Cash and cash equivalents $ 266 Accounts receivable and unbilled revenues 389 Price risk management assets 146 Property, plant and equipment, net (a) 14,392 Goodwill 2,558 Other intangibles 413 Pension benefit asset 682 Other assets 137 Total Assets $ 18,983 Short-term debt and long-term debt due within one year $ 994 Accounts payable 220 Customer deposits 217 Accrued interest 190 Long-term debt 7,938 Total deferred income taxes 1,032 Price risk management liabilities 137 Other deferred credits and liabilities 295 Total Liabilities $ 11,023 Net assets (b) $ 7,960 (a) Depreciation of fixed assets ceased upon classification as held for sale in the first quarter of 2021. (b) The net assets and liabilities held for sale exclude $4.0 billion of AOCI related to the U.K. utility business that is required to be included in the carrying value of an entity classified as held for sale when assessing impairment and determining the gain or loss on sale. Prior to the sale, AOCI related to the U.K. utility business was reported as a component of PPL’s equity. Acquisitions Share Purchase Agreement to Acquire Narragansett Electric On March 17, 2021, PPL and its subsidiary, PPL Energy Holdings, entered into a share purchase agreement (Narragansett SPA) with National Grid USA (National Grid U.S.), a subsidiary of National Grid plc, to acquire 100% of the outstanding shares of common stock of Narragansett Electric for approximately $3.8 billion in cash. On May 3, 2021, an Assignment and Assumption Agreement was entered into by PPL, PPL Energy Holdings, PPL Rhode Island Holdings and National Grid U.S. whereby certain interests of PPL Energy Holdings in the Narragansett SPA were assigned to and assumed by PPL Rhode Island Holdings. Pursuant to that Assignment and Assumption Agreement, PPL Rhode Island Holdings became the purchasing entity under the Narragansett SPA. The acquisition is expected to be funded with proceeds from the sale of the U.K. utility business. PPL has agreed to guarantee all obligations of PPL Energy Holdings and PPL Rhode Island Holdings under the Narragansett SPA and the related Assignment and Assumption Agreement. The closing of the acquisition is subject to the receipt of certain U.S. regulatory approvals or waivers, including, among others, authorizations or waivers from the Rhode Island Division of Public Utilities and Carriers, the Massachusetts Department of Public Utilities, the Federal Communications Commission (FCC), and the FERC, as well as review under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended, and other customary conditions to closing, including the execution and delivery of certain related transaction documents. The waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended, with respect to the acquisition, expired on June 2, 2021. On July 14, 2021, the FCC consented to the Transfer of Control Application for the transfer of control of certain communications licenses held by Narragansett Electric from National Grid U.S. to PPL. On July 16, 2021, the Massachusetts Department of Public Utilities (MDPU) granted a waiver of jurisdiction with respect to the acquisition, finding that the acquisition would not adversely impact Massachusetts ratepayers. On December 3, 2021, the MPDU denied the request by the Attorney General of Massachusetts (AG) to stay the order granting the waiver, and on December 31, 2021, the AG then moved for the Massachusetts Supreme Judicial Court (SJC) to stay the final MDPU order. That request remains pending. If a stay is issued, PPL would not be able to close the acquisition until any stay is lifted or the appeal is resolved. On September 23, 2021, the FERC issued an order authorizing, as consistent with the public interest, the disposition of jurisdictional facilities that will result in PPL Rhode Island Holdings, LLC, acquiring 100% of the outstanding shares of common stock of Narragansett Electric. The regulatory approvals remain subject to any applicable appeal periods. PPL anticipates receiving a final order from the Rhode Island Division of Public Utilities and Carriers with respect to the acquisition by March 2022, however, no assurance can be given as to ultimate outcome of that review or the timing of any final decision. PPL Energy Holdings and PPL Rhode Island Holdings and National Grid U.S. have each made customary representations, warranties and covenants in the Narragansett SPA, including, among others, customary indemnification provisions and covenants by National Grid U.S. to conduct the Narragansett Electric business in the ordinary course between the execution of the Narragansett SPA and the closing of the acquisition. The consummation of the transaction is not subject to a financing condition. In connection with the acquisition, National Grid U.S. and one or more of its subsidiaries and Narragansett Electric will enter into a transition services agreement, pursuant to which National Grid U.S. and/or one or more of its affiliates will agree to provide certain transition services to Narragansett Electric and its affiliates to facilitate the operation of Narragansett Electric following the consummation of the acquisition and the transition of operations to PPL, as agreed upon in the Narragansett SPA.

Leases

Leases	12 Months Ended
	Dec. 31, 2021
Leases [Line Items]
Lessor, Operating Leases [Text Block]	Lessor Transactions Third parties leased land from LG&E and KU at certain generation plants to produce refined coal used to generate electricity. The leases were operating leases and expired in 2021. Payments were allocated among lease and non-lease components as stated in the agreements. Lease payments were fixed or determined based on the amount of refined coal used in electricity generation at the facility. Payments received were primarily recorded as a regulatory liability and amortized in accordance with regulatory approvals. The following table shows the lease income recognized for the years ended December 31: PPL LG&E KU Lease income recognized for the twelve months ended December 31, 2021 $ 11 $ 5 $ 5 Lease income recognized for the twelve months ended December 31, 2020 16 6 9 Lease income recognized for the twelve months ended December 31, 2019 14 5 8
Lessee, Operating Leases [Text Block]	(All Registrants) The Registrants determine whether contractual arrangements contain a lease by evaluating whether those arrangements either implicitly or explicitly identify an asset, whether the Registrants have the right to obtain substantially all of the economic benefits from use of the asset throughout the term of the arrangement, and whether the Registrants have the right to direct the use of the asset. Renewal options are included in the lease term if it is reasonably certain the Registrants will exercise those options. Periods for which the Registrants are reasonably certain not to exercise termination options are also included in the lease term. The Registrants have certain agreements with lease and non-lease components, such as office space leases, which are generally accounted for separately. LG&E and KU have entered into various operating leases primarily for office space, vehicles and railcars. The leases generally have fixed payments with expiration dates ranging from 2022 to 2033, some of which have options to extend the leases from one year to ten years and some have options to terminate at LG&E's and KU's discretion. PPL has also entered into various operating leases primarily for office and warehouse space. These leases generally have fixed payments with expiration dates ranging from 2024 through 2030. PPL Electric also has operating leases which do not have a significant impact to its operations. Short-term Leases Short-term leases are leases with a term that is 12 months or less and do not include a purchase option or option to extend the initial term of the lease to greater than 12 months that the Registrants are reasonably certain to exercise. The Registrants have made an accounting policy election to not recognize the right-of-use asset and the lease liability arising from leases classified as short-term. Expenses related to short-term leases are included in the tables below. Discount Rate The discount rate for a lease is the rate implicit in the lease unless that rate cannot be readily determined. In that case, the Registrants are required to use their incremental borrowing rate, which is the rate the Registrants would have to pay to borrow, on a collateralized basis over a similar term, an amount equal to the lease payments in a similar economic environment. The Registrants receive secured borrowing rates from financial institutions based on their applicable credit profiles. The Registrants use the secured rate which corresponds with the term of the applicable lease. (PPL, LG&E and KU) Lessee Transactions The following table provides the components of lease cost for the Registrants' operating leases for the years ended December 31: 2021 2020 2019 PPL Lease cost: Operating lease cost $ 24 $ 28 $ 30 Short-term lease cost 6 7 5 Total lease cost $ 30 $ 35 $ 35 LG&E Lease cost: Operating lease cost $ 6 $ 8 $ 12 Short-term lease cost 1 1 1 Total lease cost $ 7 $ 9 $ 13 KU Lease cost: Operating lease cost $ 10 $ 13 $ 13 Short-term lease cost 1 1 1 Total lease cost $ 11 $ 14 $ 14 The following table provides other key information related to the Registrants' operating leases at December 31: 2021 2020 2019 PPL Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 23 $ 24 $ 26 Right-of-use asset obtained in exchange for new operating lease liabilities 12 17 45 LG&E Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 6 $ 7 $ 9 Right-of-use asset obtained in exchange for new operating lease liabilities 4 6 5 KU Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 10 $ 11 $ 11 Right-of-use asset obtained in exchange for new operating lease liabilities 7 9 11 The following table provides the total future minimum rental payments for operating leases, as well as a reconciliation of these undiscounted cash flows to the lease liabilities recognized on the Balance Sheets as of December 31, 2021. PPL LG&E KU 2022 $ 23 $ 6 $ 10 2023 20 5 8 2024 15 4 6 2025 8 3 4 2026 3 1 1 Thereafter 5 1 1 Total $ 74 $ 20 $ 30 Weighted-average discount rate 3.38% 3.48% 3.67% Weighted-average remaining lease term (in years) 4 4 4 Current lease liabilities (a) $ 22 $ 6 $ 9 Non-current lease liabilities (a) 47 12 17 Right-of-use assets (b) 62 15 24 (a) Current lease liabilities are included in " Other Current Liabilities Other deferred credits and noncurrent liabilities (b) Right-of-use assets are included in "Other noncurrent assets" on the Balance Sheets.

Stock-Based Compensation

Stock-Based Compensation	12 Months Ended
	Dec. 31, 2021
Stock-Based Compensation [Line Items]
Stock-Based Compensation	(PPL and PPL Electric) Under the ICP, SIP and the ICPKE (together, the Plans), restricted shares of PPL common stock, restricted stock units, performance units and stock options may be granted to officers and other key employees of PPL, PPL Electric and other affiliated companies. Awards under the Plans are made by the Compensation Committee of the PPL Board of Directors, in the case of the ICP and SIP, and by the PPL Corporate Leadership Council (CLC), in the case of the ICPKE. The following table details the award limits under each of the Plans. Total Plan Annual Grant Limit Annual Grant Annual Grant Limit Award PPL Common Stock Limit For awards For awards Plan (Shares) Each Calendar Year (Shares) shares (Shares) cash (in dollars) SIP 15,000,000 2,000,000 750,000 $ 15,000,000 ICPKE 14,199,796 2 % 3,000,000 Any portion of these awards that has not been granted may be carried over and used in any subsequent year. If any award lapses, the rights of the participant terminate, or, with respect to certain awards, is forfeited, and the shares of PPL common stock underlying such an award are again available for grant. Shares delivered under the Plans may be in the form of authorized and unissued PPL common stock, common stock held in treasury by PPL or PPL common stock purchased on the open market (including private purchases) in accordance with applicable securities laws. Restricted Stock Units Restricted stock units represent the right to receive shares of PPL common stock in the future, generally three years after the date of grant, in an amount based on the fair value of PPL common stock on the date of grant. Under the SIP, each restricted stock unit entitles the grant recipient to accrue additional restricted stock units equal to the amount of quarterly dividends paid on PPL stock. These additional restricted stock units are deferred and payable in shares of PPL common stock at the end of the restriction period. Dividend equivalents on restricted stock unit awards granted under the ICPKE are currently paid in cash when dividends are declared by PPL. The fair value of restricted stock units granted is recognized on a straight-line basis over the restriction period or through the date at which the employee reaches retirement eligibility. The fair value of restricted stock units granted to retirement-eligible employees is recognized as compensation expense immediately upon the date of grant. Recipients of restricted stock units granted under the ICPKE may also be granted the right to receive dividend equivalents through the end of the restriction period or until the award is forfeited. Restricted stock units are subject to forfeiture or accelerated payout under the plan provisions for termination, retirement, disability and death of employees. Restrictions lapse on restricted stock units fully, in certain situations, as defined by each of the Plans. The weighted-average grant date fair value of restricted stock units granted was: 2021 2020 2019 PPL $ 28.00 $ 35.30 $ 31.95 PPL Electric 27.96 35.37 32.33 Restricted stock unit activity for 2021 was: Restricted Weighted- PPL Nonvested, beginning of period 896,336 $ 32.56 Granted 458,610 28.00 Vested (303,890) 30.57 Forfeited (46,473) 30.23 Nonvested, end of period 1,004,583 31.19 PPL Electric Nonvested, beginning of period 210,720 $ 32.73 Transfer between registrants (92,596) 32.99 Granted 51,587 27.96 Vested (32,266) 29.98 Forfeited (6,158) 32.16 Nonvested, end of period 131,287 31.50 Substantially all restricted stock unit awards are expected to vest. The total fair value of restricted stock units vesting for the years ended December 31 was: 2021 2020 2019 PPL $ 8 $ 19 $ 13 PPL Electric 1 3 2 Performance Units - Total Shareowner Return Performance units based on relative Total Shareowner Return (TSR) are intended to encourage and reward future corporate performance. Performance units represent a target number of shares (Target Award) of PPL's common stock that the recipient would receive upon PPL's attainment of the applicable performance goal. Performance is determined based on TSR during a three The fair value of TSR performance units granted to retirement-eligible employees is recognized as compensation expense on a straight-line basis over a one three one The fair value of each performance unit granted was estimated using a Monte Carlo pricing model that considers stock beta, a risk-free interest rate, expected stock volatility and expected life. The stock beta was calculated comparing the risk of the individual securities to the average risk of the companies in the index group. The risk-free interest rate reflects the yield on a U.S. Treasury bond commensurate with the expected life of the performance unit. Volatility over the expected term of the performance unit is calculated using daily stock price observations for PPL and all companies in the index group and is evaluated with consideration given to prior periods that may need to be excluded based on events not likely to recur that had impacted PPL and the companies in the index group. PPL uses a mix of historic and implied volatility to value awards. The weighted-average assumptions used in the model were: 2021 2020 2019 Expected stock volatility 27.81% 15.64% 17.57% Expected life 3 years 3 years 3 years The weighted-average grant date fair value of TSR performance units granted was: 2021 2020 2019 PPL $ 32.44 $ 37.63 $ 35.83 PPL Electric 32.92 38.64 35.68 TSR performance unit activity for 2021 was: TSR Performance Units Weighted- PPL Nonvested, beginning of period 626,254 $ 36.98 Granted 306,009 32.44 Vested (53,340) 34.47 Forfeited (a) (245,150) 37.75 Nonvested, end of period 633,773 34.68 TSR Performance Units Weighted- PPL Electric Nonvested, beginning of period 61,807 $ 37.44 Transfer between registrants (53,663) 37.42 Granted 10,010 32.92 Forfeited (a) (2,800) 38.47 Nonvested, end of period 15,354 34.36 (a) Primarily related to the forfeiture of 2018 domestic performance units as performance during the period was below the minimum established performance threshold, which resulted in no payout. For the year ended December 31, 2021, $2 million of TSR performance units vested. All awards vested were associated with the sale of the U.K. utility business. See Note 9 for additional information on the sale of the U.K. utility business. No TSR performance units vested for the years ended December 31, 2020 and 2019. Amounts for PPL Electric are insignificant. Performance Units - Return on Equity Beginning in 2017, PPL changed its executive compensation mix to add performance units based on achievement of a corporate Return on Equity (ROE). ROE performance units are intended to further align compensation with the company’s strategy and reward for future corporate performance. Payout of these performance units will be based on the calculated average of the annual corporate ROE for each year of the three The fair value of each ROE performance unit is based on the closing price of PPL Common Stock on the date of grant. The fair value of ROE performance units is recognized on a straight-line basis over the service period or through the date at which the employee reaches retirement eligibility. The fair value awards granted to retirement-eligible employees is recognized as compensation expense immediately upon the date of grant. As these awards are based on performance conditions, the level of attainment is monitored each reporting period and compensation expense is adjusted based on the expected attainment level. The weighted-average grant date fair value of ROE performance units granted was: 2021 2020 2019 PPL $ 30.08 $ 34.95 $ 30.89 PPL Electric 29.39 35.59 30.76 ROE performance unit activity for 2021 was: ROE Performance Unit Weighted- PPL Nonvested, beginning of period 728,664 $ 32.81 Granted 572,571 30.08 Vested (570,722) 32.02 Forfeited (8,160) 30.44 Nonvested, end of period 722,353 31.28 PPL Electric Nonvested, beginning of period 61,807 $ 33.01 Transfer between registrants (53,663) 33.00 Granted 12,895 29.39 Vested (5,685) 32.27 Nonvested, end of period 15,354 30.27 The total fair value of ROE performance units vesting for the years ended December 31 was: 2021 2020 PPL $ 16 $ 8 PPL Electric — 1 Stock Options PPL's Compensation, Governance and Nominating Committee, now known as the Compensation Committee, eliminated the use of stock options due to changes in its long-term incentive mix beginning in January 2014 . Under the Plans, stock options had been granted with an option exercise price per share not less than the fair value of PPL's common stock on the date of grant. Options outstanding at December 31, 2021, are fully vested. All options expire no later than 10 years from the grant date. The options become exercisable immediately in certain situations, as defined by each of the Plans. Stock option activity for 2021 was: Number Weighted Weighted- Aggregate PPL Outstanding at beginning of period 1,103,016 $ 26.22 Exercised (337,014) 25.42 Outstanding and exercisable at end of period 766,002 26.57 1 $ 3 For 2021, 2020 and 2019, PPL received $10 million, $8 million and $53 million in cash from stock options exercised. The total intrinsic value of stock options exercised was insignificant in 2021 and 2020 and $11 million in 2019. The related income tax benefits realized were not significant. Compensation Expense Compensation expense for restricted stock, restricted stock units, performance units and stock options accounted for as equity awards, which for PPL Electric includes an allocation of PPL Services' expense, was: 2021 2020 2019 PPL $ 34 $ 28 $ 35 PPL Electric 11 10 12 The income tax benefit related to above compensation expense was as follows: 2021 2020 2019 PPL $ 10 $ 8 $ 10 PPL Electric 3 3 3 At December 31, 2021, unrecognized compensation expense related to nonvested stock awards was: Unrecognized Weighted- PPL $ 19 1.7 PPL Electric 2 1.8

Retirement and Postemployment B

Retirement and Postemployment Benefits	12 Months Ended
	Dec. 31, 2021
Retirement Benefits [Abstract]
Retirement and Postemployment Benefits	(All Registrants) Defined Benefits Certain employees of PPL's subsidiaries are eligible for pension benefits under non-contributory defined benefit pension plans with benefits based on length of service and final average pay, as defined by the plans. Effective January 1, 2012, PPL's primary defined benefit pension plan was closed to all newly hired salaried employees. Effective July 1, 2014, PPL's primary defined benefit pension plan was closed to all newly hired bargaining unit employees. Newly hired employees are eligible to participate in the PPL Retirement Savings Plan, a 401(k) savings plan with enhanced employer contributions. The defined benefit pension plans of LKE and its subsidiaries were closed to new salaried and bargaining unit employees hired after December 31, 2005. Employees hired after December 31, 2005 receive additional company contributions above the standard matching contributions to their savings plans. The pension plans sponsored by LKE and LG&E were merged effective January 1, 2020 into the LG&E and KU Pension Plan. The merged plan is sponsored by LKE. LG&E and KU participate in this plan. PPL and certain of its subsidiaries also provide supplemental retirement benefits to executives and other key management employees through unfunded nonqualified retirement plans. Certain employees of PPL's subsidiaries are eligible for certain health care and life insurance benefits upon retirement through contributory plans. Effective January 1, 2014, the PPL Postretirement Medical Plan was closed to all newly hired salaried employees. Effective July 1, 2014, the PPL Postretirement Medical Plan was closed to all newly hired bargaining unit employees. Postretirement health benefits may be paid from 401(h) accounts established as part of the PPL Retirement Plan and the LG&E and KU Pension Plan within the PPL Services Corporation Master Trust, funded VEBA trusts and company funds. (PPL) The following table provides the components of net periodic defined benefit costs (credits) for PPL's pension and other postretirement benefit plans for the years ended December 31. Pension Benefits Other Postretirement Benefits 2021 2020 2019 2021 2020 2019 Net periodic defined benefit costs (credits): Service cost $ 56 $ 56 $ 50 $ 6 $ 6 $ 6 Interest cost 121 146 164 16 19 22 Expected return on plan assets (255) (246) (245) (23) (21) (18) Amortization of: Prior service cost (credit) 8 9 8 1 1 (1) Actuarial (gain) loss 93 89 56 (1) — 1 Net periodic defined benefit costs (credits) prior to settlements and termination benefits 23 54 33 (1) 5 10 Settlements (a) 18 23 1 — — — Net periodic defined benefit costs (credits) $ 41 $ 77 $ 34 $ (1) $ 5 $ 10 Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: Settlement (18) (23) (1) — — — Net (gain) loss 42 (221) (121) (53) (6) (18) Prior service cost (credit) 3 1 2 — 5 — Amortization of: Prior service (cost) credit (8) (9) (8) (1) (1) 1 Actuarial gain (loss) (93) (89) (56) 1 — (1) Total recognized in OCI and regulatory assets/liabilities (74) (341) (184) (53) (2) (18) Total recognized in net periodic defined benefit costs, OCI and regulatory assets/liabilities $ (33) $ (264) $ (150) $ (54) $ 3 $ (8) (a) 2021 and 2020 include a settlement charge for a retired PPL executive as well as a settlement charge incurred as a result of the amount of lump sum payment distributions from the LKE qualified pension plan. In accordance with existing regulatory accounting treatment, LG&E and KU have primarily maintained the settlement charge in regulatory assets to be amortized in accordance with existing regulatory practice. The portion of the settlement attributed to LKE's operations outside of the jurisdiction of the KPSC has been charged to expense. For PPL's pension and postretirement benefits, the amounts recognized in OCI and regulatory assets/liabilities for the years ended December 31 were as follows: Pension Benefits Other Postretirement Benefits 2021 2020 2019 2021 2020 2019 OCI $ (70) $ (428) $ (194) $ (42) $ (12) $ (13) Regulatory assets/liabilities (4) 87 10 (11) 10 (5) Total recognized in OCI and $ (74) $ (341) $ (184) $ (53) $ (2) $ (18) (LG&E) The following table provides the components of net periodic defined benefit costs for LG&E's pension benefit plan for the year ended December 31. Pension Benefits 2019 (a) Net periodic defined benefit costs (credits): Service cost $ 1 Interest cost 11 Expected return on plan assets (21) Amortization of: Prior service cost (credit) 5 Actuarial loss (b) 9 Net periodic defined benefit costs (credits) (c) $ 5 Other Changes in Plan Assets and Benefit Obligations Net (gain) loss $ (19) Amortization of: Prior service credit (5) Actuarial gain (9) Total recognized in regulatory assets/liabilities (33) Total recognized in net periodic defined benefit costs and regulatory assets $ (28) (a) The pension plans sponsored by LKE and LG&E were merged effective January 1, 2020 into the LG&E and KU Pension Plan, sponsored by LKE. (b) As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, the difference between actuarial (gain)/loss calculated in accordance with LG&E's pension accounting policy and actuarial (gain)/loss calculated using a 15 year amortization period was $3 million in 2019. (c) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, settlement charges of $5 million in 2019 was incurred. In accordance with existing regulatory accounting treatment, LG&E has maintained the settlement charge in regulatory assets. The amount will be amortized in accordance with existing regulatory practice. (All Registrants) The following net periodic defined benefit costs (credits) were charged to expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts. Pension Benefits Other Postretirement Benefits 2021 2020 2019 2021 2020 2019 PPL $ 12 $ 40 $ 18 $ (1) $ 4 $ 8 PPL Electric (a) (9) (2) (4) (1) 2 4 LG&E (a) (b) (1) 4 3 2 2 2 KU (a) (b) (3) 1 (1) — — — (a) PPL Electric and KU do not directly sponsor any defined benefit plans. PPL Electric and KU were allocated these costs of defined benefit plans sponsored by PPL Services (for PPL Electric) and by LKE (for KU), based on their participation in those plans, which management believes are reasonable. KU is also allocated costs of defined benefit plans from LKS for defined benefit plans sponsored by LKE. Effective January 1, 2020, the LKE and LG&E defined benefit pension plans were merged into a combined defined benefit pension plan, sponsored by LKE, therefore LG&E does not directly sponsor any defined benefit plans. LG&E and KU were allocated these costs of defined benefit plans sponsored by LKE, based on their participation in those plans, which management believes are reasonable. LG&E and KU are also allocated costs of defined benefit plans from LKS for defined benefit plans sponsored by LKE. See Note 15 for additional information on costs allocated to LG&E and KU from LKS. (b) As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, the difference between net periodic defined benefit costs calculated in accordance with LG&E's and KU's pension accounting policy and the net periodic defined benefit costs calculated using a 15 year amortization period for gains and losses is recorded as a regulatory asset. Of the costs charged to Other operation and maintenance, Other Income (Expense) - net or regulatory assets, excluding amounts charged to construction and other non-expense accounts, insignificant amounts for LG&E and KU were recorded as regulatory assets in 2021, $3 million for LG&E and $1 million for KU were recorded as regulatory assets in 2020 and $2 million for LG&E and $1 million for KU were recorded as regulatory assets in 2019. (PPL and LG&E) PPL and LG&E use base mortality tables issued by the Society of Actuaries for all defined benefit pension and other postretirement benefit plans. In 2019, PPL and LG&E used RP-2014 base tables with collar and factor adjustments, where applicable, and the MP-2017 mortality improvement scale from 2006 on a generational basis. In 2020, PPL updated to the Pri-2012 base table and the MP-2020 projection scale with varying adjustment factors based on the underlying demographic and geographic differences and experience of the plan participants. The following weighted-average assumptions were used in the valuation of the benefit obligations at December 31. Pension Benefits Other Postretirement Benefits 2021 2020 2021 2020 PPL Discount rate 3.15 % 2.92 % 3.13 % 2.84 % Rate of compensation increase 3.76 % 3.76 % 3.77 % 3.75 % The following weighted-average assumptions were used to determine the net periodic defined benefit costs for the years ended December 31. Pension Benefits Other Postretirement Benefits 2021 2020 2019 2021 2020 2019 PPL Discount rate 2.92 % 3.64 % 4.35 % 2.84 % 3.60 % 4.31 % Rate of compensation increase 3.76 % 3.79 % 3.79 % 3.75 % 3.76 % 3.76 % Expected return on plan assets 7.25 % 7.25 % 7.25 % 6.48 % 6.44 % 6.46 % LG&E Discount rate — % — % 4.33 % Expected return on plan assets (a) — % — % 7.25 % (a) The expected long-term rates of return for pension and other postretirement benefits are based on management's projections using a best-estimate of expected returns, volatilities and correlations for each asset class. Each plan's specific current and expected asset allocations are also considered in developing a reasonable return assumption. (PPL) The following table provides the assumed health care cost trend rates for the years ended December 31: 2021 2020 2019 PPL Health care cost trend rate assumed for next year – obligations 6.25 % 6.50 % 6.60 % – cost 6.50 % 6.60 % 6.60 % Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) – obligations 5.00 % 5.00 % 5.00 % – cost 5.00 % 5.00 % 5.00 % Year that the rate reaches the ultimate trend rate – obligations 2027 2027 2024 – cost 2027 2024 2023 The funded status of PPL's plans at December 31 was as follows: Pension Benefits Other Postretirement Benefits 2021 2020 2021 2020 Change in Benefit Obligation Benefit Obligation, beginning of period $ 4,251 $ 4,146 $ 573 $ 557 Service cost 56 56 6 6 Interest cost 121 146 16 19 Participant contributions — — 14 15 Plan amendments 2 2 — 5 Actuarial (gain) loss (88) 256 (50) 29 Settlements (106) (114) — — Gross benefits paid (247) (241) (55) (58) Benefit Obligation, end of period 3,989 4,251 504 573 Change in Plan Assets Plan assets at fair value, beginning of period 4,068 3,585 367 340 Actual return on plan assets 125 723 25 56 Employer contributions 47 115 18 18 Participant contributions — — 11 11 Settlements (106) (114) — — Gross benefits paid (247) (241) (54) (58) Plan assets at fair value, end of period 3,887 4,068 367 367 Funded Status, end of period $ (102) $ (183) $ (137) $ (206) Amounts recognized in the Balance Sheets consist of: Noncurrent asset $ 91 $ 24 $ — $ — Current liability (10) (18) (15) (22) Noncurrent liability (183) (189) (122) (184) Net amount recognized, end of period $ (102) $ (183) $ (137) $ (206) Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: Prior service cost (credit) $ 22 $ 27 $ 12 $ 14 Net actuarial (gain) loss 626 695 (51) — Total $ 648 $ 722 $ (39) $ 14 Total accumulated benefit obligation $ 3,786 $ 4,024 For PPL's pension and other postretirement benefit plans, the amounts recognized in AOCI and regulatory assets/liabilities at December 31 were as follows: Pension Benefits Other Postretirement Benefits 2021 2020 2021 2020 AOCI $ 239 $ 270 $ (2) $ 10 Regulatory assets/liabilities 409 452 (37) 4 Total $ 648 $ 722 $ (39) $ 14 The actuarial gain for pension plans in 2021 was primarily related to a change in the discount rate used to measure the benefit obligations of those plans. The actuarial loss for pension plans in 2020 was related to a change in the discount rate used to measure the benefit obligations of those plans offset by gains resulting from the updated mortality assumptions noted above and other demographic assumption changes resulting from the completion of a tri-annual demographic experience study. The following tables provide information on pension plans where the projected benefit obligation (PBO) or accumulated benefit obligation (ABO) exceed the fair value of plan assets: PBO in excess of plan assets 2021 2020 Projected benefit obligation $ 193 $ 1,875 Fair value of plan assets — 1,668 ABO in excess of plan assets 2021 2020 Accumulated benefit obligation $ 177 $ 184 Fair value of plan assets — — (PPL Electric) Although PPL Electric does not directly sponsor any defined benefit plans, it is allocated a portion of the funded status and costs of plans sponsored by PPL Services based on its participation in those plans, which management believes are reasonable. The actuarially determined obligations of current active employees and retirees are used as a basis to allocate total plan activity, including active and retiree costs and obligations. Allocations to PPL Electric resulted in assets/(liabilities) at December 31 as follows: 2021 2020 Pension $ 42 $ 4 Other postretirement benefits (78) (99) (LG&E) Although LG&E does not directly sponsor any defined benefit plans, it is allocated a portion of the funded status and costs of plans sponsored by LKE. LG&E is also allocated costs of defined benefits plans from LKS for defined benefit plans sponsored by LKE. See Note 15 for additional information on costs allocated to LG&E from LKS. These allocations are based on LG&E's participation in those plans, which management believes are reasonable. The actuarially determined obligations of current active employees and retired employees of LG&E are used as a basis to allocate total plan activity, including active and retiree costs and obligations. Allocations to LG&E resulted in assets/(liabilities) at December 31 as follows: 2021 2020 Pension $ 85 $ 78 Other postretirement benefits (51) (68) (KU) Although KU does not directly sponsor any defined benefit plans, it is allocated a portion of the funded status and costs of plans sponsored by LKE. KU is also allocated costs of defined benefit plans from LKS for defined benefit plans sponsored by LKE. See Note 15 for additional information on costs allocated to KU from LKS. These allocations are based on KU's participation in those plans, which management believes are reasonable. The actuarially determined obligations of current active employees and retired employees of KU are used as a basis to allocate total plan activity, including active and retiree costs and obligations. Allocations to KU resulted in assets/(liabilities) at December 31 as follows. 2021 2020 Pension $ 75 $ 62 Other postretirement benefits (6) (16) Plan Assets - Pension Plans (PPL) PPL's primary legacy pension plan and the pension plan sponsored by LKE are invested in the PPL Services Corporation Master Trust (the Master Trust) that also includes 401(h) accounts that are restricted for certain other postretirement benefit obligations of PPL and LKE. The investment strategy for the Master Trust is to achieve a risk-adjusted return on a mix of assets that, in combination with PPL's funding policy, will ensure that sufficient assets are available to provide long-term growth and liquidity for benefit payments, while also managing the duration of the assets to complement the duration of the liabilities. The Master Trust benefits from a wide diversification of asset types, investment fund strategies and external investment fund managers, and therefore has no significant concentration of risk. The investment policy of the Master Trust outlines investment objectives and defines the responsibilities of the EBPB, external investment managers, investment advisor and trustee and custodian. The investment policy is reviewed annually by PPL's Board of Directors. The EBPB created a risk management framework around the trust assets and pension liabilities. This framework considers the trust assets as being composed of three sub-portfolios: growth, immunizing and liquidity portfolios. The growth portfolio is comprised of investments that generate a return at a reasonable risk, including equity securities, certain debt securities and alternative investments. The immunizing portfolio consists of debt securities, generally with long durations, and derivative positions. The immunizing portfolio is designed to offset a portion of the change in the pension liabilities due to changes in interest rates. The liquidity portfolio consists primarily of cash and cash equivalents. Target allocation ranges have been developed for each portfolio based on input from external consultants with a goal of limiting funded status volatility. The EBPB monitors the investments in each portfolio, and seeks to obtain a target portfolio that emphasizes reduction of risk of loss from market volatility. In pursuing that goal, the EBPB establishes revised guidelines from time to time. EBPB investment guidelines as of the end of 2021 are presented below. The asset allocation for the trust and the target allocation by portfolio at December 31 are as follows: Percentage of trust assets 2021 2021 2020 Target Asset Growth Portfolio 55 % 56 % 55 % Equity securities 32 % 34 % Debt securities (a) 13 % 13 % Alternative investments 10 % 9 % Immunizing Portfolio 43 % 43 % 43 % Debt securities (a) 35 % 33 % Derivatives 8 % 10 % Liquidity Portfolio 2 % 1 % 2 % Total 100 % 100 % 100 % (a) Includes commingled debt funds, which PPL treats as debt securities for asset allocation purposes. (PPL) The fair value of net assets in the Master Trust by asset class and level within the fair value hierarchy was: December 31, 2021 December 31, 2020 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Services Corporation Master Trust Cash and cash equivalents $ 266 $ 266 $ — $ — $ 300 $ 300 $ — $ — Equity securities: U.S. Equity 41 41 — — 60 60 — — U.S. Equity fund measured at NAV (a) 754 — — — 742 — — — International equity fund at NAV (a) 511 — — — 566 — — — Commingled debt measured at NAV (a) 677 — — — 712 — — — December 31, 2021 December 31, 2020 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Debt securities: U.S. Treasury and U.S. government sponsored 281 280 1 — 336 335 1 — Corporate 1,039 — 1,019 20 1,045 — 1,030 15 Other 14 — 14 — 13 — 13 — Alternative investments: Real estate measured at NAV (a) 69 — — — 76 — — — Private equity measured at NAV (a) 94 — — — 68 — — — Hedge funds measured at NAV (a) 236 — — — 223 — — — Limited Partnerships at NAV (a) — — — — 6 — — — Derivatives 35 — 35 — (37) — (37) — PPL Services Corporation Master Trust assets, at 4,017 $ 587 $ 1,069 $ 20 4,110 $ 695 $ 1,007 $ 15 Receivables and payables, net (b) 25 116 401(h) accounts restricted for other (155) (158) Total PPL Services Corporation Master Trust $ 3,887 $ 4,068 (a) In accordance with accounting guidance certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position. (b) Receivables and payables, net represents amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received. A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2021 is as follows: Corporate Total Balance at beginning of period $ 15 $ 15 Purchases, sales and settlements 5 5 Balance at end of period $ 20 $ 20 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2020 is as follows: Corporate Insurance Total Balance at beginning of period $ 20 $ 4 $ 24 Purchases, sales and settlements (5) (4) (9) Balance at end of period $ 15 $ — $ 15 The fair value measurements of cash and cash equivalents are based on the amounts on deposit. The market approach is used to measure fair value of equity securities. The fair value measurements of equity securities (excluding commingled funds), which are generally classified as Level 1, are based on quoted prices in active markets. These securities represent actively and passively managed investments that are managed against various equity indices. Investments in commingled equity and debt funds are categorized as equity securities. Investments in commingled equity funds include funds that invest in U.S. and international equity securities. Investments in commingled debt funds include funds that invest in a diversified portfolio of emerging market debt obligations, as well as funds that invest in investment grade long-duration fixed-income securities. The fair value measurements of debt securities are generally based on evaluations that reflect observable market information, such as actual trade information for identical securities or for similar securities, adjusted for observable differences. The fair value of debt securities is generally measured using a market approach, including the use of pricing models, which incorporate observable inputs. Common inputs include benchmark yields, relevant trade data, broker/dealer bid/ask prices, benchmark securities and credit valuation adjustments. When necessary, the fair value of debt securities is measured using the income approach, which incorporates similar observable inputs as well as payment data, future predicted cash flows, collateral performance and new issue data. For the Master Trust, these securities represent investments in securities issued by U.S. Treasury and U.S. government sponsored agencies; investments securitized by residential mortgages, auto loans, credit cards and other pooled loans; investments in investment grade and non-investment grade bonds issued by U.S. companies across several industries; investments in debt securities issued by foreign governments and corporations. Investments in real estate represent an investment in a partnership whose purpose is to manage investments in core U.S. real estate properties diversified geographically and across major property types (e.g., office, industrial, retail, etc.). The strategy is focused on properties with high occupancy rates with quality tenants. This results in a focus on high income and stable cash flows with appreciation being a secondary factor. Core real estate generally has a lower degree of leverage when compared with more speculative real estate investing strategies. The partnership has limitations on the amounts that may be redeemed based on available cash to fund redemptions. Additionally, the general partner may decline to accept redemptions when necessary to avoid adverse consequences for the partnership, including legal and tax implications, among others. The fair value of the investment is based upon a partnership unit value. Investments in private equity represent interests in partnerships in multiple early-stage venture capital funds and private equity fund of funds that use a number of diverse investment strategies. The partnerships have limited lives of at least 10 years, after which liquidating distributions will be received. Prior to the end of each partnership's life, the investment cannot be redeemed with the partnership; however, the interest may be sold to other parties, subject to the general partner's approval. At December 31, 2021, the Master Trust had unfunded commitments of $111 million that may be required during the lives of the partnerships. Fair value is based on an ownership interest in partners' capital to which a proportionate share of net assets is attributed. Investments in limited partnerships include Term Asset-Backed Securities Loan Facility (TALF) funds. The Master Trust received notice that the TALF funds are liquidating in an orderly manner and distributing capital back to the partners. Therefore, the Master Trust has no unfunded commitment related to the TALF funds. Fair value of the funds is based on an ownership interest in partners' capital to which a proportionate share of net assets is attributed. Investments in hedge funds represent investments in a fund of hedge funds. Hedge funds seek a return utilizing a number of diverse investment strategies. The strategies, when combined aim to reduce volatility and risk while attempting to deliver positive returns under most market conditions. Major investment strategies for the fund of hedge funds include long/short equity, tactical trading, event driven, and relative value. Shares may be redeemed with 45 days prior written notice. The fund is subject to short term lockups and other restrictions. The fair value for the fund has been estimated using the net asset value per share. The fair value measurements of derivative instruments utilize various inputs that include quoted prices for similar contracts or market-corroborated inputs. In certain instances, these instruments may be valued using models, including standard option valuation models and standard industry models. These securities primarily represent investments in treasury futures, total return swaps, interest rate swaps and swaptions (the option to enter into an interest rate swap), which are valued based on quoted prices, changes in the value of the underlying exposure or on the swap details, such as swap curves, notional amount, index and term of index, reset frequency, volatility and payer/receiver credit ratings. In 2019, obligations underlying an investment in an immediate participation guaranteed group annuity contract, classified as Level 3, were assumed by the insurance company, with a residual amount remaining in the general account of the insurer that was paid into the master trust or distributed to participants in 2020. Plan Assets - Other Postretirement Benefit Plans The investment strategy with respect to other postretirement benefit obligations is to fund VEBA trusts and/or 401(h) accounts with voluntary contributions and to invest in a tax efficient manner. Excluding the 401(h) accounts included in the Master Trust, other postretirement benefit plans are invested in a mix of assets for long-term growth with an objective of earning returns that provide liquidity as required for benefit payments. These plans benefit from diversification of asset types, investment fund strategies and investment fund managers and, therefore, have no significant concentration of risk. Equity securities include investments in domestic large-cap commingled funds. Ownership interests in commingled funds that invest entirely in debt securities are classified as equity securities, but treated as debt securities for asset allocation and target allocation purposes. Ownership interests in money market funds are treated as cash and cash equivalents for asset allocation and target allocation purposes. The asset allocation for the PPL VEBA trusts and the target allocation, by asset class, at December 31 are detailed below. Percentage of plan assets Target Asset 2021 2020 2021 Asset Class U.S. Equity securities 45 % 42 % 45 % Debt securities (a) 52 % 55 % 50 % Cash and cash equivalents (b) 3 % 3 % 5 % Total 100 % 100 % 100 % (a) Includes commingled debt funds and debt securities. (b) Includes money market funds. The fair value of assets in the other postretirement benefit plans by asset class and level within the fair value hierarchy was: December 31, 2021 December 31, 2020 Fair Value Measurement Using Fair Value Measurement Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Money market funds $ 6 $ 6 $ — $ — $ 5 $ 5 $ — $ — U.S. Equity securities: Large-cap equity fund measure at NAV (a) 96 — — — 89 — — — Commingled debt fund measured at NAV (a) 75 — — — 77 — — — Debt securities: Corporate bonds 38 — 38 — 37 — 37 — U.S. Treasury and U.S. government sponsored — — — — 2 — 2 — Total VEBA trust assets, at fair value 215 $ 6 $ 38 $ — 210 $ 5 $ 39 $ — Receivables and payables, net (b) (3) (1) 401(h) account assets 155 158 Total other postretirement benefit plan assets $ 367 $ 367 (a) In accordance with accounting guidance certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position. (b) Receivables and payables represent amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received. Investments in money market funds represent investments in funds that invest primarily in a diversified portfolio of investment grade money market instruments, including, but not limited to, commercial paper, notes, repurchase agreements and other evidences of indebtedness with a maturity not exceeding 13 months from the date of purchase. The primary objective of the fund is a level of current income consistent with stability of principal and liquidity. Redemptions can be made daily on this fund. Investments in large-cap equity securities represent investments in a passively managed equity index fund that invests in securities and a combination of other collective funds. Fair value measurements are not obtained from a quoted price in an active market but are based on firm quotes of net asset values per share as provided by the trustee of the fund. Redemptions can be made daily on this fund. Investments in commingled debt securities represent investments in a fund that invests in a diversified portfolio of investment grade long-duration fixed income securities. Redemptions can be made daily on these funds. Investments in corporate bonds represent investment in a diversified portfolio of investment grade long-duration fixed income securities. The fair value of debt securities are generally based on evaluations that reflect observable market information, such as actual trade information for identical securities or for similar securities, adjusted for observable differences. Investments in U.S. Treasury and U.S. government sponsored agencies represent securities included in a portfolio of investment-grade long-duration fixed income. The fair value of debt securities are generally based on evaluations that reflect observable market information, such as actual trade information for identical securities or for similar securities, adjusted for observable differences. Expected Cash Flows - Defined Benefit Plans (PPL) PPL does not plan to contribute to its pension plans in 2022, as PPL's defined benefit pension plans have the option to utilize available prior year credit balances to meet current and future contribution requirements. PPL sponsors various non-qualified supplemental pension plans for which no assets are segregated from corporate assets. PPL expects to make approximately $10 million of benefit payments under these plans in 2022. PPL is not required to make contributions to its other postretirement benefit plans but has historically funded these plans in amounts equal to the postretirement benefit costs recognized. Continuation of this past practice would cause PPL to contribute $22 million to its other postretirement benefit plans in 2022. The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid by the plans and the following federal subsidy payments are expected to be received by PPL. Other Postretirement Pension Benefit Expected 2022 $ 207 $ 44 $ 1 2023 207 42 — 2024 204 41 — 2025 204 40 — 2026 202 38 — 2027-2030 946 176 1 Savings Plans (All Registrants) Substantially all employees of PPL's subsidiaries are eligible to participate in deferred savings plans (401(k)s). Employer contributions to the plans were: 2021 2020 2019 PPL $ 29 $ 29 $ 30 PPL Electric 5 6 6 LG&E 7 6 6 KU 5 5 5

Jointly Owned Facilities

Jointly Owned Facilities	12 Months Ended
	Dec. 31, 2021
Jointly Owned Facilities [Line Items]
Jointly Owned Facilities	(PPL, LG&E and KU) At December 31, 2021 and 2020, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL December 31, 2021 Trimble County Unit 1 75.00 % $ 457 $ 79 $ — Trimble County Unit 2 75.00 % 1,360 247 121 December 31, 2020 Trimble County Unit 1 75.00 % $ 440 $ 64 $ 2 Trimble County Unit 2 75.00 % 1,340 227 106 Ownership Electric Plant Accumulated Construction LG&E December 31, 2021 E.W. Brown Units 6-7 38.00 % $ 53 $ 24 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 25 — Trimble County Unit 1 75.00 % 457 79 — Trimble County Unit 2 14.25 % 379 57 64 Trimble County Units 5-6 29.00 % 36 15 — Trimble County Units 7-10 37.00 % 81 34 — Cane Run Unit 7 22.00 % 125 19 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 2 — — December 31, 2020 E.W. Brown Units 6-7 38.00 % $ 46 $ 22 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 22 — Trimble County Unit 1 75.00 % 440 64 2 Trimble County Unit 2 14.25 % 370 51 54 Trimble County Units 5-6 29.00 % 33 14 1 Trimble County Units 7-10 37.00 % 77 31 1 Cane Run Unit 7 22.00 % 123 15 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 2 — — KU December 31, 2021 E.W. Brown Units 6-7 62.00 % $ 88 $ 40 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 22 — Trimble County Unit 2 60.75 % 981 190 57 Trimble County Units 5-6 71.00 % 84 36 — Trimble County Units 7-10 63.00 % 133 57 — Cane Run Unit 7 78.00 % 444 70 — E.W. Brown Solar Unit 61.00 % 16 4 — Solar Share 56.00 % 3 — — December 31, 2020 E.W. Brown Units 6-7 62.00 % $ 76 $ 37 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 20 — Trimble County Unit 2 60.75 % 970 176 52 Trimble County Units 5-6 71.00 % 77 33 4 Trimble County Units 7-10 63.00 % 129 53 2 Cane Run Unit 7 78.00 % 443 57 2 E.W. Brown Solar Unit 61.00 % 16 3 — Solar Share 56.00 % 2 — — Each subsidiary owning these interests provides its own funding for its share of the facility. Each receives a portion of the total output of the generating plants equal to its percentage ownership. The share of fuel and other operating costs associated with the plants is included in the corresponding operating expenses on the Statements of Income.
Louisville Gas And Electric Co [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Facilities	(PPL, LG&E and KU) At December 31, 2021 and 2020, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL December 31, 2021 Trimble County Unit 1 75.00 % $ 457 $ 79 $ — Trimble County Unit 2 75.00 % 1,360 247 121 December 31, 2020 Trimble County Unit 1 75.00 % $ 440 $ 64 $ 2 Trimble County Unit 2 75.00 % 1,340 227 106 Ownership Electric Plant Accumulated Construction LG&E December 31, 2021 E.W. Brown Units 6-7 38.00 % $ 53 $ 24 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 25 — Trimble County Unit 1 75.00 % 457 79 — Trimble County Unit 2 14.25 % 379 57 64 Trimble County Units 5-6 29.00 % 36 15 — Trimble County Units 7-10 37.00 % 81 34 — Cane Run Unit 7 22.00 % 125 19 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 2 — — December 31, 2020 E.W. Brown Units 6-7 38.00 % $ 46 $ 22 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 22 — Trimble County Unit 1 75.00 % 440 64 2 Trimble County Unit 2 14.25 % 370 51 54 Trimble County Units 5-6 29.00 % 33 14 1 Trimble County Units 7-10 37.00 % 77 31 1 Cane Run Unit 7 22.00 % 123 15 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 2 — — KU December 31, 2021 E.W. Brown Units 6-7 62.00 % $ 88 $ 40 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 22 — Trimble County Unit 2 60.75 % 981 190 57 Trimble County Units 5-6 71.00 % 84 36 — Trimble County Units 7-10 63.00 % 133 57 — Cane Run Unit 7 78.00 % 444 70 — E.W. Brown Solar Unit 61.00 % 16 4 — Solar Share 56.00 % 3 — — December 31, 2020 E.W. Brown Units 6-7 62.00 % $ 76 $ 37 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 20 — Trimble County Unit 2 60.75 % 970 176 52 Trimble County Units 5-6 71.00 % 77 33 4 Trimble County Units 7-10 63.00 % 129 53 2 Cane Run Unit 7 78.00 % 443 57 2 E.W. Brown Solar Unit 61.00 % 16 3 — Solar Share 56.00 % 2 — — Each subsidiary owning these interests provides its own funding for its share of the facility. Each receives a portion of the total output of the generating plants equal to its percentage ownership. The share of fuel and other operating costs associated with the plants is included in the corresponding operating expenses on the Statements of Income.
Kentucky Utilities Co [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Facilities	(PPL, LG&E and KU) At December 31, 2021 and 2020, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL December 31, 2021 Trimble County Unit 1 75.00 % $ 457 $ 79 $ — Trimble County Unit 2 75.00 % 1,360 247 121 December 31, 2020 Trimble County Unit 1 75.00 % $ 440 $ 64 $ 2 Trimble County Unit 2 75.00 % 1,340 227 106 Ownership Electric Plant Accumulated Construction LG&E December 31, 2021 E.W. Brown Units 6-7 38.00 % $ 53 $ 24 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 25 — Trimble County Unit 1 75.00 % 457 79 — Trimble County Unit 2 14.25 % 379 57 64 Trimble County Units 5-6 29.00 % 36 15 — Trimble County Units 7-10 37.00 % 81 34 — Cane Run Unit 7 22.00 % 125 19 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 2 — — December 31, 2020 E.W. Brown Units 6-7 38.00 % $ 46 $ 22 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 22 — Trimble County Unit 1 75.00 % 440 64 2 Trimble County Unit 2 14.25 % 370 51 54 Trimble County Units 5-6 29.00 % 33 14 1 Trimble County Units 7-10 37.00 % 77 31 1 Cane Run Unit 7 22.00 % 123 15 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 2 — — KU December 31, 2021 E.W. Brown Units 6-7 62.00 % $ 88 $ 40 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 22 — Trimble County Unit 2 60.75 % 981 190 57 Trimble County Units 5-6 71.00 % 84 36 — Trimble County Units 7-10 63.00 % 133 57 — Cane Run Unit 7 78.00 % 444 70 — E.W. Brown Solar Unit 61.00 % 16 4 — Solar Share 56.00 % 3 — — December 31, 2020 E.W. Brown Units 6-7 62.00 % $ 76 $ 37 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 20 — Trimble County Unit 2 60.75 % 970 176 52 Trimble County Units 5-6 71.00 % 77 33 4 Trimble County Units 7-10 63.00 % 129 53 2 Cane Run Unit 7 78.00 % 443 57 2 E.W. Brown Solar Unit 61.00 % 16 3 — Solar Share 56.00 % 2 — — Each subsidiary owning these interests provides its own funding for its share of the facility. Each receives a portion of the total output of the generating plants equal to its percentage ownership. The share of fuel and other operating costs associated with the plants is included in the corresponding operating expenses on the Statements of Income.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2021
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Energy Purchase Commitments (PPL, LG&E and KU) LG&E and KU enter into purchase contracts to supply the coal and natural gas requirements for generation facilities and LG&E's retail natural gas supply operations. These contracts include the following commitments: Contract Type Maximum Maturity Natural Gas Fuel 2024 Natural Gas Retail Supply 2023 Coal 2026 Coal Transportation and Fleeting Services 2027 Natural Gas Transportation 2026 LG&E and KU have a power purchase agreement with OVEC expiring in June 2040. See footnote (c) to the table in "Guarantees and Other Assurances" below for information on the OVEC power purchase contract, including recent developments in credit or debt conditions relating to OVEC. Future obligations for power purchases from OVEC are demand payments, comprised of debt-service payments and contractually-required reimbursements of plant operating, maintenance and other expenses, and are projected as follows: LG&E KU Total 2022 $ 23 $ 10 $ 33 2023 23 10 33 2024 22 10 32 2025 22 10 32 2026 22 10 32 Thereafter 218 96 314 Total $ 330 $ 146 $ 476 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2021 2020 2019 LG&E $ 13 $ 12 $ 15 KU 6 6 7 Total $ 19 $ 18 $ 22 Legal Matters (All Registrants) PPL and its subsidiaries are involved in legal proceedings, claims and litigation in the ordinary course of business. PPL and its subsidiaries cannot predict the outcome of such matters, or whether such matters may result in material liabilities, unless otherwise noted. Talen Litigation (PPL) Background In September 2013, one of PPL's former subsidiaries, PPL Montana entered into an agreement to sell its hydroelectric generating facilities. In June 2014, PPL and PPL Energy Supply, the parent company of PPL Montana, entered into various definitive agreements with affiliates of Riverstone to spin off PPL Energy Supply and ultimately combine it with Riverstone's competitive power generation businesses to form a stand-alone company named Talen Energy. In November 2014, after executing the spinoff agreements but prior to the closing of the spinoff transaction, PPL Montana closed the sale of its hydroelectric generating facilities. Subsequently, on June 1, 2015, the spinoff of PPL Energy Supply was completed. Following the spinoff transaction, PPL had no continuing ownership interest in or control of PPL Energy Supply. In connection with the spinoff transaction, PPL Montana became Talen Montana, LLC (Talen Montana), a subsidiary of Talen Energy. Talen Energy Marketing also became a subsidiary of Talen Energy as a result of the June 2015 spinoff of PPL Energy Supply. Talen Energy has owned and operated both Talen Montana and Talen Energy Marketing since the spinoff. At the time of the spinoff, affiliates of Riverstone acquired a 35% ownership interest in Talen Energy. Riverstone subsequently acquired the remaining interests in Talen Energy in a take private transaction in December 2016. Talen Montana Retirement Plan and Talen Energy Marketing, LLC, Individually and on Behalf of All Others Similarly Situated v. PPL Corporation et al. On October 29, 2018, Talen Montana Retirement Plan and Talen Energy Marketing filed a putative class action complaint on behalf of current and contingent creditors of Talen Montana who allegedly suffered harm or allegedly will suffer reasonably foreseeable harm as a result of the November 2014 distribution of proceeds from the sale of then-PPL Montana's hydroelectric generating facilities. The action was filed in the Sixteenth Judicial District of the State of Montana, Rosebud County, against PPL and certain of its affiliates and current and former officers and directors (Talen Putative Class Action). Plaintiff asserts claims for, among other things, fraudulent transfer, both actual and constructive; recovery against subsequent transferees; civil conspiracy; aiding and abetting tortious conduct; and unjust enrichment. Plaintiff is seeking avoidance of the purportedly fraudulent transfer, unspecified damages, including punitive damages, the imposition of a constructive trust, and other relief. In December 2018, PPL removed the Talen Putative Class Action from the Sixteenth Judicial District of the State of Montana to the United States District Court for the District of Montana, Billings Division (MT Federal Court). In January 2019, the plaintiff moved to remand the Talen Putative Class Action back to state court, and dismissed without prejudice all current and former PPL Corporation directors from the case. In September 2019, the MT Federal Court granted plaintiff's motion to remand the case back to state court. Although, the PPL defendants petitioned the Ninth Circuit Court of Appeals to grant an appeal of the remand decision, in November 2019, the Ninth Circuit Court of Appeals denied that request and in December 2019, Talen Montana Retirement Plan filed a Second Amended Complaint in the Sixteenth Judicial District of the State of Montana, Rosebud County, which removed Talen Energy Marketing as a plaintiff. In January 2020, PPL defendants filed a motion to dismiss the Second Amended Complaint or, in the alternative, to stay the proceedings pending the resolution of the below mentioned Delaware Action. The Court held a hearing on June 24, 2020 regarding the motions. On September 11, 2020, the Court granted PPL defendants' alternative Motion for a Stay of the proceedings. PPL Corporation et al. vs. Riverstone Holdings LLC, Talen Energy Corporation et al. On November 30, 2018, PPL, certain PPL affiliates, and certain current and former officers and directors (PPL plaintiffs) filed a complaint in the Court of Chancery of the State of Delaware seeking various forms of relief against Riverstone, Talen Energy and certain of their affiliates (Delaware Action), in response to and as part of the defense strategy for an action filed by Talen Montana, LLC (the Talen Direct Action, since dismissed) and the Talen Putative Class Action described above (together, the Montana Actions) originally filed in Montana state court in October 2018. In the complaint, the PPL plaintiffs ask the Delaware Court of Chancery for declaratory and injunctive relief. This includes a declaratory judgment that, under the separation agreement governing the spinoff of PPL Energy Supply, all related claims that arise must be heard in Delaware; that the statute of limitations in Delaware and the spinoff agreement bar these claims at this time; that PPL is not liable for the claims in either the Talen Direct Action or the Talen Putative Class Action as PPL Montana was solvent at all relevant times; and that the separation agreement requires that Talen Energy indemnify PPL for all losses arising from the debts of Talen Montana, among other things. PPL's complaint also seeks damages against Riverstone for interfering with the separation agreement and against Riverstone affiliates for breach of the implied covenant of good faith and fair dealing. The complaint was subsequently amended on January 11, 2019 and March 20, 2019, to include, among other things, claims related to indemnification with respect to the Montana Actions, request a declaration that the Montana Actions are time-barred under the spinoff agreements, and allege additional facts to support the tortious interference claim. In April 2019, the defendants filed motions to dismiss the amended complaint. In July 2019, the Court heard oral arguments from the parties regarding the motions to dismiss, and in October 2019, the Delaware Court of Chancery issued an opinion sustaining all of the PPL plaintiffs' claims except for the claim for breach of implied covenant of good faith and fair dealing. As a result of the dismissal of the Talen Direct Action in December 2019, in January 2020, Talen Energy filed a new motion to dismiss five of the remaining eight claims in the amended complaint. The Court heard oral argument on the motion to dismiss on May 28, 2020, and on June 22, 2020, issued an opinion denying the motion in its entirety. Discovery is proceeding, and the parties have filed certain motions and cross-motions for summary judgment, which are not yet scheduled for hearing. The trial was previously scheduled for February 2022, but has been rescheduled for July 2022. With respect to each of the Talen-related matters described above, PPL believes that the 2014 distribution of proceeds was made in compliance with all applicable laws and that PPL Montana was solvent at all relevant times. Additionally, the agreements entered into in connection with the spinoff, which PPL and affiliates of Talen Energy and Riverstone negotiated and executed prior to the 2014 distribution, directly address the treatment of the proceeds from the sale of PPL Montana's hydroelectric generating facilities; in those agreements, Talen Energy and Riverstone definitively agreed that PPL was entitled to retain the proceeds. PPL believes that it has meritorious defenses to the claims made in the Talen Putative Class Action and intends to continue to vigorously defend against this action. The Talen Putative Class Action was stayed at an early stage of litigation. While the Delaware Action is progressing, at this time PPL cannot predict the outcome of either of these matters or estimate the range of possible losses, if any, that PPL might incur as a result of the claims, although they could be material. Cane Run Environmental Claims (PPL and LG&E) In December 2013, six residents, on behalf of themselves and others similarly situated, filed a class action complaint against LG&E and PPL in the U.S. District Court for the Western District of Kentucky (U.S. District Court) alleging violations of the Clean Air Act, RCRA, and common law claims of nuisance, trespass and negligence. In July 2014, the U.S. District Court dismissed the RCRA claims and all but one Clean Air Act claim, but declined to dismiss the common law tort claims. In February 2017, the U.S. District Court dismissed PPL as a defendant and dismissed the final federal claim against LG&E, and in April 2017, issued an Order declining to exercise supplemental jurisdiction on the state law claims dismissing the case in its entirety. In June 2017, the plaintiffs filed a class action complaint in Jefferson County, Kentucky Circuit Court, against LG&E alleging state law nuisance, negligence and trespass tort claims. The plaintiffs sought compensatory and punitive damages for alleged property damage due to purported plant emissions on behalf of a class of residents within one to three miles of the plant. On January 8, 2020, the Jefferson Circuit Court issued an order denying the plaintiffs’ request for class certification. On January 14, 2020, the plaintiffs filed a notice of appeal in the Kentucky Court of Appeals. On December 11, 2020, the Court of Appeals issued an order affirming the lower court’s denial of class certification. In December 2020, plaintiffs filed a petition for discretionary review with the Kentucky Supreme Court. On April 20, 2021, the Kentucky Supreme Court denied further review of the lower court order. The case was remanded to the Jefferson Circuit Court for the claims of the three remaining petitioners. Settlements with two of the three remaining petitioners were reached with none of the settlements having or expected to have a significant impact on LG&E's operations or financial condition. E.W. Brown Environmental Claims (PPL and KU) In July 2017, the Kentucky Waterways Alliance and the Sierra Club filed a citizen suit complaint against KU in the U.S. District Court for the Eastern District of Kentucky (U.S. District Court) alleging discharges at the E.W. Brown plant in violation of the Clean Water Act and the plant's water discharge permit and alleging contamination that may present an imminent and substantial endangerment in violation of the RCRA. The plaintiffs' suit relates to prior notices of intent to file a citizen suit submitted in October and November 2015 and October 2016. These plaintiffs sought injunctive relief ordering KU to take all actions necessary to comply with the Clean Water Act and RCRA, including ceasing the discharges in question, abating effects associated with prior discharges and eliminating the alleged imminent and substantial endangerment. These plaintiffs also sought assessment of civil penalties and an award of litigation costs and attorney fees. In December 2017, the U.S. District Court issued an Order dismissing the Clean Water Act and RCRA complaints against KU in their entirety. In January 2018, the plaintiffs appealed the dismissal Order to the U.S. Court of Appeals for the Sixth Circuit. In September 2018, the U.S. Court of Appeals for the Sixth Circuit issued its ruling affirming the lower court's decision to dismiss the Clean Water Act claims but reversing its dismissal of the RCRA claims against KU and remanding the latter to the U.S. District Court. In January 2019, KU filed an answer to plaintiffs’ complaint in the U.S. District Court. In May 2021, the U.S. District Court issued an order granting KU's motion for summary judgment and dismissed the case. In June 2021, the plaintiffs appealed the district court's order to the U.S. Court of Appeals for the Sixth Circuit. In September 2021, the parties entered into a settlement agreement, providing for dismissal of the appellate proceedings and release of other claims. KU is undertaking extensive remedial measures at the E.W. Brown plant including closure of the former ash pond, implementation of a groundwater remedial action plan and performance of a corrective action plan including aquatic study of adjacent surface waters and risk assessment. The aquatic study and risk assessment are being undertaken pursuant to a 2017 agreed Order with the Kentucky Energy and Environment Cabinet (KEEC). KU conducted sampling of Herrington Lake in 2017 and 2018. In June 2019, KU submitted to the KEEC the required aquatic study and risk assessment, conducted by an independent third-party consultant, finding that discharges from the E.W. Brown plant have not had any significant impact on Herrington Lake and that the water in the lake is safe for recreational use and meets safe drinking water standards. On May 31, 2021, the KEEC approved the report and released a response to public comments. On August 6, 2021, KU submitted a Supplemental Remedial Alternatives Analysis (SRAA) report to the KEEC that outlines proposed additional fish, water, and sediment testing. KU has submitted a response to the KEEC's comments and expects to undertake the proposed testing in the spring of 2022. Air (PPL and LG&E) Sulfuric Acid Mist Emissions In June 2016, the EPA issued a notice of violation under the Clean Air Act alleging that LG&E violated applicable rules relating to sulfuric acid mist emissions at its Mill Creek plant. The notice alleges failure to install proper controls, failure to operate the facility consistent with good air pollution control practice and causing emissions exceeding applicable requirements or constituting a nuisance or endangerment. LG&E believes it has complied with applicable regulations during the relevant time period. On July 31, 2020, the U.S. Department of Justice and Louisville Metro Air Pollution Control District filed a complaint in the U.S. District Court for the Western District of Kentucky alleging violations specified in the EPA notice of violation and seeking civil penalties and injunctive relief. In October 2020, LG&E filed a motion to dismiss the complaint. In December 2020, the U.S. Department of Justice and the Louisville Metro Air Pollution Control District filed an amended complaint. In February 2021, LG&E filed a renewed motion to dismiss regarding the amended complaint. In September 2021, the parties reached a tentative agreement providing for dismissal of the court action, the payment by LG&E of a penalty amount and performance of a supplemental environmental project (SEP). The parties have entered a Consent Decree, which is awaiting approval from the U.S. District Court for the Western District of Kentucky. PPL and LG&E are unable to predict the final outcome of this matter but do not believe the matter, including the agreed penalty and SEP, will have a significant impact on LG&E's operations or financial condition. Water/Waste (PPL, LG&E and KU) ELGs In 2015, the EPA finalized ELGs for wastewater discharge permits for new and existing steam electricity generating facilities. These guidelines require deployment of additional control technologies providing physical, chemical and biological treatment and mandate operational changes including "no discharge" requirements for certain wastewaters. The implementation date for individual generating stations was to be determined by the states on a case-by-case basis according to criteria provided by the EPA. Legal challenges to the final rule were consolidated before the U.S. Court of Appeals for the Fifth Circuit. In April 2017, the EPA announced that it would grant petitions for reconsideration of the rule. In September 2017, the EPA issued a rule to postpone the compliance date for certain requirements. On October 13, 2020, the EPA published final revisions to its best available technology standards for certain wastewaters and potential extensions to compliance dates (the Reconsideration Rule). The rule is expected to be implemented by the states or applicable permitting authorities in the course of their normal permitting activities. LG&E and KU are currently implementing responsive compliance strategies and schedules. Certain aspects of these compliance plans and estimates relate to developments in state water quality standards, which are separate from the ELG rule or its implementation. Certain costs are included in the Registrants' capital plans and expected to be recovered from customers through rate recovery mechanisms, but additional costs and recovery will depend on further regulatory developments at the state level. In August 2021, the EPA published a notice of rulemaking announcing that it will propose revisions to the Reconsideration Rule and determine "whether more stringent limitations and standards are appropriate." Compliance with the Reconsideration Rule is required during the pendency of the rulemaking process. CCRs In 2015, the EPA issued a final rule governing management of CCRs which include fly ash, bottom ash and sulfur dioxide scrubber wastes. The CCR Rule imposes extensive new requirements for certain CCR impoundments and landfills, including public notifications, location restrictions, design and operating standards, groundwater monitoring and corrective action requirements, and closure and post-closure care requirements, and specifies restrictions relating to the beneficial use of CCRs. In July 2018, the EPA issued a final rule extending the deadline for closure of certain impoundments and adopting other substantive changes. In August 2018, the D.C. Circuit Court of Appeals vacated and remanded portions of the CCR Rule. In December 2019, the EPA addressed the deficiencies identified by the court and proposed amendments to change the closure deadline. In August 2020, the EPA published a final rule extending the deadline to initiate closure to April 11, 2021, while providing for certain extensions. The EPA is conducting ongoing rulemaking actions regarding various other amendments to the rule. Certain ongoing legal challenges to various provisions of the CCR Rule have been held in abeyance pending review by the EPA pursuant to the President's executive order. PPL, LG&E, and KU are monitoring the EPA’s ongoing efforts to refine and implement the regulatory program under the CCR Rule. In January 2022, the EPA issued several proposed regulatory determinations, facility notifications, and public announcements which indicate increased scrutiny by the EPA to determine the adequacy of measures taken by facility owners and operators to achieve closure of CCR surface impoundments and landfills. In particular, the agency indicated that it will focus on certain practices which it views as posing a threat of continuing groundwater contamination. Future guidance, regulatory determinations, rulemakings, and other developments could potentially require revisions to current LG&E and KU compliance plans including additional monitoring and remediation at surface impoundments and landfills, the cost of which could be substantial. PPL, LG&E and KU are unable to predict the outcome of the ongoing litigation, rulemaking, and regulatory determinations or potential impacts on current LG&E and KU compliance plans. The Registrants are currently finalizing closure plans and schedules. In January 2017, Kentucky issued a new state rule relating to CCR management, effective May 2017, aimed at reflecting the requirements of the federal CCR rule. As a result of a subsequent legal challenge, in January 2018, the Franklin County, Kentucky Circuit Court issued an opinion invalidating certain procedural elements of the rule. LG&E and KU presently operate their facilities under continuing permits authorized under the former program and do not currently anticipate material impacts as a result of the judicial ruling. Associated costs are expected to be subject to rate recovery. LG&E and KU received KPSC approval for a compliance plan providing for the closure of impoundments at the Mill Creek, Trimble County, E.W. Brown, and Ghent stations, and construction of process water management facilities at those plants. In addition to the foregoing measures required for compliance with the federal CCR rule, KU also received KPSC approval for its plans to close impoundments at the retired Green River, Pineville and Tyrone plants to comply with applicable state law. As of April 2021, LG&E and KU have commenced closure of all of the subject impoundments and have completed closure of some of their smaller impoundments. LG&E and KU generally expect to complete impoundment closures within five years of commencement, although a longer period may be required to complete closure of some facilities. Associated costs are expected to be subject to rate recovery. In connection with the final CCR rule, LG&E and KU recorded adjustments to existing AROs beginning in 2015 and continue to record adjustments as required. See Note 20 for additional information. Further changes to AROs, current capital plans or operating costs may be required as estimates are refined based on closure developments, groundwater monitoring results, and regulatory or legal proceedings. Costs relating to this rule are expected to be subject to rate recovery. (All Registrants) Superfund and Other Remediation PPL Electric, LG&E and KU are potentially responsible for investigating and remediating contamination under the federal Superfund program and similar state programs. Actions are under way at certain sites including former coal gas manufacturing plants in Pennsylvania and Kentucky previously owned or operated by, or currently owned by predecessors or affiliates of, PPL Electric, LG&E and KU. PPL Electric is potentially responsible for a share of clean-up costs at certain sites including the Columbia Gas Plant site and the Brodhead site. Cleanup actions have been or are being undertaken at these sites as requested by governmental agencies, the costs of which have not been and are not expected to be significant to PPL Electric. At December 31, 2021 and December 31, 2020, PPL Electric had a recorded liability of $10 million representing its best estimate of the probable loss incurred to remediate the sites identified above. Depending on the outcome of investigations at identified sites where investigations have not begun or been completed, or developments at sites for which information is incomplete, additional costs of remediation could be incurred. PPL Electric, LG&E and KU lack sufficient information about such additional sites to estimate any potential liability or range of reasonably possible losses, if any, related to these sites. Such costs, however, are not currently expected to be significant. The EPA is evaluating the risks associated with polycyclic aromatic hydrocarbons and naphthalene, chemical by-products of coal gas manufacturing. As a result, individual states may establish stricter standards for water quality and soil cleanup, that could require several PPL subsidiaries to take more extensive assessment and remedial actions at former coal gas manufacturing plants. The Registrants cannot reasonably estimate a range of possible losses, if any, related to these matters. Regulatory Issues See Note 7 for information on regulatory matters related to utility rate regulation. Electricity - Reliability Standards The NERC is responsible for establishing and enforcing mandatory reliability standards (Reliability Standards) regarding the bulk electric system in North America. The FERC oversees this process and independently enforces the Reliability Standards. The Reliability Standards have the force and effect of law and apply to certain users of the bulk electric system, including electric utility companies, generators and marketers. Under the Federal Power Act, the FERC may assess civil penalties for certain violations. PPL Electric, LG&E and KU monitor their compliance with the Reliability Standards and self-report or self-log potential violations of applicable reliability requirements whenever identified, and submit accompanying mitigation plans, as required. The resolution of a small number of potential violations is pending. Penalties incurred to date have not been significant. Any Regional Reliability Entity determination concerning the resolution of violations of the Reliability Standards remains subject to the approval of the NERC and the FERC. In the course of implementing their programs to ensure compliance with the Reliability Standards by those PPL affiliates subject to the standards, certain other instances of potential non-compliance may be identified from time to time. The Registrants cannot predict the outcome of these matters, and an estimate or range of possible losses cannot be determined. Gas - Security Directives (PPL and LG&E) In May and July of 2021, the Department of Homeland Security’s (DHS) Transportation Security Administration (TSA) released two security directives applicable to certain notified owners and operators of natural gas pipeline facilities (including local distribution companies) that TSA has determined to be critical. The first security directive required notified owners/operators to implement cybersecurity incident reporting to the DHS, designate a cybersecurity coordinator, and perform a gap assessment of current entity cybersecurity practices against certain voluntary TSA security guidelines and report relevant results and proposed mitigation to applicable DHS agencies. The second security directive requires notified entities to implement a significant number of specified cyber security controls and processes. LG&E does not believe the security directives will have a significant impact on LG&E’s operations or financial condition. Other Guarantees and Other Assurances (All Registrants) In the normal course of business, the Registrants enter into agreements that provide financial performance assurance to third parties on behalf of certain subsidiaries. Examples of such agreements include: guarantees, stand-by letters of credit issued by financial institutions and surety bonds issued by insurance companies. These agreements are entered into primarily to support or enhance the creditworthiness attributed to a subsidiary on a stand-alone basis or to facilitate the commercial activities in which these subsidiaries engage. (PPL) PPL fully and unconditionally guarantees all of the debt obligations of PPL Capital Funding. (All Registrants) The table below details guarantees provided as of December 31, 2021. "Exposure" represents the estimated maximum potential amount of future payments that could be required to be made under the guarantee. The probability of expected payment/performance under each of these guarantees is remote. For reporting purposes, on a consolidated basis, the guarantees of PPL include the guarantees of its subsidiary Registrants. Exposure at December 31, 2021 Expiration PPL Indemnifications related to the sale of the U.K. utility business (a) Indemnifications related to certain tax liabilities related to the sale of the U.K. utility business £ 50 (b) 2028 LG&E and KU LG&E and KU obligation of shortfall related to OVEC (c) (a) PPL WPD Limited agreed to provide a standard indemnity regarding “leakage” amounts, which included amounts taken out of the sold assets through dividends, return of capital, bonuses or similar method, received or waived by WPD (or its affiliates defined as members of the Sellers Group in the SPA) during the period from April 1, 2020 through June 14, 2021, except such amounts permitted under the WPD SPA. The amount of the cap on this indemnity was £7,881 million, the amount paid to PPL WPD Limited at closing. This indemnification expired in December 2021 and no claims have been made. (b) PPL WPD Limited entered into a Tax Deed dated June 9, 2021 in which it agreed to a tax indemnity regarding certain potential tax liabilities of the entities sold with respect to periods prior to the completion of the sale, subject to customary exclusions and limitations. Because National Grid Holdings One plc, the buyer, agreed to purchase indemnity insurance, the amount of the cap on the indemnity for these liabilities is £1, except with respect to certain surrenders of tax losses, for which the amount of the cap on the indemnity is £50 million. (c) Pursuant to the OVEC power purchase contract, LG&E and KU are obligated to pay for their share of OVEC's excess debt service, post-retirement and decommissioning costs, as well as any shortfall from amounts included within a demand charge designed and expected to cover these costs over the term of the contract. PPL's proportionate share of OVEC's outstanding debt was $92 million at December 31, 2021, consisting of LG&E's share of $64 million and KU's share of $28 million. The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchase Commitments" above for additional information on the OVEC power purchase contract. In March 2018, a sponsor with a 4.85% pro-rata share of OVEC obligations filed for bankruptcy under Chapter 11 and, in August 2018, received a rejection order for the OVEC power purchase contract in the bankruptcy proceeding. OVEC and other entities challenged the contract rejection, the bankruptcy plan confirmation and regulatory aspects of the plan in various forums. In May 2020, OVEC and the relevant sponsor announced a settlement resolving all disputed matters in the bankruptcy and other proceedings, including providing that the sponsor will withdraw its request to reject the power purchase agreement. The settlement was implemented in July 2020. The Registrants provide other miscellaneous guarantees through contracts entered into in the normal course of business. These guarantees are primarily in the form of indemnification or warranties related to services or equipment and vary in duration. The amounts of these guarantees often are not explicitly stated, and the overall maximum amount of the obligation under such guarantees cannot be reasonably estimated. Historically, no significant payments have been made with respect to these types of guarantees and the probability of payment/performance under these guarantees is remote. PPL, on behalf of itself and certain of its subsidiaries, maintains insurance that covers liability assumed under contract for bodily injury and property damage. The coverage provides maximum aggregate coverage of $225 million. This insurance may be applicable to obligations under certain of these contractual arrangements. Risks and Uncertainties (All Registrants) The COVID-19 pandemic has disrupted the U.S. and global economies and continues to present challenges to businesses, communities, workforces, markets and increasingly to supply chains. In the U.S. and throughout the world, governmental authorities have taken actions to contain the spread of the virus and mitigate known or foreseeable impacts. In the Registrants’ service territories, mitigation measures have included quarantines, stay-at-home orders, travel restrictions, reduced operations or closures of businesses, schools and governmental agencies, and executive, legislative or regulatory actions to address health or other

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2021
PPL Electric Utilities Corp [Member]
Related Party Transactions [Line Items]
Related Party Transactions	Wholesale Sales and Purchases (LG&E and KU) LG&E and KU jointly dispatch their generation units with the lowest cost generation used to serve their retail customers. When LG&E has excess generation capacity after serving its own retail customers and its generation cost is lower than that of KU, KU purchases electricity from LG&E and vice versa. These transactions are reflected in the Statements of Income as "Electric revenue from affiliate" and "Energy purchases from affiliate" and are recorded at a price equal to the seller's fuel cost plus any split savings. Savings realized from such intercompany transactions are shared equally between both companies. The volume of energy each company has to sell to the other is dependent on its retail customers' needs and its available generation. Support Costs (PPL Electric, LG&E and KU) PPL Services, PPL EU Services, prior to its merger into PPL Services as of December 31, 2021, and LKS provide the Registrants and each other with administrative, management and support services. For all services companies, the costs of directly assignable and attributable services are charged to the respective recipients as direct support costs. General costs that cannot be directly attributed to a specific entity are allocated and charged to the respective recipients as indirect support costs. PPL Services and PPL EU Services use a three-factor methodology that includes the applicable recipients' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. PPL Services may also use a ratio of overall direct and indirect costs or a weighted average cost ratio. LKS bases its indirect allocations on the subsidiaries' number of employees, total assets, revenues, number of customers and/or other statistical information. PPL Services, PPL EU Services and LKS charged the following amounts for the years ended December 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable. 2021 2020 2019 PPL Electric from PPL Services $ 54 $ 50 $ 59 PPL Electric from PPL EU Services 222 176 152 LG&E from LKS 169 170 160 KU from LKS 179 180 178 In addition to the charges for services noted above, LKS makes payments on behalf of LG&E and KU for fuel purchases and other costs for products or services provided by third parties. LG&E and KU also provide services to each other and to LKS. Billings between LG&E and KU relate to labor and overheads associated with union and hourly employees performing work for the other company, charges related to jointly-owned generating units and other miscellaneous charges. Tax settlements between PPL and LG&E and KU are reimbursed through LKS. Intercompany Borrowings (PPL Electric) PPL Energy Funding maintains a $1,200 million revolving line of credit with a PPL Electric subsidiary. At December 31, 2021, PPL Energy Funding had borrowings outstanding in the amount of $499 million. This balance is reflected in "Notes receivable from affiliate" on the PPL Electric balance sheet. No balance was outstanding at December 31, 2020. The interest rates on borrowings are equal to one-month LIBOR plus a spread. Interest income is reflected in "Interest Income from Affiliate" on the Income Statements. (LG&E) LG&E participates in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E funds up to the difference between LG&E's FERC borrowing limit and LG&E's commercial paper limit at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on LIBOR. LG&E's money pool borrowing limit is $325 million. At December 31, 2021, LG&E had borrowings outstanding from LKE in the amount of $324 million. This balance is reflected in "Notes payable with affiliates" on the LG&E balance sheets. No balances were outstanding at December 31, 2020. (KU) KU participates in an intercompany money pool agreement whereby LKE and/or LG&E make available to KU funds up to the difference between KU's FERC borrowing limit and KU's commercial paper limit at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on LIBOR. KU's money pool borrowing limit is $300 million. At December 31, 2021, KU had borrowings outstanding from LKE in the amount of $294 million. This balance is reflected in "Notes payable with affiliates" on the KU balance sheets. No balances were outstanding at December 31, 2020. VEBA Funds Receivable (PPL Electric) In May 2018, PPL received a favorable private letter ruling from the IRS permitting a transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to a new subaccount within the VEBA, to be used to pay medical claims of active bargaining unit employees. Based on PPL Electric's participation in PPL’s Other Postretirement Benefit plan, PPL Electric was allocated a portion of the excess funds from PPL Services. These funds have been recorded as an intercompany receivable on the Balance Sheets. The receivable balance decreases as PPL Electric pays incurred medical claims and is reimbursed by PPL Services. The intercompany receivable balance associated with these funds was $11 million as of December 31, 2021, of which $10 million was reflected in "Accounts receivable from affiliates" and $1 million was reflected in "Other noncurrent assets" on the Balance Sheets. The intercompany receivable balance associated with these funds was $22 million as of December 31, 2020, of which $10 million was reflected in "Accounts receivable from affiliates" and $12 million was reflected in "Other noncurrent assets" on the Balance Sheets. Other (PPL Electric, LG&E and KU) See Note 1 for discussions regarding the intercompany tax sharing agreement (for PPL Electric, LG&E and KU) and intercompany allocations of stock-based compensation expense (for PPL Electric). For PPL Electric, LG&E and KU, see Note 12 for discussions regarding intercompany allocations associated with defined benefits.
Louisville Gas And Electric Co [Member]
Related Party Transactions [Line Items]
Related Party Transactions	Wholesale Sales and Purchases (LG&E and KU) LG&E and KU jointly dispatch their generation units with the lowest cost generation used to serve their retail customers. When LG&E has excess generation capacity after serving its own retail customers and its generation cost is lower than that of KU, KU purchases electricity from LG&E and vice versa. These transactions are reflected in the Statements of Income as "Electric revenue from affiliate" and "Energy purchases from affiliate" and are recorded at a price equal to the seller's fuel cost plus any split savings. Savings realized from such intercompany transactions are shared equally between both companies. The volume of energy each company has to sell to the other is dependent on its retail customers' needs and its available generation. Support Costs (PPL Electric, LG&E and KU) PPL Services, PPL EU Services, prior to its merger into PPL Services as of December 31, 2021, and LKS provide the Registrants and each other with administrative, management and support services. For all services companies, the costs of directly assignable and attributable services are charged to the respective recipients as direct support costs. General costs that cannot be directly attributed to a specific entity are allocated and charged to the respective recipients as indirect support costs. PPL Services and PPL EU Services use a three-factor methodology that includes the applicable recipients' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. PPL Services may also use a ratio of overall direct and indirect costs or a weighted average cost ratio. LKS bases its indirect allocations on the subsidiaries' number of employees, total assets, revenues, number of customers and/or other statistical information. PPL Services, PPL EU Services and LKS charged the following amounts for the years ended December 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable. 2021 2020 2019 PPL Electric from PPL Services $ 54 $ 50 $ 59 PPL Electric from PPL EU Services 222 176 152 LG&E from LKS 169 170 160 KU from LKS 179 180 178 In addition to the charges for services noted above, LKS makes payments on behalf of LG&E and KU for fuel purchases and other costs for products or services provided by third parties. LG&E and KU also provide services to each other and to LKS. Billings between LG&E and KU relate to labor and overheads associated with union and hourly employees performing work for the other company, charges related to jointly-owned generating units and other miscellaneous charges. Tax settlements between PPL and LG&E and KU are reimbursed through LKS. Intercompany Borrowings (PPL Electric) PPL Energy Funding maintains a $1,200 million revolving line of credit with a PPL Electric subsidiary. At December 31, 2021, PPL Energy Funding had borrowings outstanding in the amount of $499 million. This balance is reflected in "Notes receivable from affiliate" on the PPL Electric balance sheet. No balance was outstanding at December 31, 2020. The interest rates on borrowings are equal to one-month LIBOR plus a spread. Interest income is reflected in "Interest Income from Affiliate" on the Income Statements. (LG&E) LG&E participates in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E funds up to the difference between LG&E's FERC borrowing limit and LG&E's commercial paper limit at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on LIBOR. LG&E's money pool borrowing limit is $325 million. At December 31, 2021, LG&E had borrowings outstanding from LKE in the amount of $324 million. This balance is reflected in "Notes payable with affiliates" on the LG&E balance sheets. No balances were outstanding at December 31, 2020. (KU) KU participates in an intercompany money pool agreement whereby LKE and/or LG&E make available to KU funds up to the difference between KU's FERC borrowing limit and KU's commercial paper limit at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on LIBOR. KU's money pool borrowing limit is $300 million. At December 31, 2021, KU had borrowings outstanding from LKE in the amount of $294 million. This balance is reflected in "Notes payable with affiliates" on the KU balance sheets. No balances were outstanding at December 31, 2020. VEBA Funds Receivable (PPL Electric) In May 2018, PPL received a favorable private letter ruling from the IRS permitting a transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to a new subaccount within the VEBA, to be used to pay medical claims of active bargaining unit employees. Based on PPL Electric's participation in PPL’s Other Postretirement Benefit plan, PPL Electric was allocated a portion of the excess funds from PPL Services. These funds have been recorded as an intercompany receivable on the Balance Sheets. The receivable balance decreases as PPL Electric pays incurred medical claims and is reimbursed by PPL Services. The intercompany receivable balance associated with these funds was $11 million as of December 31, 2021, of which $10 million was reflected in "Accounts receivable from affiliates" and $1 million was reflected in "Other noncurrent assets" on the Balance Sheets. The intercompany receivable balance associated with these funds was $22 million as of December 31, 2020, of which $10 million was reflected in "Accounts receivable from affiliates" and $12 million was reflected in "Other noncurrent assets" on the Balance Sheets. Other (PPL Electric, LG&E and KU) See Note 1 for discussions regarding the intercompany tax sharing agreement (for PPL Electric, LG&E and KU) and intercompany allocations of stock-based compensation expense (for PPL Electric). For PPL Electric, LG&E and KU, see Note 12 for discussions regarding intercompany allocations associated with defined benefits.
Kentucky Utilities Co [Member]
Related Party Transactions [Line Items]
Related Party Transactions	Wholesale Sales and Purchases (LG&E and KU) LG&E and KU jointly dispatch their generation units with the lowest cost generation used to serve their retail customers. When LG&E has excess generation capacity after serving its own retail customers and its generation cost is lower than that of KU, KU purchases electricity from LG&E and vice versa. These transactions are reflected in the Statements of Income as "Electric revenue from affiliate" and "Energy purchases from affiliate" and are recorded at a price equal to the seller's fuel cost plus any split savings. Savings realized from such intercompany transactions are shared equally between both companies. The volume of energy each company has to sell to the other is dependent on its retail customers' needs and its available generation. Support Costs (PPL Electric, LG&E and KU) PPL Services, PPL EU Services, prior to its merger into PPL Services as of December 31, 2021, and LKS provide the Registrants and each other with administrative, management and support services. For all services companies, the costs of directly assignable and attributable services are charged to the respective recipients as direct support costs. General costs that cannot be directly attributed to a specific entity are allocated and charged to the respective recipients as indirect support costs. PPL Services and PPL EU Services use a three-factor methodology that includes the applicable recipients' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. PPL Services may also use a ratio of overall direct and indirect costs or a weighted average cost ratio. LKS bases its indirect allocations on the subsidiaries' number of employees, total assets, revenues, number of customers and/or other statistical information. PPL Services, PPL EU Services and LKS charged the following amounts for the years ended December 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable. 2021 2020 2019 PPL Electric from PPL Services $ 54 $ 50 $ 59 PPL Electric from PPL EU Services 222 176 152 LG&E from LKS 169 170 160 KU from LKS 179 180 178 In addition to the charges for services noted above, LKS makes payments on behalf of LG&E and KU for fuel purchases and other costs for products or services provided by third parties. LG&E and KU also provide services to each other and to LKS. Billings between LG&E and KU relate to labor and overheads associated with union and hourly employees performing work for the other company, charges related to jointly-owned generating units and other miscellaneous charges. Tax settlements between PPL and LG&E and KU are reimbursed through LKS. Intercompany Borrowings (PPL Electric) PPL Energy Funding maintains a $1,200 million revolving line of credit with a PPL Electric subsidiary. At December 31, 2021, PPL Energy Funding had borrowings outstanding in the amount of $499 million. This balance is reflected in "Notes receivable from affiliate" on the PPL Electric balance sheet. No balance was outstanding at December 31, 2020. The interest rates on borrowings are equal to one-month LIBOR plus a spread. Interest income is reflected in "Interest Income from Affiliate" on the Income Statements. (LG&E) LG&E participates in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E funds up to the difference between LG&E's FERC borrowing limit and LG&E's commercial paper limit at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on LIBOR. LG&E's money pool borrowing limit is $325 million. At December 31, 2021, LG&E had borrowings outstanding from LKE in the amount of $324 million. This balance is reflected in "Notes payable with affiliates" on the LG&E balance sheets. No balances were outstanding at December 31, 2020. (KU) KU participates in an intercompany money pool agreement whereby LKE and/or LG&E make available to KU funds up to the difference between KU's FERC borrowing limit and KU's commercial paper limit at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on LIBOR. KU's money pool borrowing limit is $300 million. At December 31, 2021, KU had borrowings outstanding from LKE in the amount of $294 million. This balance is reflected in "Notes payable with affiliates" on the KU balance sheets. No balances were outstanding at December 31, 2020. VEBA Funds Receivable (PPL Electric) In May 2018, PPL received a favorable private letter ruling from the IRS permitting a transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to a new subaccount within the VEBA, to be used to pay medical claims of active bargaining unit employees. Based on PPL Electric's participation in PPL’s Other Postretirement Benefit plan, PPL Electric was allocated a portion of the excess funds from PPL Services. These funds have been recorded as an intercompany receivable on the Balance Sheets. The receivable balance decreases as PPL Electric pays incurred medical claims and is reimbursed by PPL Services. The intercompany receivable balance associated with these funds was $11 million as of December 31, 2021, of which $10 million was reflected in "Accounts receivable from affiliates" and $1 million was reflected in "Other noncurrent assets" on the Balance Sheets. The intercompany receivable balance associated with these funds was $22 million as of December 31, 2020, of which $10 million was reflected in "Accounts receivable from affiliates" and $12 million was reflected in "Other noncurrent assets" on the Balance Sheets. Other (PPL Electric, LG&E and KU) See Note 1 for discussions regarding the intercompany tax sharing agreement (for PPL Electric, LG&E and KU) and intercompany allocations of stock-based compensation expense (for PPL Electric). For PPL Electric, LG&E and KU, see Note 12 for discussions regarding intercompany allocations associated with defined benefits.

Other Income (Expense) - net

Other Income (Expense) - net	12 Months Ended
	Dec. 31, 2021
Other Income (Expense) Net [Line Items]
Other Income (Expense) - net	(PPL) The components of "Other Income (Expense) - net" for the years ended December 31, were: 2021 2020 2019 Other Income Defined benefit plans - non-service credits (Note 12) $ 21 $ (2) $ 8 Interest income 12 9 15 AFUDC - equity component 18 20 23 Miscellaneous 10 7 7 Total Other Income 61 34 53 Other Expense Charitable contributions 14 3 17 Miscellaneous 32 29 22 Total Other Expense 46 32 39 Other Income (Expense) - net $ 15 $ 2 $ 14 (PPL Electric) The components of "Other Income (Expense) - net" for the years ended December 31, were: 2021 2020 2019 Other Income Defined benefit plans - non-service credits (Note 12) $ 9 $ 4 $ 4 Interest income — 2 2 AFUDC - equity component 18 19 23 Total Other Income 27 25 29 Other Expense Charitable contributions 3 3 3 Miscellaneous 3 4 1 Total Other Expense 6 7 4 Other Income (Expense) - net $ 21 $ 18 $ 25
PPL Electric Utilities Corp [Member]
Other Income (Expense) Net [Line Items]
Other Income (Expense) - net	The components of "Other Income (Expense) - net" for the years ended December 31, were: 2021 2020 2019 Other Income Defined benefit plans - non-service credits (Note 12) $ 9 $ 4 $ 4 Interest income — 2 2 AFUDC - equity component 18 19 23 Total Other Income 27 25 29 Other Expense Charitable contributions 3 3 3 Miscellaneous 3 4 1 Total Other Expense 6 7 4 Other Income (Expense) - net $ 21 $ 18 $ 25

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2021
Fair Value Disclosures [Abstract]
Fair Value Measurements and Credit Concentration	(All Registrants) Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (an exit price). A market approach (generally, data from market transactions), an income approach (generally, present value techniques and option-pricing models), and/or a cost approach (generally, replacement cost) are used to measure the fair value of an asset or liability, as appropriate. These valuation approaches incorporate inputs such as observable, independent market data and/or unobservable data that management believes are predicated on the assumptions market participants would use to price an asset or liability. These inputs may incorporate, as applicable, certain risks such as nonperformance risk, which includes credit risk. The fair value of a group of financial assets and liabilities is measured on a net basis. See Note 1 for information on the levels in the fair value hierarchy. Recurring Fair Value Measurements The assets and liabilities measured at fair value were: December 31, 2021 December 31, 2020 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 3,571 $ 3,571 $ — $ — $ 442 $ 442 $ — $ — Restricted cash and cash equivalents (a) 1 1 — — 1 1 — — Special use funds (a): Money market fund 2 2 — — — — — — Commingled debt fund measured at NAV (b) 22 — — — 26 — — — Commingled equity fund measured at NAV (b) 21 — — — 25 — — — Total special use funds 45 2 — — 51 — — — Total assets $ 3,617 $ 3,574 $ — $ — $ 494 $ 443 $ — $ — Liabilities Price risk management liabilities (c): Interest rate swaps $ 18 $ — $ 18 $ — $ 23 $ — $ 23 $ — Total price risk management liabilities $ 18 $ — $ 18 $ — $ 23 $ — $ 23 $ — PPL Electric Assets Cash and cash equivalents $ 21 $ 21 $ — $ — $ 40 $ 40 $ — $ — Total assets $ 21 $ 21 $ — $ — $ 40 $ 40 $ — $ — LG&E Assets Cash and cash equivalents $ 9 $ 9 $ — $ — $ 7 $ 7 $ — $ — Total assets $ 9 $ 9 $ — $ — $ 7 $ 7 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 18 $ — $ 18 $ — $ 23 $ — $ 23 $ — Total price risk management liabilities $ 18 $ — $ 18 $ — $ 23 $ — $ 23 $ — KU Assets Cash and cash equivalents $ 13 $ 13 $ — $ — $ 22 $ 22 $ — $ — Total assets $ 13 $ 13 $ — $ — $ 22 $ 22 $ — $ — (a) Current portion is included in "Other current assets" and long-term portion is included in "Other noncurrent assets" on the Balance Sheets. (b) In accordance with accounting guidance, certain investments that are measured at fair value using net asset value per share (NAV), or its equivalent, have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position. (c) Current portion is included in "Other current liabilities" and noncurrent portion is included in "Other deferred credits and noncurrent liabilities" on the Balance Sheets. Special Use Funds (PPL) The special use funds are investments restricted for paying active union employee medical costs. In 2018, PPL received a favorable private letter ruling from the IRS permitting a transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to a new subaccount within the VEBA to be used to pay medical claims of active bargaining unit employees. The funds are invested primarily in commingled debt and equity funds measured at NAV and are classified as investments in equity securities. Changes in the fair value of the funds are recorded to the Statement of Income. Price Risk Management Assets/Liabilities - Interest Rate Swaps/Foreign Currency Contracts/Cross-Currency Swaps (PPL, LG&E and KU) To manage interest rate risk, PPL, LG&E and KU use interest rate contracts such as forward-starting swaps, floating-to-fixed swaps and fixed-to-floating swaps. To manage foreign currency exchange risk, PPL uses foreign currency contracts such as forwards, options, and cross-currency swaps that contain characteristics of both interest rate and foreign currency contracts. An income approach is used to measure the fair value of these contracts, utilizing readily observable inputs, such as forward interest rates (e.g., LIBOR and government security rates) and forward foreign currency exchange rates (e.g., GBP), as well as inputs that may not be observable, such as credit valuation adjustments. In certain cases, market information cannot practicably be obtained to value credit risk and therefore internal models are relied upon. These models use projected probabilities of default and estimated recovery rates based on historical observances. When the credit valuation adjustment is significant to the overall valuation, the contracts are classified as Level 3. Financial Instruments Not Recorded at Fair Value (All Registrants) The carrying amounts of long-term debt on the Balance Sheets and their estimated fair values are set forth below. Long-term debt is classified as Level 2. The effect of third-party credit enhancements is not included in the fair value measurement. December 31, 2021 December 31, 2020 Carrying Fair Value Carrying Fair Value PPL $ 11,140 $ 12,955 $ 14,689 $ 17,774 PPL Electric 4,484 5,272 4,236 5,338 LG&E 2,006 2,363 2,007 2,499 KU 2,618 3,120 2,618 3,334 (a) Amounts are net of debt issuance costs. The carrying amounts of other current financial instruments (except for long-term debt due within one year) approximate their fair values because of their short-term nature.

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	12 Months Ended
	Dec. 31, 2021
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	18. Derivative Instruments and Hedging Activities Risk Management Objectives (All Registrants) PPL has a risk management policy approved by the Board of Directors to manage market risk associated with commodities, interest rates on debt issuances and foreign exchange (including price, liquidity and volumetric risk) and credit risk (including non-performance risk and payment default risk). The Risk Management Committee, comprised of senior management and chaired by the Senior Director-Risk Management, oversees the risk management function. Key risk control activities designed to ensure compliance with the risk policy and detailed programs include, but are not limited to, credit review and approval, validation of transactions, verification of risk and transaction limits, value-at-risk analyses (VaR, a statistical model that attempts to estimate the value of potential loss over a given holding period under normal market conditions at a given confidence level) and the coordination and reporting of the Enterprise Risk Management program. Market Risk Market risk includes the potential loss that may be incurred as a result of price changes associated with a particular financial or commodity instrument as well as market liquidity and volumetric risks. Forward contracts, futures contracts, options, swaps and structured transactions are utilized as part of risk management strategies to minimize unanticipated fluctuations in earnings caused by changes in commodity prices, interest rates and foreign currency exchange rates. Many of these contracts meet the definition of a derivative. All derivatives are recognized on the Balance Sheets at their fair value, unless NPNS is elected. The following summarizes the market risks that affect PPL and its subsidiaries. Interest Rate Risk • PPL and its subsidiaries are exposed to interest rate risk associated with forecasted fixed-rate and existing floating-rate debt issuances. Prior to the sale of the U.K. utility business on June 14, 2021, PPL and WPD held over-the-counter cross currency swaps to limit exposure to market fluctuations on interest and principal payments from changes in foreign currency exchange rates and interest rates. PPL and LG&E utilize over-the-counter interest rate swaps to limit exposure to market fluctuations on floating-rate debt. PPL, LG&E and KU utilize forward starting interest rate swaps to hedge changes in benchmark interest rates, when appropriate, in connection with future debt issuances. • PPL and its subsidiaries are exposed to interest rate risk associated with debt securities and derivatives held by defined benefit plans. This risk is significantly mitigated to the extent that the plans are sponsored at, or sponsored on behalf of, the regulated domestic utilities and, prior to the sale of the U.K. utility business on June 14, 2021, for certain plans at WPD due to the recovery methods in place. Foreign Currency Risk (PPL) • PPL was exposed to foreign currency exchange risk primarily associated with its investments in and earnings of U.K. affiliates. (All Registrants) Commodity Price Risk PPL is exposed to commodity price risk through its domestic subsidiaries as described below. • PPL Electric is required to purchase electricity to fulfill its obligation as a PLR. Potential commodity price risk is insignificant and mitigated through its PUC-approved cost recovery mechanism and full-requirement supply agreements to serve its PLR customers which transfer the risk to energy suppliers. • LG&E's and KU's rates include certain mechanisms for fuel, fuel-related expenses and energy purchases. In addition, LG&E's rates include a mechanism for natural gas supply expenses. These mechanisms generally provide for timely recovery of market price fluctuations associated with these expenses. Volumetric Risk Volumetric risk is the risk related to the changes in volume of retail sales due to weather, economic conditions or other factors. PPL is exposed to volumetric risk through its subsidiaries as described below. • WPD was exposed to volumetric risk which was significantly mitigated as a result of the method of regulation in the U.K. • PPL Electric, LG&E and KU are exposed to volumetric risk on retail sales, mainly due to weather and other economic conditions for which there is limited mitigation between rate cases. Equity Securities Price Risk • PPL and its subsidiaries are exposed to equity securities price risk associated with the fair value of the defined benefit plans' assets. This risk is significantly mitigated due to the recovery methods in place. • PPL is exposed to equity securities price risk from future stock sales and/or purchases. Credit Risk Credit risk is the potential loss that may be incurred due to a counterparty's non-performance. PPL is exposed to credit risk from "in-the-money" transactions with counterparties, as well as additional credit risk through certain of its subsidiaries, as discussed below. In the event a supplier of PPL Electric, LG&E or KU defaults on its obligation, those Registrants would be required to seek replacement power or replacement fuel in the market. In general, subject to regulatory review or other processes, appropriate incremental costs incurred by these entities would be recoverable from customers through applicable rate mechanisms, thereby mitigating the financial risk for these entities. PPL and its subsidiaries have credit policies in place to manage credit risk, including the use of an established credit approval process, daily monitoring of counterparty positions and the use of master netting agreements or provisions. These agreements generally include credit mitigation provisions, such as margin, prepayment or collateral requirements. PPL and its subsidiaries may request additional credit assurance, in certain circumstances, in the event that the counterparties' credit ratings fall below investment grade, their tangible net worth falls below specified percentages or their exposures exceed an established credit limit. Master Netting Arrangements (PPL, LG&E and KU) Net derivative positions on the balance sheets are not offset against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements. PPL had no obligation and an immaterial obligation to return cash collateral under master netting arrangements at December 31, 2021 and 2020. PPL had no obligation to post cash collateral under master netting arrangements at December 31, 2021 and 2020. LG&E and KU had no obligation to return cash collateral under master netting arrangements at December 31, 2021 and 2020. LG&E and KU had no cash collateral posted under master netting arrangements at December 31, 2021 and 2020. See "Offsetting Derivative Instruments" below for a summary of derivative positions presented in the balance sheets where a right of setoff exists under these arrangements. Interest Rate Risk (All Registrants) PPL and its subsidiaries issue debt to finance their operations, which exposes them to interest rate risk. A variety of financial derivative instruments are utilized to adjust the mix of fixed and floating interest rates in their debt portfolios, adjust the duration of the debt portfolios and lock in benchmark interest rates in anticipation of future financing, when appropriate. Risk limits under PPL's risk management program are designed to balance risk exposure to volatility in interest expense and changes in the fair value of the debt portfolio due to changes in benchmark interest rates. In addition, the interest rate risk of certain subsidiaries is potentially mitigated as a result of the existing regulatory framework or the timing of rate cases. Cash Flow Hedges (PPL) Interest rate risks include exposure to adverse interest rate movements for outstanding variable rate debt and for future anticipated financings. Financial interest rate swap contracts that qualify as cash flow hedges may be entered into to hedge floating interest rate risk associated with both existing and anticipated debt issuances. PPL had no such contracts at December 31, 2021. As of December 31, 2021, PPL had no aggregate notional value in cross-currency interest rate swap contracts. In March 2021, $500 million of WPD's U.S. dollar-denominated senior notes were repaid prior to maturity and $500 million notional value of cross-currency interest rate swap contracts matured. Cash flow hedges are discontinued if it is no longer probable that the original forecasted transaction will occur by the end of the originally specified time period and any amounts previously recorded in AOCI are reclassified into earnings once it is determined that the hedged transaction is not probable of occurring. For 2021, 2020 and 2019, PPL had no cash flow hedges reclassified into earnings associated with discontinued cash flow hedges. At December 31, 2021, the amount of accumulated net unrecognized after-tax gains (losses) on qualifying derivatives expected to be reclassified into earnings during the next 12 months is insignificant. Amounts are reclassified as the hedged interest expense is recorded. Economic Activity (PPL and LG&E) LG&E enters into interest rate swap contracts that economically hedge interest payments. Because realized gains and losses from the swaps, including terminated swap contracts, are recoverable through regulated rates, any subsequent changes in fair value of these derivatives are included in regulatory assets or liabilities until they are realized as interest expense. Realized gains and losses are recognized in "Interest Expense" on the Statements of Income at the time the underlying hedged interest expense is recorded. At December 31, 2021, LG&E held contracts with a notional amount of $64 million that mature in 2033. Foreign Currency Risk (PPL) PPL was exposed to foreign currency risk, primarily through investments in and earnings of U.K affiliates. PPL has adopted a foreign currency risk management program designed to hedge certain foreign currency exposures, including firm commitments, recognized assets or liabilities, anticipated transactions, including the sale of its U.K utility business and net investments. In addition, PPL entered into financial instruments to protect against foreign currency translation risk of expected GBP earnings. Net Investment Hedges PPL entered into foreign currency contracts on behalf of a subsidiary to protect the value of a portion of its net investment in WPD. There were no contracts outstanding at December 31, 2021. At December 31, 2020, PPL had $33 million of accumulated net investment hedge after tax gains (losses) that were included in the foreign currency translation adjustment component of AOCI. The remaining balance was transferred out of AOCI and realized in discontinued operations as a result of the sale of the U.K. utility business. Economic Activity PPL entered into foreign currency contracts on behalf of subsidiaries to economically hedge foreign-denominated anticipated earnings and anticipated transactions, including the sale of its U.K. utility business. Accounting and Reporting (All Registrants) All derivative instruments are recorded at fair value on the Balance Sheet as an asset or liability unless the Normal Purchase Normal Sale scope exception (NPNS) is elected. NPNS contracts include certain full-requirement purchase contracts and other physical purchase contracts. Changes in the fair value of derivatives not designated as NPNS are recognized in earnings unless specific hedge accounting criteria are met and designated as such, except for the changes in fair values of LG&E's interest rate swaps that are recognized as regulatory assets or regulatory liabilities. See Note 7 for amounts recorded in regulatory assets and regulatory liabilities at December 31, 2021 and 2020. See Note 1 for additional information on accounting policies related to derivative instruments. (PPL) The following table presents the fair value and location of derivative instruments recorded on the Balance Sheets: December 31, 2021 December 31, 2020 Derivatives designated as Derivatives not designated Derivatives designated as Derivatives not designated Assets Liabilities Assets Liabilities Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) $ — $ — $ — $ 1 $ — $ — $ — $ 2 Cross-currency swaps (c) — — — — 94 — — — Foreign currency contracts (c) — — — — — — — 137 Total current — — — 1 94 — — 139 Noncurrent: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) — — — 17 — — — 21 Cross-currency swaps (c) — — — — 52 — — — Total noncurrent — — — 17 52 — — 21 Total derivatives $ — $ — $ — $ 18 $ 146 $ — $ — $ 160 (a) Current portion is included in "Price risk management assets" and "Other current liabilities" and noncurrent portion is included in "Price risk management assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets. (b) Excludes accrued interest, if applicable. (c) Included in "Current assets held for sale" and "Current liabilities held for sale" on the Balance Sheet. The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities: Derivative Derivative Gain Location of Gain (Loss) Gain (Loss) Reclassified 2021 Cash Flow Hedges: Interest rate swaps $ — Interest Expense $ 11 Income (Loss) from Discontinued operations (net of taxes) (2) Cross-currency swaps (50) Income (Loss) from Discontinued operations (net of taxes) (39) Total $ (50) $ (30) Net Investment Hedges: Foreign currency contracts in Discontinued operations $ 1 2020 Cash Flow Hedges: Interest rate swaps $ (9) Interest Expense $ (8) Income (Loss) from Discontinued operations (net of taxes) (2) Cross-currency swaps (15) Income (Loss) from Discontinued operations (net of taxes) (22) Total $ (24) $ (32) Net Investment Hedges: Foreign currency contracts in Discontinued operations $ 1 2019 Cash Flow Hedges: Interest rate swaps $ (30) Interest Expense $ (9) Cross-currency swaps 17 Income (Loss) from Discontinued operations (net of taxes) (9) Total $ (13) $ (18) Net Investment Hedges: Foreign currency contracts in Discontinued operations $ 2 Derivatives Not Designated as Location of Gain (Loss) Recognized in 2021 2020 2019 Foreign currency contracts Income (Loss) from Discontinued Operations (net of taxes) $ (266) $ (98) $ (14) Interest rate swaps Interest Expense (2) (5) (5) Total $ (268) $ (103) $ (19) Derivatives Not Designated as Location of Gain (Loss) Recognized as 2021 2020 2019 Interest rate swaps Regulatory assets - noncurrent $ 5 $ (2) $ (1) The following table presents the effect of cash flow hedge activity on the Statement of Income for the year ended December 31, 2021: Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Interest Expense Income (Loss) from Discontinued Operations (net of income taxes) Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 918 $ (1,498) The effects of cash flow hedges: Gain (Loss) on cash flow hedging relationships: Interest rate swaps: Amount of gain (loss) reclassified from AOCI to income 11 (2) Cross-currency swaps: Hedged items — 39 Amount of gain (loss) reclassified from AOCI to income — (39) The following table presents the effect of cash flow hedge activity on the Statement of Income for the year ended December 31, 2020: Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Interest Expense Income (Loss) from Discontinued Operations (net of income taxes) Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 634 $ 829 The effects of cash flow hedges: Gain (Loss) on cash flow hedging relationships: Interest rate swaps: Amount of gain (loss) reclassified from AOCI to income (8) (2) Cross-currency swaps: Hedged items — 22 Amount of gain (loss) reclassified from AOCI to income — (22) The following table presents the effect of cash flow hedge activity on the Statement of Income for the year ended December 31,2019: Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Interest Expense Income (Loss) from Discontinued Operations (net of income taxes) Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 621 $ 1,010 The effects of cash flow hedges: Gain (Loss) on cash flow hedging relationships: Interest rate swaps: Amount of gain (loss) reclassified from AOCI to income (9) — Cross-currency swaps: Hedged items — 9 Amount of gain (loss) reclassified from AOCI to income — (9) (LG&E) The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments: December 31, 2021 December 31, 2020 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ 1 $ — $ 2 Total current — 1 — 2 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 17 — 21 Total noncurrent — 17 — 21 Total derivatives $ — $ 18 $ — $ 23 The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets: Derivative Instruments Location of Gain (Loss) 2021 2020 2019 Interest rate swaps Interest Expense $ (2) $ (5) $ (5) Derivative Instruments Location of Gain (Loss) 2021 2020 2019 Interest rate swaps Regulatory assets - noncurrent $ 5 $ (2) $ (1) (PPL, LG&E and KU) Offsetting Derivative Instruments PPL, LG&E and KU or certain of their subsidiaries have master netting arrangements in place and also enter into agreements pursuant to which they purchase or sell certain energy and other products. Under the agreements, upon termination of the agreement as a result of a default or other termination event, the non-defaulting party typically would have a right to set off amounts owed under the agreement against any other obligations arising between the two parties (whether under the agreement or not), whether matured or contingent and irrespective of the currency, place of payment or place of booking of the obligation. PPL, LG&E and KU have elected not to offset derivative assets and liabilities and not to offset net derivative positions against the right to reclaim cash collateral pledged (an asset) or the obligation to return cash collateral received (a liability) under derivatives agreements. The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged. Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Cash Net Gross Derivative Cash Net December 31, 2021 Treasury Derivatives PPL $ — $ — $ — $ — $ 18 $ — $ — $ 18 LG&E — — — — 18 — — 18 December 31, 2020 Treasury Derivatives PPL $ 146 $ 34 $ — $ 112 $ 160 $ 34 $ — $ 126 LG&E — — — — 23 — — 23 Credit Risk-Related Contingent Features Certain derivative contracts contain credit risk-related contingent features which, when in a net liability position, would permit the counterparties to require the transfer of additional collateral upon a decrease in the credit ratings of PPL, LG&E and KU or certain of their subsidiaries. Most of these features would require the transfer of additional collateral or permit the counterparty to terminate the contract if the applicable credit rating were to fall below investment grade. Some of these features also would allow the counterparty to require additional collateral upon each downgrade in credit rating at levels that remain above investment grade. In either case, if the applicable credit rating were to fall below investment grade, and assuming no assignment to an investment grade affiliate were allowed, most of these credit contingent features require either immediate payment of the net liability as a termination payment or immediate and ongoing full collateralization on derivative instruments in net liability positions. Additionally, certain derivative contracts contain credit risk-related contingent features that require adequate assurance of performance be provided if the other party has reasonable concerns regarding the performance of PPL's, LG&E's and KU's obligations under the contracts. A counterparty demanding adequate assurance could require a transfer of additional collateral or other security, including letters of credit, cash and guarantees from a creditworthy entity. This would typically involve negotiations among the parties. However, amounts disclosed below represent assumed immediate payment or immediate and ongoing full collateralization for derivative instruments in net liability positions with "adequate assurance" features. (PPL) At December 31, 2021, there were no derivative contracts in a net liability position that contain credit risk-related contingent features, collateral posted on those positions and the related effect of a decrease in credit ratings below investment grade.

Goodwill and Other Intangible A

Goodwill and Other Intangible Assets	12 Months Ended
	Dec. 31, 2021
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Other Intangible Assets	19. Goodwill and Other Intangible Assets Goodwill (PPL) Goodwill for the Kentucky Regulated segment was $662 million at December 31, 2021 and 2020. Goodwill for Corporate and Other was $53 million at December 31, 2021 and 2020. There were no accumulated impairment losses related to goodwill. Other Intangible Assets (PPL) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2021 December 31, 2020 Gross Accumulated Gross Accumulated Subject to amortization: Contracts (a) $ 125 $ 90 $ 125 $ 82 Land rights and easements 406 135 401 133 Licenses and other 20 6 21 4 Total subject to amortization 551 231 547 219 Not subject to amortization due to indefinite life: Land rights and easements 17 — 17 — Other 6 — 6 — Total not subject to amortization due to indefinite life 23 — 23 — Total $ 574 $ 231 $ 570 $ 219 (a) Gross carrying amount in 2021 and 2020 includes the fair value at the acquisition date of the OVEC power purchase contract with terms favorable to market recognized as a result of the 2010 acquisition of LKE by PPL. Current intangible assets are included in "Other current assets" and long-term intangible assets are included in "Other intangibles" on the Balance Sheets. Amortization expense was as follows: 2021 2020 2019 Intangible assets with no regulatory offset $ 9 $ 7 $ 6 Intangible assets with regulatory offset 8 8 9 Total $ 17 $ 15 $ 15 Amortization expense for each of the next five years is estimated to be: 2022 2023 2024 2025 2026 Intangible assets with no regulatory offset $ 5 $ 5 $ 5 $ 5 $ 5 Intangible assets with regulatory offset 8 8 9 9 2 Total $ 13 $ 13 $ 14 $ 14 $ 7 (PPL Electric) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2021 December 31, 2020 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 382 $ 130 $ 379 $ 129 Licenses and other 2 1 2 1 Total subject to amortization 384 131 381 130 Not subject to amortization due to indefinite life: Land rights and easements 17 — 17 — Total $ 401 $ 131 $ 398 $ 130 Intangible assets are shown as "Intangibles" on the Balance Sheets. Amortization expense was as follows: 2021 2020 2019 Intangible assets with no regulatory offset $ 4 $ 4 $ 4 Amortization expense for each of the next five years is estimated to be: 2022 2023 2024 2025 2026 Intangible assets with no regulatory offset $ 4 $ 4 $ 4 $ 4 $ 4 (LG&E) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2021 December 31, 2020 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 7 $ 1 $ 7 $ 1 OVEC power purchase agreement (a) 86 62 86 57 Total subject to amortization $ 93 $ 63 $ 93 $ 58 (a) Gross carrying amount represents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability was recorded related to this contract, which is being amortized over the same period as the intangible asset, eliminating any income statement impact. See Note 7 for additional information. Long-term intangible assets are presented as "Other intangibles" on the Balance Sheets. Amortization expense was as follows: 2021 2020 2019 Intangible assets with regulatory offset $ 5 $ 6 $ 6 Amortization expense for each of the next five years is estimated to be: 2022 2023 2024 2025 2026 Intangible assets with regulatory offset $ 6 $ 6 $ 6 $ 6 $ 1 (KU) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2021 December 31, 2020 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 16 $ 4 $ 15 $ 3 OVEC power purchase agreement (a) 39 28 39 25 Total subject to amortization $ 55 $ 32 $ 54 $ 28 (a) Gross carrying amount represents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability was recorded related to this contract, which is being amortized over the same period as the intangible asset, eliminating any income statement impact. See Note 7 for additional information. Long-term intangible assets are presented as "Other intangibles" on the Balance Sheets. Amortization expense was as follows: 2021 2020 2019 Intangible assets with no regulatory offset $ 1 $ — $ — Intangible assets with regulatory offset 3 2 3 Amortization expense for each of the next five years is estimated to be: 2022 2023 2024 2025 2026 Intangible assets with regulatory offset $ 2 $ 2 $ 3 $ 3 $ 1

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2021
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	(PPL and PPL Electric) PPL Electric has identified legal retirement obligations for the retirement of certain transmission assets that could not be reasonably estimated due to indeterminable settlement dates. These assets are located on rights-of-way that allow the grantor to require PPL Electric to relocate or remove the assets. Since this option is at the discretion of the grantor of the right-of-way, PPL Electric is unable to determine when these events may occur. (PPL, LG&E and KU) PPL's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 14 for information on the CCR rule. LG&E also has AROs related to natural gas mains and wells. LG&E's and KU's transmission and distribution lines largely operate under perpetual property easement agreements, which do not generally require restoration upon removal of the property. Therefore, no material AROs are recorded for transmission and distribution assets. For LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, deferred accretion and depreciation expense is recovered through cost of removal. The changes in the carrying amounts of AROs were as follows: PPL LG&E KU 2021 2020 2021 2020 2021 2020 ARO at beginning of period $ 182 $ 215 $ 67 $ 73 $ 115 $ 142 Accretion 16 15 5 5 11 10 Changes in estimated timing or cost 56 40 40 13 16 27 Obligations settled (65) (88) (28) (24) (37) (64) ARO at end of period $ 189 $ 182 $ 84 $ 67 $ 105 $ 115

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income	12 Months Ended
	Dec. 31, 2021
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss)	(PPL) The after-tax changes in AOCI by component for the years ended December 31 were as follows: Defined benefit plans Foreign Unrealized gains (losses) on Prior Actuarial Total PPL December 31, 2018 $ (1,533) $ (7) $ (19) $ (2,405) $ (3,964) Amounts arising during the year 108 (11) (1) (592) (496) Reclassifications from AOCI — 13 2 87 102 Net OCI during the year 108 2 1 (505) (394) December 31, 2019 $ (1,425) $ (5) $ (18) $ (2,910) $ (4,358) Amounts arising during the year 267 (19) (1) (341) (94) Reclassifications from AOCI — 24 3 205 232 Net OCI during the year 267 5 2 (136) 138 December 31, 2020 $ (1,158) $ — $ (16) $ (3,046) $ (4,220) Defined benefit plans Foreign Unrealized gains (losses) on Prior Actuarial Total Amounts arising during the year 372 (39) — (1) 332 Reclassifications from AOCI — 25 2 126 153 Reclassifications from AOCI due to the sale of the U.K. utility business (Note 9) 786 15 8 2,769 3,578 Net OCI during the year 1,158 1 10 2,894 4,063 December 31, 2021 $ — $ 1 $ (6) $ (152) $ (157) The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the years ended December 31, 2021, 2020 and 2019. The defined benefit plan components of AOCI are not reflected in their entirety in the statement of income; rather, they are included in the computation of net periodic defined benefit costs (credits) and subject to capitalization. See Note 12 for additional information. PPL Details about AOCI 2021 2020 2019 Affected Line Item on the Qualifying derivatives Interest rate swaps $ 11 $ (8) $ (9) Interest Expense (2) (2) — Income (Loss) from Discontinued Operations (net of income taxes) Cross-currency swaps (39) (22) (9) Income (Loss) from Discontinued Operations (net of income taxes) Total Pre-tax (30) (32) (18) Income Taxes 5 8 5 Total After-tax (25) (24) (13) Defined benefit plans Prior service costs (3) (4) (3) Net actuarial loss (159) (256) (109) Total Pre-tax (162) (260) (112) Income Taxes 34 52 23 Total After-tax (128) (208) (89) Sale of the U.K. utility business (Note 9) Foreign currency translation adjustments (646) — — Income (Loss) from Discontinued Operations (net of income taxes) Qualifying derivatives (15) — — Income (Loss) from Discontinued Operations (net of income taxes) Defined benefit plans (3,577) — — Income (Loss) from Discontinued Operations (net of income taxes) Total Pre-tax (4,238) — — Income Taxes 660 — — Total After-tax (3,578) — — Total reclassifications during the year $ (3,731) $ (232) $ (102)

New Accounting Guidance Pending

New Accounting Guidance Pending Adoption	12 Months Ended
	Dec. 31, 2021
Accounting Standards Update and Change in Accounting Principle [Abstract]
New Accounting Guidance Pending Adoption	(All Registrants) See Note 1 to the Financial Statements for a discussion of new accounting guidance adopted.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2021
Summary of Significant Accounting Policies [Line Items]
Business and Consolidation	Business and Consolidation (PPL) PPL is a utility holding company that, through its regulated subsidiaries, is primarily engaged in: 1) the generation, transmission, distribution and sale of electricity and the distribution and sale of natural gas, primarily in Kentucky; and 2) the transmission, distribution and sale of electricity in Pennsylvania. Headquartered in Allentown, PA, PPL's principal subsidiaries are LKE (including its principal subsidiaries, LG&E and KU) and PPL Electric. PPL's corporate level financing subsidiary is PPL Capital Funding. On March 17, 2021, PPL WPD Limited entered into a share purchase agreement to sell PPL's U.K. utility business, which substantially represented PPL's U.K. Regulated segment, to a subsidiary of National Grid plc. The sale was completed on June 14, 2021. The results of operations of the U.K. utility business are classified as Discontinued Operations on PPL's Statements of Income. The assets and liabilities of the U.K. utility business as of December 31, 2020 are classified as assets and liabilities held for sale on PPL's Balance Sheets. PPL has elected to separately report the cash flows of continuing and discontinued operations on the Statements of Cash Flows. Unless otherwise noted, the notes to these financial statements exclude amounts related to discontinued operations and assets and liabilities held for sale for all periods presented. See Note 9 for additional information. On July 1, 2021, LKE redeemed, at par, its $250 million 4.375% Senior Notes due 2021 and on July 9, 2021, LKE filed a Form 15 with the SEC to suspend its duty to file reports under sections 13 and 15(d) of the Securities Exchange Act of 1934. As a result, beginning with the June 30, 2021 Form 10-Q, LKE was no longer reported as a Registrant. (PPL and PPL Electric) PPL Electric is a cost-based rate-regulated utility subsidiary of PPL. PPL Electric's principal business is the transmission and distribution of electricity to serve retail customers in its franchised territory in eastern and central Pennsylvania and the regulated supply of electricity to retail customers in that territory as a PLR. (PPL, LG&E and KU) LG&E and KU are engaged in the generation, transmission, distribution and sale of electricity. LG&E also engages in the distribution and sale of natural gas. LG&E and KU maintain their separate identities and serve customers in Kentucky under their respective names. KU also serves customers in Virginia under the Old Dominion Power name. (All Registrants) The financial statements of the Registrants include each company's own accounts as well as the accounts of all entities in which the company has a controlling financial interest. Entities for which a controlling financial interest is not demonstrated through voting interests are evaluated based on accounting guidance for Variable Interest Entities (VIEs). The Registrants consolidate a VIE when they are determined to have a controlling interest in the VIE and, as a result, are the primary beneficiary of the entity. Amounts consolidated under the VIE guidance are not material to the Registrants. All significant intercompany transactions have been eliminated. The financial statements of PPL, LG&E and KU include their share of any undivided interests in jointly owned facilities, as well as their share of the related operating costs of those facilities. See Note 13 for additional information.
Regulation	Regulation (All Registrants) PPL Electric, LG&E and KU are cost-based rate-regulated utilities for which rates are set by regulators to enable PPL Electric, LG&E and KU to recover the costs of providing electric or gas service, as applicable, and to provide a reasonable return to shareholders. Base rates are generally established based on a future test period. As a result, the financial statements are subject to the accounting for certain types of regulation as prescribed by GAAP and reflect the effects of regulatory actions. Regulatory assets are recognized for the effect of transactions or events where future recovery of underlying costs is probable in regulated customer rates. The effect of such accounting is to defer certain or qualifying costs that would otherwise currently be charged to expense. Regulatory liabilities are recognized for amounts expected to be returned through future regulated customer rates. In certain cases, regulatory liabilities are recorded based on an understanding or agreement with the regulator that rates have been set to recover expected future costs, and the regulated entity is accountable for any amounts charged pursuant to such rates and not yet expended for the intended purpose. The accounting for regulatory assets and regulatory liabilities is based on specific ratemaking decisions or precedent for each transaction or event as prescribed by the FERC or the applicable state regulatory commissions. See Note 7 for additional details regarding regulatory matters.
Accounting Records	Accounting Records The system of accounts for domestic regulated entities is maintained in accordance with the Uniform System of Accounts prescribed by the FERC and adopted by the applicable state regulatory commissions.
Use of Estimates	Use of Estimates The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Loss Accruals	Loss Accruals Potential losses are accrued when (1) information is available that indicates it is "probable" that a loss has been incurred, given the likelihood of uncertain future events and (2) the amount of loss can be reasonably estimated. Accounting guidance defines "probable" as cases in which "the future event or events are likely to occur." The Registrants continuously assess potential loss contingencies for environmental remediation, litigation claims, regulatory penalties and other events. Loss accruals for environmental remediation are discounted when appropriate. The accrual of contingencies that might result in gains is not recorded, unless realization is assured.
Earnings Per Share	Earnings Per Share (PPL) EPS is computed using the two-class method, which is an earnings allocation method for computing EPS that treats a participating security as having rights to earnings that would otherwise have been available to common shareowners. Share-based payment awards that provide recipients a non-forfeitable right to dividends or dividend equivalents are considered participating securities.
Price Risk Management	Price Risk Management (All Registrants) Interest rate contracts are used to hedge exposure to changes in the fair value of debt instruments and to hedge exposure to variability in expected cash flows associated with existing floating-rate debt instruments or forecasted fixed-rate issuances of debt. Foreign currency exchange contracts are used to hedge foreign currency exposures. Similar derivatives may receive different accounting treatment, depending on management's intended use and documentation. Certain contracts may not meet the definition of a derivative because they lack a notional amount or a net settlement provision. In cases where there is no net settlement provision, markets are periodically assessed to determine whether market mechanisms have evolved to facilitate net settlement. Certain derivative contracts may be excluded from the requirements of derivative accounting treatment because the NPNS has been elected. These contracts are accounted for using accrual accounting. Contracts that have been classified as derivative contracts are reflected on the balance sheets at fair value. The portion of derivative positions that deliver within a year are included in "Current Assets" and "Current Liabilities," while the portion of derivative positions that deliver beyond a year are recorded in "Other Noncurrent Assets" and "Deferred Credits and Other Noncurrent Liabilities." Cash inflows and outflows related to derivative instruments are included as a component of operating, investing or financing activities on the Statements of Cash Flows, depending on the classification of the hedged items. PPL and its subsidiaries have elected not to offset net derivative positions against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements. (PPL) Processes exist that allow for subsequent review and validation of contract information as it relates to interest rate derivatives and foreign currency derivatives. The accounting department provides the treasury department with guidelines on appropriate accounting classifications for various contract types and strategies. Examples of accounting guidelines provided to the treasury department staff include, but are not limited to: • Transactions to lock in an interest rate prior to a debt issuance can be designated as cash flow hedges, to the extent the forecasted debt issuances remain probable of occurring. • Cross-currency transactions to hedge interest and principal repayments can be designated as cash flow hedges. • Transactions to hedge fluctuations in the fair value of existing debt can be designated as fair value hedges. • Transactions to hedge the value of a net investment of foreign operations can be designated as net investment hedges. • Derivative transactions that do not qualify for cash flow or net investment hedge treatment are marked to fair value through earnings. As such, these transactions reduce earnings volatility due solely to changes in foreign currency exchange rates. PPL also hedges anticipated transactions, including the previously completed sale of its U.K utility business and net investments. (All Registrants) Derivative transactions may be marked to fair value through regulatory assets/liabilities at PPL Electric, LG&E and KU, if approved by the appropriate regulatory body. These transactions generally include the effect of interest rate swaps that are included in customer rates. (PPL and PPL Electric) To meet its obligation as a PLR to its customers, PPL Electric has entered into certain contracts that meet the definition of a derivative. However, NPNS has been elected for these contracts. See Notes 17 and 18 for additional information on derivatives.
Revenue Recognition	(All Registrants) Operating revenues are primarily recorded based on energy deliveries through the end of each calendar month. Unbilled retail revenues result because customers' bills are rendered throughout the month, rather than bills being rendered at the end of the month. For LG&E and KU, unbilled revenues for a month are calculated by multiplying an estimate of unbilled kWh or Mcf by the estimated average cents per kWh or Mcf. Any difference between estimated and actual revenues is adjusted the following month when the previous unbilled estimate is reversed and actual billings occur. For PPL Electric, unbilled revenues for a month are calculated by multiplying the actual unbilled volumes by the price per tariff. PPL Electric's, LG&E's and KU's base rates are determined based on cost of service. Some regulators have also authorized the use of additional alternative revenue programs, which enable PPL Electric, LG&E and KU to adjust future rates based on past activities or completed events. Revenues from alternative revenue programs are recognized when the specific events permitting future billings have occurred. Revenues from alternative revenue programs are required to be presented separately from revenues from contracts with customers. These amounts are, however, presented as revenues from contracts with customers, with an offsetting adjustment to alternative revenue program revenue, when they are billed to customers in future periods. See Note 3 for additional information.
Cash	Cash (All Registrants) Cash Equivalents All highly liquid investments with original maturities of three months or less are considered to be cash equivalents. (PPL) Restricted Cash and Cash Equivalents Bank deposits and other cash equivalents that are restricted by agreement or that have been clearly designated for a specific purpose are classified as restricted cash and cash equivalents. On the Balance Sheets, the current portion of restricted cash and cash equivalents is included in "Other current assets," while the noncurrent portion is included in "Other noncurrent assets."
Fair Value Measurements	(All Registrants) Fair Value Measurements The Registrants value certain financial and nonfinancial assets and liabilities at fair value. Generally, the most significant fair value measurements relate to price risk management assets and liabilities, investments in securities in defined benefit plans, and cash and cash equivalents. PPL and its subsidiaries use, as appropriate, a market approach (generally, data from market transactions), an income approach (generally, present value techniques and option-pricing models) and/or a cost approach (generally, replacement cost) to measure the fair value of an asset or liability. These valuation approaches incorporate inputs such as observable, independent market data and/or unobservable data that management believes are predicated on the assumptions market participants would use to price an asset or liability. These inputs may incorporate, as applicable, certain risks such as nonperformance risk, which includes credit risk. The Registrants classify fair value measurements within one of three levels in the fair value hierarchy. The level assigned to a fair value measurement is based on the lowest level input that is significant to the fair value measurement in its entirety. The three levels of the fair value hierarchy are as follows: • Level 1 - quoted prices (unadjusted) in active markets for identical assets or liabilities that are accessible at the measurement date. Active markets are those in which transactions for the asset or liability occur with sufficient frequency and volume to provide pricing information on an ongoing basis. • Level 2 - inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for substantially the full term of the asset or liability. • Level 3 - unobservable inputs that management believes are predicated on the assumptions market participants would use to measure the asset or liability at fair value. Assessing the significance of a particular input requires judgment that considers factors specific to the asset or liability. As such, the Registrants' assessment of the significance of a particular input may affect how the assets and liabilities are classified within the fair value hierarchy.
Investments	Investments Generally, the original maturity date of an investment and management's intent and ability to sell an investment prior to its original maturity determine the classification of investments as either short-term or long-term. Investments that would otherwise be classified as short-term, but are restricted as to withdrawal or use for other than current operations or are clearly designated for expenditure in the acquisition or construction of noncurrent assets or for the liquidation of long-term debts, are classified as long-term. Investments in entities in which a company has the ability to exercise significant influence but does not have a controlling financial interest are accounted for under the equity method. All other investments are carried at cost or fair value. These investments are included in "Other noncurrent assets" on the Balance Sheets. Earnings from these investments are recorded in "Other Income (Expense) - net" on the Statements of Income. Short-term investments generally include certain deposits as well as securities that are considered highly liquid or provide for periodic reset of interest rates. Investments with original maturities greater than three months and less than a year, as well as investments with original maturities of greater than a year that management has the ability and intent to sell within a year, are included in "Other current assets" on the Balance Sheets.
Property, Plant and Equipment	Property, Plant and Equipment (All Registrants) PP&E is recorded at original cost, unless impaired. PP&E acquired in business combinations is recorded at fair value at the time of acquisition. If impaired, the asset is written down to fair value at that time, which becomes the new cost basis of the asset. Original cost for constructed assets includes material, labor, contractor costs, certain overheads and financing costs, where applicable. Included in PP&E are capitalized costs of software projects that were developed or obtained for internal use. The cost of repairs and minor replacements are charged to expense as incurred. The Registrants record costs associated with planned major maintenance projects in the period in which work is performed and costs are incurred. AFUDC is capitalized at PPL Electric as part of the construction costs for cost-based rate-regulated projects for which a return on such costs is recovered after the project is placed in service. The debt component of AFUDC is credited to "Interest Expense" and the equity component is credited to "Other Income (Expense) - net" on the Statements of Income. LG&E and KU generally do not record AFUDC as a return is provided on construction work in progress. (PPL and PPL Electric) Depreciation (All Registrants) Depreciation is recorded over the estimated useful lives of property using various methods including the straight-line, composite and group methods. When a component of PP&E that was depreciated under the composite or group method is retired, the original cost is charged to accumulated depreciation. When all or a significant portion of an operating unit that was depreciated under the composite or group method is retired or sold, the property and the related accumulated depreciation account is reduced and any gain or loss is included in income, unless otherwise required by regulators. LG&E and KU accrue costs of removal net of estimated salvage value through depreciation, which is included in the calculation of customer rates over the assets' depreciable lives in accordance with regulatory practices. Cost of removal amounts accrued through depreciation rates are accumulated as a regulatory liability until the removal costs are incurred. For LG&E and KU, all ARO depreciation expenses are reclassified to a regulatory asset or regulatory liability. See "Asset Retirement Obligations" below and Note 7 for additional information. PPL Electric records net costs of removal when incurred as a regulatory asset. The regulatory asset is subsequently amortized through depreciation over a five-year period, which is recoverable in customer rates in accordance with regulatory practices.
Goodwill and Other Intangible Assets	Goodwill and Other Intangible Assets ( All Registrants) Goodwill represents the excess of the purchase price paid over the fair value of the identifiable net assets acquired in a business combination. Other acquired intangible assets are initially measured based on their fair value. Intangibles that have finite useful lives are amortized over their useful lives based upon the pattern in which the economic benefits of the intangible assets are consumed or otherwise used. Costs incurred to obtain an initial license and renew or extend terms of licenses are capitalized as intangible assets. When determining the useful life of an intangible asset, including intangible assets that are renewed or extended, PPL and its subsidiaries consider: • the expected use of the asset; • the expected useful life of other assets to which the useful life of the intangible asset may relate; • legal, regulatory, or contractual provisions that may limit the useful life; • the company's historical experience as evidence of its ability to support renewal or extension; • the effects of obsolescence, demand, competition, and other economic factors; and, • the level of maintenance expenditures required to obtain the expected future cash flows from the asset.
Asset Impairment (Excluding Investments)	Asset Impairment (Excluding Investments) (All Registrants) The Registrants review long-lived assets that are subject to depreciation or amortization, including finite-lived intangibles, for impairment when events or circumstances indicate carrying amounts may not be recoverable. A long-lived asset classified as held and used is impaired when the carrying amount of the asset exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. If impaired, the asset's carrying value is written down to its fair value. A long-lived asset classified as held for sale is impaired when the carrying amount of the asset (disposal group) exceeds its fair value less cost to sell. If impaired, the asset's (disposal group's) carrying value is written down to its fair value less cost to sell. PPL, LG&E and KU review goodwill for impairment at the reporting unit level annually or more frequently when events or circumstances indicate that the carrying amount of a reporting unit may be greater than the unit's fair value. Additionally, goodwill must be tested for impairment in circumstances when a portion of goodwill has been allocated to a business to be disposed. PPL's, LG&E's and KU's reporting units are primarily at the operating segment level. PPL, for its Kentucky Regulated segment and LKE reporting units, and individually LG&E and KU may elect either to initially make a qualitative evaluation about the likelihood of an impairment of goodwill or to bypass the qualitative evaluation and test goodwill for impairment using a quantitative test. If the qualitative evaluation (referred to as step zero) is elected and the assessment results in a determination that it is not more likely than not that the fair value of a reporting unit is less than the carrying amount, the quantitative impairment test is not necessary. However, the quantitative impairment test is required if management concludes it is more likely than not that the fair value of a reporting unit is less than the carrying amount based on the step zero assessment. If the carrying amount of the reporting unit, including goodwill, exceeds its fair value, an impairment loss is recognized in an amount equal to that excess, limited to the total amount of goodwill allocated to that reporting unit. In the fourth quarter of 2021, PPL, for its Kentucky Regulated segment and LKE reporting units, and individually, LG&E and KU, elected to perform qualitative step zero evaluations for their annual goodwill impairment tests, as of October 1, 2021. Based on these evaluations, management concluded it was not "more likely than not" that the fair value of these reporting units was less than their carrying values. As such, quantitative impairment tests were not performed. (PPL) During the three month-period ended June 30, 2021, Safari Energy determined that the carrying value of its solar panel inventory would not be fully recoverable due to a decrease in the net realizable value of the modules. The decrease was due primarily to the combination of the three following factors: (1) a continued decrease in the fair value of the modules on hand due to more efficient modules being available on the market, (2) the federal government's extension of certain investment tax credits which make modules on the open market eligible for those credits at higher levels of credits and (3) an increase in commodity prices for materials used in various types of solar projects, all of which place pressure on the economics of those projects, making the cost of Safari's solar panels uncompetitive. As a result, Safari Energy recorded a loss of $37 million ($28 million after-tax) in June 2021 to record the solar panels at fair value. The loss was recorded to "Other operation and maintenance" expense on the Statement of Income. Solar panel inventories of $32 million are included in "Other noncurrent assets" on PPL's Balance Sheet at December 31, 2021. PPL considered whether the events and circumstances that led to the impairment of Safari Energy's solar panels would more likely than not reduce the fair value of PPL's Distributed Energy Resources reporting unit below its carrying amount. Based on PPL's assessment, a quantitative impairment test was not required as of June 30, 2021. In the fourth quarter of 2021, PPL elected to perform a quantitative goodwill impairment test in conjunction with the annual goodwill impairment assessment for the Distributed Energy Resources reporting unit. The test did not indicate impairment of the reporting unit , however, it is possible that an impairment charge could occur in future periods if any of the assumptions used in determining fair value of the reporting unit are negatively impacted.
Asset Retirement Obligations	( PPL, LG&E and KU ) Asset Retirement Obligations PPL and its subsidiaries record liabilities to reflect various legal obligations associated with the retirement of long-lived assets. Initially, this obligation is measured at fair value and offset with an increase in the value of the capitalized asset, which is depreciated over the asset's useful life. Until the obligation is settled, the liability is increased through the recognition of accretion expense classified within "Other operation and maintenance" on the Statements of Income to reflect changes in the obligation due to the passage of time. For LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, deferred accretion and depreciation expense is recovered through cost of removal. Estimated ARO costs and settlement dates, which affect the carrying value of the ARO and the related capitalized asset, are reviewed periodically to ensure that any material changes are incorporated into the latest estimate of the ARO. Any change to the capitalized asset, positive or negative, is generally amortized over the remaining life of the associated long-lived asset. See Note 7 and Note 20 for additional information on AROs.
Compensation and Benefits	Compensation and Benefits Defined Benefits (All Registrants) Certain PPL subsidiaries sponsor various defined benefit pension and other postretirement plans. An asset or liability is recorded to recognize the funded status of all defined benefit plans with an offsetting entry to AOCI or, for LG&E, KU and PPL Electric, to regulatory assets or liabilities. Consequently, the funded status of all defined benefit plans is fully recognized on the Balance Sheets. The expected return on plan assets is determined based on a market-related value of plan assets, which is calculated by rolling forward the prior year market-related value with contributions, disbursements and long-term expected return on investments. One-fifth of the difference between the actual value and the expected value is added (or subtracted if negative) to the expected value to determine the new market-related value. PPL uses an accelerated amortization method for the recognition of gains and losses for its defined benefit pension plans. Under the accelerated method, actuarial gains and losses in excess of 30% of the plan's projected benefit obligation are amortized on a straight-line basis over one-half of the required amortization period. Actuarial gains and losses in excess of 10% of the greater of the plan's projected benefit obligation or the market-related value of plan assets and less than 30% of the plan's projected benefit obligation are amortized on a straight-line basis over the full required amortization period. See Note 7 for a discussion of the regulatory treatment of defined benefit costs and Note 12 for a discussion of defined benefits. Stock-Based Compensation (PPL and PPL Electric) PPL has several stock-based compensation plans for purposes of granting stock options, restricted stock, restricted stock units and performance units to certain employees as well as stock units and restricted stock units to directors. PPL grants most stock-based awards in the first quarter of each year. PPL and its subsidiaries recognize compensation expense for stock-based awards based on the fair value method. Forfeitures of awards are recognized when they occur. See Note 11 for a discussion of stock-based compensation. All awards are recorded as equity or a liability on the Balance Sheets. Stock-based compensation is primarily included in "Other operation and maintenance" on the Statements of Income. Stock-based compensation expense for PPL Electric includes an allocation of PPL Services' expense.
Income Taxes	Taxes Income Taxes (All Registrants) PPL and its domestic subsidiaries file a consolidated U.S. federal income tax return. Significant management judgment is required in developing the Registrants' provision for income taxes, primarily due to the uncertainty related to tax positions taken or expected to be taken on tax returns and valuation allowances on deferred tax assets. The Registrants use a two-step process to evaluate tax positions. The first step requires an entity to determine whether, based on the technical merits supporting a particular tax position, it is more likely than not (greater than a 50% chance) that the tax position will be sustained. This determination assumes that the relevant taxing authority will examine the tax position and is aware of all the relevant facts surrounding the tax position. The second step requires an entity to recognize in its financial statements the benefit of a tax position that meets the more-likely-than-not recognition criterion. The benefit recognized is measured at the largest amount of benefit that has a likelihood of realization upon settlement that exceeds 50%. Unrecognized tax benefits are classified as current to the extent management expects to settle the uncertain tax position by payment or receipt of cash within one year of the reporting date. The amounts ultimately paid upon resolution of issues raised by taxing authorities may differ materially from the amounts accrued and may materially impact the financial statements of the Registrants in future periods. At December 31, 2021, no significant changes in unrecognized tax benefits were projected over the next 12 months. Deferred income taxes reflect the net future tax effects of temporary differences between the carrying amounts of assets and liabilities for accounting purposes and their basis for income tax purposes, as well as the tax effects of net operating losses and tax credit carryforwards. The Registrants record valuation allowances to reduce deferred income tax assets to the amounts that are more-likely-than-not to be realized. The need for valuation allowances requires significant management judgment. If the Registrants determine that they are able to realize deferred tax assets in the future in excess of recorded net deferred tax assets, adjustments to the valuation allowances increase income by reducing tax expense in the period that such determination is made. Likewise, if the Registrants determine that they are not able to realize all or part of net deferred tax assets in the future, adjustments to the valuation allowances would decrease income by increasing tax expense in the period that such determination is made. The amount of deferred tax assets ultimately realized may differ materially from the estimates utilized in the computation of valuation allowances and may materially impact the financial statements in the future . The Registrants defer investment tax credits when the credits are generated and amortize the deferred amounts over the average lives of the related assets. The Registrants recognize tax-related interest and penalties in "Income Taxes" on their Statements of Income. The Registrants use the portfolio approach method of accounting for deferred taxes related to pre-tax OCI transactions. The portfolio approach involves a strict period-by-period cumulative incremental allocation of income taxes to the change in income and losses reflected in OCI. Under this approach, the net cumulative tax effect is ignored. The net change in unrealized gains and losses recorded in AOCI under this approach would be eliminated only on the date the investment portfolio is classified as held for sale or is liquidated. See Note 6 to the Financial Statements for income tax disclosures. The provision for the Registrants' deferred income taxes related to regulatory assets and liabilities is based upon the ratemaking principles reflected in rates established by relevant regulators. The difference in the provision for deferred income taxes for regulatory assets and liabilities and the amount that otherwise would be recorded under GAAP is deferred and included on the Balance Sheets in noncurrent "Regulatory assets" or "Regulatory liabilities."
Taxes, Other Than Income	Taxes, Other Than Income (All Registrants) The Registrants present sales taxes in "Other current liabilities" on the Balance Sheets. These taxes are not reflected on the Statements of Income. See Note 6 for details of taxes included in "Taxes, other than income" on the Statements of Income.
Leases	(All Registrants) Leases The Registrants evaluate whether arrangements entered into contain leases for accounting purposes. See Note 10 for additional information.
Fuel, Materials and Supplies	Fuel, Materials and Supplies Fuel, natural gas stored underground and materials and supplies are valued using the average cost method. Fuel costs for electricity generation are charged to expense as used. For LG&E, natural gas supply costs are charged to expense as delivered to the distribution system. See Note 7 for further discussion of the fuel adjustment clauses and gas supply clause.
Guarantees	Guarantees Generally, the initial measurement of a guarantee liability is the fair value of the guarantee at its inception. However, there are certain guarantees excluded from the scope of accounting guidance and other guarantees that are not subject to the initial recognition and measurement provisions of accounting guidance that only require disclosure. See Note 14 for further discussion of recorded and unrecorded guarantees.
Treasury Stock	Treasury Stock
Foreign Currency Translation and Transactions	Foreign Currency Translation and Transactions Adjustments resulting from foreign currency translation are recorded in AOCI and reclassified to income when the related foreign entity is sold. See Note 21 for additional information.
Financing Receivable, Allowance for Credit Losses, Policy for Uncollectible Amounts	Financing and Other Receivables (All Registrants) Accounts receivable are reported on the Balance Sheets at the gross outstanding amount adjusted for an allowance for doubtful accounts. Financing receivables include accounts receivable, with the exception of those items within accounts receivable that are not subject to the credit loss model. Financing receivable collectibility is evaluated using a current expected credit loss model, consisting of a combination of factors, including past due status based on contractual terms, trends in write-offs and the age of the receivable. Specific events, such as bankruptcies, are also considered when applicable. Adjustments to the allowance for doubtful accounts are made when necessary based on the results of analysis, the aging of receivables and historical and industry trends. The Registrants periodically evaluate the impact of observable external factors on the collectibility of the financing receivables to determine if adjustments to the allowance for doubtful accounts should be made based on current conditions or reasonable and supportable forecasts. Accounts receivable are written off in the period in which the receivable is deemed uncollectible. (PPL and PPL Electric) PPL Electric has identified one class of financing receivables, “accounts receivable - customer”, which includes financing receivables for all billed and unbilled sales with residential and non-residential customers. All other financing receivables are classified as other. Within the credit loss model for the residential customer accounts receivables, customers are disaggregated based on their projected propensity to pay, which is derived from historical trends and the current activity of the individual customer accounts. Conversely, the non-residential customer accounts receivables are not further segmented due to the varying nature of the individual customers, which lack readily identifiable risk characteristics for disaggregation. (PPL, LG&E and KU) LG&E and KU have identified one class of financing receivables, “accounts receivable - customer”, which includes financing receivables for all billed and unbilled sales with customers. All other financing receivables are classified as other.
PPL Electric Utilities Corp [Member]
Summary of Significant Accounting Policies [Line Items]
Business and Consolidation	PPL Electric is a cost-based rate-regulated utility subsidiary of PPL. PPL Electric's principal business is the transmission and distribution of electricity to serve retail customers in its franchised territory in eastern and central Pennsylvania and the regulated supply of electricity to retail customers in that territory as a PLR.
Price Risk Management	(PPL and PPL Electric) To meet its obligation as a PLR to its customers, PPL Electric has entered into certain contracts that meet the definition of a derivative. However, NPNS has been elected for these contracts. See Notes 17 and 18 for additional information on derivatives.
Accounts Receivable	(PPL and PPL Electric) PPL Electric has identified one class of financing receivables, “accounts receivable - customer”, which includes financing receivables for all billed and unbilled sales with residential and non-residential customers. All other financing receivables are classified as other. Within the credit loss model for the residential customer accounts receivables, customers are disaggregated based on their projected propensity to pay, which is derived from historical trends and the current activity of the individual customer accounts. Conversely, the non-residential customer accounts receivables are not further segmented due to the varying nature of the individual customers, which lack readily identifiable risk characteristics for disaggregation.
Compensation and Benefits	Stock-Based Compensation (PPL and PPL Electric) PPL has several stock-based compensation plans for purposes of granting stock options, restricted stock, restricted stock units and performance units to certain employees as well as stock units and restricted stock units to directors. PPL grants most stock-based awards in the first quarter of each year. PPL and its subsidiaries recognize compensation expense for stock-based awards based on the fair value method. Forfeitures of awards are recognized when they occur. See Note 11 for a discussion of stock-based compensation. All awards are recorded as equity or a liability on the Balance Sheets. Stock-based compensation is primarily included in "Other operation and maintenance" on the Statements of Income. Stock-based compensation expense for PPL Electric includes an allocation of PPL Services' expense.
Income Taxes	(PPL Electric, LG&E and KU) The income tax provision for PPL Electric, LG&E and KU is calculated in accordance with an intercompany tax sharing agreement, which provides that taxable income be calculated as if PPL Electric, LG&E, KU and any domestic subsidiaries each filed a separate return. Tax benefits are not shared between companies. The entity that generates a tax benefit is the entity that is entitled to the tax benefit. The effect of PPL filing a consolidated tax return is taken into account in the settlement of current taxes and the recognition of deferred taxes.
Louisville Gas And Electric Co [Member]
Summary of Significant Accounting Policies [Line Items]
Business and Consolidation	LG&E and KU are engaged in the generation, transmission, distribution and sale of electricity. LG&E also engages in the distribution and sale of natural gas. LG&E and KU maintain their separate identities and serve customers in Kentucky under their respective names. KU also serves customers in Virginia under the Old Dominion Power name.
Accounts Receivable	(PPL, LG&E and KU) LG&E and KU have identified one class of financing receivables, “accounts receivable - customer”, which includes financing receivables for all billed and unbilled sales with customers. All other financing receivables are classified as other.
Asset Retirement Obligations	( PPL, LG&E and KU ) Asset Retirement Obligations PPL and its subsidiaries record liabilities to reflect various legal obligations associated with the retirement of long-lived assets. Initially, this obligation is measured at fair value and offset with an increase in the value of the capitalized asset, which is depreciated over the asset's useful life. Until the obligation is settled, the liability is increased through the recognition of accretion expense classified within "Other operation and maintenance" on the Statements of Income to reflect changes in the obligation due to the passage of time. For LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, deferred accretion and depreciation expense is recovered through cost of removal. Estimated ARO costs and settlement dates, which affect the carrying value of the ARO and the related capitalized asset, are reviewed periodically to ensure that any material changes are incorporated into the latest estimate of the ARO. Any change to the capitalized asset, positive or negative, is generally amortized over the remaining life of the associated long-lived asset. See Note 7 and Note 20 for additional information on AROs.
Income Taxes	(PPL Electric, LG&E and KU) The income tax provision for PPL Electric, LG&E and KU is calculated in accordance with an intercompany tax sharing agreement, which provides that taxable income be calculated as if PPL Electric, LG&E, KU and any domestic subsidiaries each filed a separate return. Tax benefits are not shared between companies. The entity that generates a tax benefit is the entity that is entitled to the tax benefit. The effect of PPL filing a consolidated tax return is taken into account in the settlement of current taxes and the recognition of deferred taxes.
Kentucky Utilities Co [Member]
Summary of Significant Accounting Policies [Line Items]
Business and Consolidation	LG&E and KU are engaged in the generation, transmission, distribution and sale of electricity. LG&E also engages in the distribution and sale of natural gas. LG&E and KU maintain their separate identities and serve customers in Kentucky under their respective names. KU also serves customers in Virginia under the Old Dominion Power name.
Accounts Receivable	(PPL, LG&E and KU) LG&E and KU have identified one class of financing receivables, “accounts receivable - customer”, which includes financing receivables for all billed and unbilled sales with customers. All other financing receivables are classified as other.
Asset Retirement Obligations	( PPL, LG&E and KU ) Asset Retirement Obligations PPL and its subsidiaries record liabilities to reflect various legal obligations associated with the retirement of long-lived assets. Initially, this obligation is measured at fair value and offset with an increase in the value of the capitalized asset, which is depreciated over the asset's useful life. Until the obligation is settled, the liability is increased through the recognition of accretion expense classified within "Other operation and maintenance" on the Statements of Income to reflect changes in the obligation due to the passage of time. For LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, deferred accretion and depreciation expense is recovered through cost of removal. Estimated ARO costs and settlement dates, which affect the carrying value of the ARO and the related capitalized asset, are reviewed periodically to ensure that any material changes are incorporated into the latest estimate of the ARO. Any change to the capitalized asset, positive or negative, is generally amortized over the remaining life of the associated long-lived asset. See Note 7 and Note 20 for additional information on AROs.
Income Taxes	(PPL Electric, LG&E and KU) The income tax provision for PPL Electric, LG&E and KU is calculated in accordance with an intercompany tax sharing agreement, which provides that taxable income be calculated as if PPL Electric, LG&E, KU and any domestic subsidiaries each filed a separate return. Tax benefits are not shared between companies. The entity that generates a tax benefit is the entity that is entitled to the tax benefit. The effect of PPL filing a consolidated tax return is taken into account in the settlement of current taxes and the recognition of deferred taxes.

Fair Value Measurements (Polici

Fair Value Measurements (Policies)	12 Months Ended
	Dec. 31, 2021
Fair Value Disclosures [Abstract]
Fair Value Measurements	The fair value of a group of financial assets and liabilities is measured on a net basis.

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Policies)	12 Months Ended
	Dec. 31, 2021
Derivative Instruments And Hedging Activities [Line Items]
Fair Value of Derivatives	Price Risk Management (All Registrants) Interest rate contracts are used to hedge exposure to changes in the fair value of debt instruments and to hedge exposure to variability in expected cash flows associated with existing floating-rate debt instruments or forecasted fixed-rate issuances of debt. Foreign currency exchange contracts are used to hedge foreign currency exposures. Similar derivatives may receive different accounting treatment, depending on management's intended use and documentation. Certain contracts may not meet the definition of a derivative because they lack a notional amount or a net settlement provision. In cases where there is no net settlement provision, markets are periodically assessed to determine whether market mechanisms have evolved to facilitate net settlement. Certain derivative contracts may be excluded from the requirements of derivative accounting treatment because the NPNS has been elected. These contracts are accounted for using accrual accounting. Contracts that have been classified as derivative contracts are reflected on the balance sheets at fair value. The portion of derivative positions that deliver within a year are included in "Current Assets" and "Current Liabilities," while the portion of derivative positions that deliver beyond a year are recorded in "Other Noncurrent Assets" and "Deferred Credits and Other Noncurrent Liabilities." Cash inflows and outflows related to derivative instruments are included as a component of operating, investing or financing activities on the Statements of Cash Flows, depending on the classification of the hedged items. PPL and its subsidiaries have elected not to offset net derivative positions against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements. (PPL) Processes exist that allow for subsequent review and validation of contract information as it relates to interest rate derivatives and foreign currency derivatives. The accounting department provides the treasury department with guidelines on appropriate accounting classifications for various contract types and strategies. Examples of accounting guidelines provided to the treasury department staff include, but are not limited to: • Transactions to lock in an interest rate prior to a debt issuance can be designated as cash flow hedges, to the extent the forecasted debt issuances remain probable of occurring. • Cross-currency transactions to hedge interest and principal repayments can be designated as cash flow hedges. • Transactions to hedge fluctuations in the fair value of existing debt can be designated as fair value hedges. • Transactions to hedge the value of a net investment of foreign operations can be designated as net investment hedges. • Derivative transactions that do not qualify for cash flow or net investment hedge treatment are marked to fair value through earnings. As such, these transactions reduce earnings volatility due solely to changes in foreign currency exchange rates. PPL also hedges anticipated transactions, including the previously completed sale of its U.K utility business and net investments. (All Registrants) Derivative transactions may be marked to fair value through regulatory assets/liabilities at PPL Electric, LG&E and KU, if approved by the appropriate regulatory body. These transactions generally include the effect of interest rate swaps that are included in customer rates. (PPL and PPL Electric) To meet its obligation as a PLR to its customers, PPL Electric has entered into certain contracts that meet the definition of a derivative. However, NPNS has been elected for these contracts. See Notes 17 and 18 for additional information on derivatives.
Price Risk Management	Net derivative positions on the balance sheets are not offset against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements.
Louisville Gas And Electric Co [Member]
Derivative Instruments And Hedging Activities [Line Items]
Price Risk Management	Net derivative positions on the balance sheets are not offset against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements.
Kentucky Utilities Co [Member]
Derivative Instruments And Hedging Activities [Line Items]
Price Risk Management	Net derivative positions on the balance sheets are not offset against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2021
Summary of Significant Accounting Policies [Line Items]
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow	The following provides a reconciliation of Cash, Cash Equivalents and Restricted Cash reported within the Balance Sheets to the amounts shown on the Statements of Cash Flows: December 31, December 31, Cash and cash equivalents $ 3,571 $ 442 Restricted cash - current 1 1 Total Cash, Cash Equivalents and Restricted Cash $ 3,572 $ 443
Capitalized Interest Table Text Block	Capitalized interest, including the debt component of AFUDC, for the years ended December 31 is as follows: 2021 2020 2019 PPL $ 6 $ 7 $ 9 PPL Electric 6 7 8
Weighted-average Rates of Depreciation	Following are the weighted-average annual rates of depreciation, for regulated utility plant, for the years ended December 31: 2021 2020 2019 PPL 3.61 % 3.53 % 3.54 % PPL Electric 3.05 % 2.99 % 3.05 % LG&E 3.99 % 4.00 % 3.87 % KU 4.17 % 4.00 % 4.02 %
Schedule of Utility Inventory	"Fuel, materials and supplies" on the Balance Sheets consisted of the following at December 31: 2021 PPL PPL Electric LG&E KU Fuel $ 90 $ — $ 32 $ 58 Natural gas stored underground 54 — 54 — Materials and supplies 178 61 51 66 Total $ 322 $ 61 $ 137 $ 124 2020 PPL PPL Electric LG&E KU Fuel $ 95 $ — $ 38 $ 57 Natural gas stored underground 30 — 30 — Materials and supplies 177 59 51 66 Total $ 302 $ 59 $ 119 $ 123
Schedule of Valuation and Qualifying Accounts Disclosure	The changes in the allowance for doubtful accounts are included in the following table. Amounts relate to financing receivables, except as noted. Additions Balance at Charged to Income Charged to Other Accounts Deductions (b) Balance at PPL 2021 $ 73 $ 26 $ — $ 30 $ 69 (d) 2020 (a) 58 (a) 28 — 13 73 (d) 2019 54 34 3 35 56 PPL Electric 2021 $ 41 $ 13 $ — $ 19 $ 35 (c) 2020 30 (a) 19 — 8 41 (c) 2019 27 26 — 25 28 LG&E 2021 $ 3 $ 4 $ — $ 4 $ 3 2020 1 4 — 2 3 2019 1 2 2 4 1 KU 2021 $ 2 $ 8 $ — $ 7 $ 3 2020 1 4 — 3 2 2019 2 4 1 6 1 (a) Adjusted for $2 million cumulative-effect adjustment upon adoption of current expected credit loss guidance. (b) Primarily related to uncollectible accounts written off. (c) Includes $3 million related to other accounts receivables at December 31, 2021 and 2020.
PPL Electric Utilities Corp [Member]
Summary of Significant Accounting Policies [Line Items]
Capitalized Interest Table Text Block	Capitalized interest, including the debt component of AFUDC, for the years ended December 31 is as follows: 2021 2020 2019 PPL $ 6 $ 7 $ 9 PPL Electric 6 7 8
Intercompany tax receivables (payables)	At December 31, the following intercompany tax receivables (payables) were recorded: 2021 2020 PPL Electric $ (4) $ (9) LG&E 4 (1) KU 1 (5)
Louisville Gas And Electric Co [Member]
Summary of Significant Accounting Policies [Line Items]
Intercompany tax receivables (payables)	At December 31, the following intercompany tax receivables (payables) were recorded: 2021 2020 PPL Electric $ (4) $ (9) LG&E 4 (1) KU 1 (5)
Kentucky Utilities Co [Member]
Summary of Significant Accounting Policies [Line Items]
Intercompany tax receivables (payables)	At December 31, the following intercompany tax receivables (payables) were recorded: 2021 2020 PPL Electric $ (4) $ (9) LG&E 4 (1) KU 1 (5)

Segment and Related Informati_2

Segment and Related Information (Tables)	12 Months Ended
	Dec. 31, 2021
Segment Reporting [Abstract]
Segment and Related Information	Income Statement data for the segments and reconciliation to PPL's consolidated results for the years ended December 31 are as follows: 2021 2020 2019 Operating Revenues from external customers (a) Kentucky Regulated $ 3,348 $ 3,106 $ 3,206 Pennsylvania Regulated 2,402 2,330 2,358 Corporate and Other 33 38 38 Total $ 5,783 $ 5,474 $ 5,602 2021 2020 2019 Depreciation Kentucky Regulated $ 647 $ 606 $ 547 Pennsylvania Regulated 424 403 386 Corporate and Other 11 13 16 Total $ 1,082 $ 1,022 $ 949 Amortization (b) Kentucky Regulated $ 15 $ 19 $ 27 Pennsylvania Regulated 19 26 24 Corporate and Other 5 13 7 Total $ 39 $ 58 $ 58 Interest Expense (c) Kentucky Regulated $ 249 $ 300 $ 298 Pennsylvania Regulated 162 172 169 Corporate and Other (d) 507 162 154 Total $ 918 $ 634 $ 621 Income Before Income Taxes Kentucky Regulated $ 562 $ 516 $ 530 Pennsylvania Regulated 599 664 607 Corporate and Other (640) (226) (218) Total $ 521 $ 954 $ 919 Income Taxes (e) Kentucky Regulated $ 94 $ 98 $ 94 Pennsylvania Regulated 154 167 149 Corporate and Other 255 49 (60) Total $ 503 $ 314 $ 183 Deferred income taxes and investment tax credits (f) Kentucky Regulated $ 272 $ 64 $ 82 Pennsylvania Regulated 79 82 90 Corporate and Other (264) 23 (3) Total $ 87 $ 169 $ 169 Net Income Kentucky Regulated $ 468 $ 418 $ 436 Pennsylvania Regulated 445 497 458 Corporate and Other (d) (895) (275) (158) Discontinued Operations (1,498) 829 1,010 Total $ (1,480) $ 1,469 $ 1,746 (a) See Note 1 and Note 3 for additional information on Operating Revenues. (b) Represents non-cash expense items that include amortization of operating lease right-of-use assets, regulatory assets and liabilities, debt discounts and premiums and debt issuance costs. (c) Beginning in 2021, corporate level financing costs are no longer allocated to the reportable segments and are being reported in Corporate and Other. For the years ended December 31, 2020 and 2019, corporate level financing costs of $32 million, net of $8 million of income taxes, and $32 million, net of $9 million of income taxes, were allocated to the Kentucky Regulated segment. For the years ended December 31, 2020 and 2019, an immaterial amount of financing costs were allocated to the Pennsylvania Regulated segment. (d) 2021 includes losses from the extinguishment of PPL Capital Funding debt. See Note 8 for additional information. (e) Represents both current and deferred income taxes, including investment tax credits. (f) Represents a non-cash expense item that is also included in "Income Taxes." Cash Flow data for the segments and reconciliation to PPL's consolidated results for the years ended December 31 are as follows: 2021 2020 2019 Expenditures for long-lived assets Kentucky Regulated $ 1,026 $ 966 $ 1,097 Pennsylvania Regulated 904 1,154 1,121 Corporate and Other 49 158 32 Total $ 1,979 $ 2,278 $ 2,250 The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated results as of: As of December 31, 2021 2020 Total Assets Kentucky Regulated $ 16,360 $ 15,943 Pennsylvania Regulated 13,336 12,347 Corporate and Other (a) 3,527 843 Assets held for sale (b) — 18,983 Total $ 33,223 $ 48,116 (a) Primarily consists of unallocated items, including cash, PP&E, goodwill, the elimination of inter-segment transactions as well as the assets of Safari Energy. (b) See Note 9 for additional information.

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	12 Months Ended
	Dec. 31, 2021
Revenue from contracts with customers [Line Items]
Reconciliation of revenue from contracts with customers [Table Text Block]	The following table reconciles "Operating Revenues" included in each Registrant's Statement of Income with revenues generated from contracts with customers for the years ended December 31: 2021 PPL PPL Electric LG&E KU Operating Revenues (a) $ 5,783 $ 2,402 $ 1,569 $ 1,826 Revenues derived from: Alternative revenue programs (b) 77 83 (3) (3) Other (c) (22) (3) (8) (9) Revenues from Contracts with Customers $ 5,838 $ 2,482 $ 1,558 $ 1,814 2020 PPL PPL Electric LG&E KU Operating Revenues (a) $ 5,474 $ 2,331 $ 1,456 $ 1,690 Revenues derived from: Alternative revenue programs (b) (24) (12) (8) (4) Other (c) (21) (3) (7) (10) Revenues from Contracts with Customers $ 5,429 $ 2,316 $ 1,441 $ 1,676 2019 PPL PPL Electric LG&E KU Operating Revenues (a) $ 5,602 $ 2,358 $ 1,500 $ 1,740 Revenues derived from: Alternative revenue programs (b) (30) (6) (10) (14) Other (c) (31) (10) (9) (12) Revenues from Contracts with Customers $ 5,541 $ 2,342 $ 1,481 $ 1,714 (a) Amounts for PPL Electric represent revenues from external customers reported by the Pennsylvania Regulated segment and amounts for LG&E and KU, net of intercompany power sales and transmission revenues, represent revenues from external customers reported by the Kentucky Regulated segment. See Note 2 for additional information. (b) Alternative revenue programs include the transmission formula rate for PPL Electric, the ECR and DSM programs for LG&E and KU, the GLT and GSC programs for LG&E, and the generation formula rate for KU. For PPL Electric, revenue in 2021 was reduced by $78 million for a reduction in the transmission formula rate return on equity. See Note 7 for additional information. This line item shows the over/under collection of these rate mechanisms with over-collections of revenue shown as positive amounts in the table above and under-collections shown as negative amounts. (c) Represents additional revenues outside the scope of revenues from contracts with customers such as leases and other miscellaneous revenues.
Disaggregation of Revenue [Table Text Block]	The following table shows revenues from contracts with customers disaggregated by customer class for the years ended December 31: 2021 Residential Commercial Industrial Other (a) Wholesale - municipality Wholesale - other (b) Transmission Revenues from Contracts with Customers PPL PA Regulated $ 1,299 $ 350 $ 53 $ 50 $ — $ — $ 730 $ 2,482 KY Regulated 1,416 928 586 305 24 66 — 3,325 Corp and Other — — — 31 — — — 31 Total PPL $ 2,715 $ 1,278 $ 639 $ 386 $ 24 $ 66 $ 730 $ 5,838 PPL Electric $ 1,299 $ 350 $ 53 $ 50 $ — $ — $ 730 $ 2,482 LG&E $ 711 $ 473 $ 180 $ 145 $ — $ 49 $ — $ 1,558 KU $ 705 $ 455 $ 406 $ 160 $ 24 $ 64 $ — $ 1,814 2020 Residential Commercial Industrial Other (a) Wholesale - municipality Wholesale - other (b) Transmission Revenues from Contracts with Customers PPL PA Regulated $ 1,238 $ 314 $ 44 $ 50 $ — $ — $ 670 $ 2,316 KY Regulated 1,347 871 538 261 20 40 — 3,077 Corp and Other — — — 36 — — — 36 Total PPL $ 2,585 $ 1,185 $ 582 $ 347 $ 20 $ 40 $ 670 $ 5,429 PPL Electric $ 1,238 $ 314 $ 44 $ 50 $ — $ — $ 670 $ 2,316 LG&E $ 676 $ 444 $ 173 $ 114 $ — $ 34 $ — $ 1,441 KU $ 671 $ 427 $ 365 $ 147 $ 20 $ 46 $ — $ 1,676 2019 Residential Commercial Industrial Other (a) Wholesale - municipality Wholesale - other (b) Transmission Revenues from Contracts with Customers PPL PA Regulated $ 1,288 $ 349 $ 59 $ 52 $ — $ — $ 594 $ 2,342 KY Regulated 1,322 908 562 277 43 49 — 3,161 Corp and Other — — — 38 — — — 38 Total PPL $ 2,610 $ 1,257 $ 621 $ 367 $ 43 $ 49 $ 594 $ 5,541 PPL Electric $ 1,288 $ 349 $ 59 $ 52 $ — $ — $ 594 $ 2,342 LG&E $ 668 $ 466 $ 180 $ 121 $ — $ 46 $ — $ 1,481 KU $ 654 $ 442 $ 382 $ 156 $ 43 $ 37 $ — $ 1,714 (a) Primarily includes revenues from pole attachments, street lighting, other public authorities and other non-core businesses. (b) Includes wholesale power and transmission revenues. LG&E and KU amounts include intercompany power sales and transmission revenues, which are eliminated upon consolidation at PPL.
Credit loss recognized from contract with customer [Table Text Block]	The following table shows the accounts receivable and unbilled revenues balances that were impaired for the year ended December 31: 2021 2020 2019 PPL $ 22 $ 25 $ 27 PPL Electric 10 17 21 LG&E 4 4 2 KU 8 4 4
Contract with Customer, Asset and Liability [Table Text Block]	The following table shows the balances and certain activity of contract liabilities resulting from contracts with customers: PPL PPL Electric LG&E KU Contract liabilities as of December 31, 2021 $ 42 $ 25 $ 6 $ 6 Contract liabilities as of December 31, 2020 40 23 5 6 Revenue recognized during the year ended December 31, 2021 that was included in the contract liability balance at December 31, 2020 24 11 5 6 Contract liabilities as of December 31, 2020 $ 40 $ 23 $ 5 $ 6 Contract liabilities as of December 31, 2019 37 21 5 4 Revenue recognized during the year ended December 31, 2020 that was included in the contract liability balance at December 31, 2019 22 9 5 4 Contract liabilities as of December 31, 2019 $ 37 $ 21 $ 5 $ 4 Contract liabilities as of December 31, 2018 40 23 5 4 Revenue recognized during the year ended December 31, 2019 that was included in the contract liability balance at December 31, 2018 25 11 5 4

Earnings Per Share (Tables)

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2021
Earnings Per Share [Abstract]
Basic and Diluted EPS Computations	Reconciliations of the amounts of income and shares of PPL common stock (in thousands) for the periods ended December 31, used in the EPS calculation are: 2021 2020 2019 Income (Numerator) Income from continuing operations after income taxes $ 18 $ 640 $ 736 Less amounts allocated to participating securities — 1 1 Income from continuing operations after income taxes available to PPL common shareowners - Basic and Diluted $ 18 $ 639 $ 735 Income (loss) from discontinued operations (net of income taxes) available to PPL common shareowners - Basic and Diluted $ (1,498) $ 829 $ 1,010 Net income (loss) attributable to PPL $ (1,480) $ 1,469 1,746 Less amounts allocated to participating securities — 1 1 Net income (loss) available to PPL common shareowners - Basic and Diluted $ (1,480) $ 1,468 $ 1,745 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 762,902 768,590 728,512 Add incremental non-participating securities: Add: Dilutive share-based payment awards (a) 1,917 794 1,101 Add: Forward sale agreements — — 7,141 Weighted-average shares - Diluted EPS 764,819 769,384 736,754 Basic EPS Available to PPL common shareowners: Income from continuing operations after income taxes $ 0.03 $ 0.83 $ 1.01 Income (loss) from discontinued operations (net of income taxes) (1.96) 1.08 1.38 Net Income (Loss) available to PPL common shareowners $ (1.93) $ 1.91 $ 2.39 Diluted EPS Available to PPL common shareowners: Income from continuing operations after income taxes $ 0.03 $ 0.83 $ 1.00 Income (loss) from discontinued operations (net of income taxes) (1.96) 1.08 1.37 Net Income (Loss) available to PPL common shareowners $ (1.93) $ 1.91 $ 2.37 (a) The Treasury Stock Method was applied to non-participating share-based payment awards.
Common Stock Issuances	For the years ended December 31, PPL issued common stock related to stock-based compensation plans and DRIP as follows (in thousands): 2021 2020 Stock-based compensation plans (a) 983 731 DRIP — 943 (a) Includes stock options exercised, vesting of performance units, vesting of restricted stock and restricted stock units and conversion of stock units granted to directors.
Antidilutive Securities Excluded From Diluted EPS	For the years ended December 31, the following shares (in thousands) were excluded from the computations of diluted EPS because the effect would have been antidilutive: 2021 2020 2019 Stock-based compensation awards 1,783 452 8

Income and Other Taxes (Tables)

Income and Other Taxes (Tables)	12 Months Ended
	Dec. 31, 2021
Income Taxes [Line Items]
Components of Deferred Tax Assets and Liabilities	Significant components of PPL's deferred income tax assets and liabilities were as follows: 2021 2020 Deferred Tax Assets Deferred investment tax credits $ 30 $ 30 Regulatory liabilities 94 68 Income taxes due to customers 422 444 Accrued pension and postretirement costs 75 106 Federal loss carryforwards (a) — 234 State loss carryforwards 483 448 Federal and state tax credit carryforwards (a) 15 401 Leases 67 68 Contributions in aid of construction 120 115 Other 84 68 Valuation allowances (462) (536) Total deferred tax assets 928 1,446 Deferred Tax Liabilities Plant - net 3,812 3,700 Regulatory assets 180 195 Other 75 70 Total deferred tax liabilities 4,067 3,965 Net deferred tax liability $ 3,139 $ 2,519
Summary of Operating Loss Carryforwards and Tax Credit Carryforwards	At December 31, 2021, PPL had the following loss and tax credit carryforwards, related deferred tax assets and valuation allowances recorded against the deferred tax assets: Gross Deferred Tax Asset Valuation Allowance Expiration Loss and other carryforwards State net operating losses $ 6,468 $ 483 $ (459) 2022-2041 Credit carryforwards State recycling credit 14 — 2028 State - other 1 — Indefinite
Schedule of Valuation and Qualifying Accounts of Deferred Tax Assets	The changes in deferred tax valuation allowances were as follows: Additions Balance at Charged Charged to Deductions Balance 2021 $ 536 $ 48 (a) $ — $ 122 (b) $ 462 2020 514 26 — 4 536 2019 495 24 — 5 514 (a) In 2021, PPL recorded a $31 million increase in a valuation allowance on a state net operating loss carryforward in connection with the loss on extinguishment associated with a tender offer to purchase and retire PPL Capital Funding's outstanding Senior Notes. See Note 8 for additional information on the tender offer. (b) In light of the disposition of PPL's U.K. utility business, there was a decrease in the valuation allowance of approximately $113 million.
Components of Income Tax Expense (Benefit)	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows: 2021 2020 2019 Income Tax Expense (Benefit) Current - Federal $ (1) $ (8) $ (10) Current - State 36 24 19 Current - Foreign (1) (2) — Total Current Expense (Benefit) 34 14 9 Deferred - Federal 28 135 141 Deferred - State 105 94 76 Deferred - Foreign (a) 383 101 (14) Total Deferred Expense (Benefit), excluding operating loss carryforwards 516 330 203 Amortization of investment tax credit (3) (3) (3) Tax expense (benefit) of operating loss carryforwards Deferred - Federal 12 6 7 Deferred - State (56) (33) (33) Total Tax Expense (Benefit) of Operating Loss Carryforwards (44) (27) (26) Total income tax expense (benefit) $ 503 $ 314 $ 183 Total income tax expense (benefit) - Federal $ 36 $ 130 $ 135 Total income tax expense (benefit) - State 85 85 62 Total income tax expense (benefit) - Foreign 382 99 (14) Total income tax expense (benefit) $ 503 $ 314 $ 183 (a) In 2021, the U.K. Finance Act 2021 increased the U.K. corporation tax rate from 19% to 25%, effective April 1, 2023. The primary impact of the corporation tax rate increase was an increase in deferred tax liabilities of the U.K. utility business, which was sold on June 14, 2021, and a corresponding deferred tax expense of $383 million, which was recognized in continuing operations in the second quarter of 2021. In 2020, the U.K. Finance Act 2020 cancelled the tax rate reduction from 19% to 17%. The primary impact of the cancellation of the corporation tax rate reduction was an increase in deferred tax liabilities and a corresponding deferred tax expense of $106 million. In the table above, the following income tax expense (benefit) are excluded from income taxes: 2021 2020 2019 Discontinued operations - PPL U.K. utility business $ 759 $ 188 $ 226 Reclassification from AOCI due to sale of UK utility business 660 — — Other comprehensive income 150 (19) (93) Total $ 1,569 $ 169 $ 133
Reconciliation of Income Tax Expense Derived From Statutory Tax Rate	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows: 2021 2020 2019 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 109 $ 200 $ 193 State income taxes, net of federal income tax benefit 23 48 45 Valuation allowance adjustments (a) 48 24 22 Federal and state income tax return adjustments (3) (9) 1 Impact of the U.K. Finance Acts on deferred tax balances (b) 383 101 (14) Depreciation and other items not normalized (5) (5) (10) Amortization of excess deferred federal and state income taxes (54) (43) (40) Non-deductible officer's salary 6 7 4 Kentucky recycling credit, net of federal income tax expense (c) — — (18) Other (4) (9) — Total increase (decrease) 394 114 (10) Total income tax expense (benefit) $ 503 $ 314 $ 183 Effective income tax rate 96.5% 32.9% 19.9% (a) In 2021, PPL recorded a $31 million state deferred tax benefit on a net operating loss and an offsetting valuation allowance in connection with the loss on extinguishment associated with a tender offer to purchase and retire PPL Capital Funding's outstanding Senior Notes. See Note 8 for additional information on the tender offer. In 2021, 2020, and 2019, PPL recorded deferred income tax expense of $15 million, $24 million and $25 million for valuation allowances primarily related to increased Pennsylvania net operating loss carryforwards expected to be unutilized. (b) In 2020, the U.K. Finance Act 2020 cancelled the tax rate reduction to 17%, thereby maintaining the corporation tax rate at 19% for financial years 2020 and 2021. The primary impact of the cancellation of the corporation tax rate reduction was an increase in deferred tax liabilities and a corresponding deferred tax expense of $106 million. In 2021, the U.K. Finance Act 2021 increased the U.K. corporation tax rate from 19% to 25%, effective April 1, 2023. The primary impact of the corporation tax rate increase was an increase in deferred tax liabilities of the U.K. utility business, which was sold on June 14, 2021, and a corresponding deferred tax expense of $383 million, which was recognized in continuing operations in the second quarter of 2021.
Details of Taxes Other Than Income	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows: 2021 2020 2019 Taxes, other than income State gross receipts $ 113 $ 100 $ 107 Domestic - other 94 80 79 Total $ 207 $ 180 $ 186
Summary of Income Tax Examinations	With few exceptions, at December 31, 2021, these jurisdictions, as well as the tax years that are no longer subject to examination, were as follows. PPL PPL Electric LG&E KU U.S. (federal) 2017 and prior 2017 and prior 2017 and prior 2017 and prior Pennsylvania (state) 2017 and prior 2017 and prior Kentucky (state) 2014 and prior 2014 and prior 2014 and prior U.K. (foreign) 2019 and prior
PPL Electric Utilities Corp [Member]
Income Taxes [Line Items]
Components of Deferred Tax Assets and Liabilities	Significant components of PPL Electric's deferred income tax assets and liabilities were as follows: 2021 2020 Deferred Tax Assets Accrued pension and postretirement costs $ 14 $ 25 Contributions in aid of construction 95 91 Regulatory liabilities 52 24 Income taxes due to customers 154 162 Federal loss carryforwards (a) — 52 Other 21 29 Total deferred tax assets 336 383 Deferred Tax Liabilities Electric utility plant - net 1,891 1,826 Regulatory assets 74 86 Other 39 30 Total deferred tax liabilities 2,004 1,942 Net deferred tax liability $ 1,668 $ 1,559
Components of Income Tax Expense (Benefit)	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows: 2021 2020 2019 Income Tax Expense (Benefit) Current - Federal $ 40 $ 61 $ 44 Current - State 35 23 15 Total Current Expense (Benefit) 75 84 59 Deferred - Federal 59 45 51 Deferred - State 20 38 39 Total Deferred Expense (Benefit), excluding operating loss carryforwards 79 83 90 Total income tax expense (benefit) $ 154 $ 167 $ 149 Total income tax expense (benefit) - Federal $ 99 $ 106 $ 95 Total income tax expense (benefit) - State 55 61 54 Total income tax expense (benefit) $ 154 $ 167 $ 149
Reconciliation of Income Tax Expense Derived From Statutory Tax Rate	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows: 2021 2020 2019 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 126 $ 139 $ 127 Increase (decrease) due to: State income taxes, net of federal income tax benefit 46 52 47 Federal and state income tax return adjustments — (4) 1 Depreciation and other items not normalized (5) (5) (10) Amortization of excess deferred federal income taxes (a) (14) (16) (18) Other 1 1 2 Total increase (decrease) 28 28 22 Total income tax expense (benefit) $ 154 $ 167 $ 149 Effective income tax rate 25.7% 25.2% 24.6% (a) In 2021, 2020 and 2019, PPL Electric recorded lower income tax expense for the amortization of excess deferred taxes that primarily resulted from the U.S. federal corporate income tax rate reduction from 35% to 21% enacted by the TCJA. This amortization represents each year's refund amount, prior to a tax gross-up, to be paid to customers for previously collected deferred taxes at higher income tax rates.
Details of Taxes Other Than Income	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows: 2021 2020 2019 Taxes, other than income State gross receipts $ 113 $ 100 $ 107 Property and other 7 7 5 Total $ 120 $ 107 $ 112
Louisville Gas And Electric Co [Member]
Income Taxes [Line Items]
Components of Deferred Tax Assets and Liabilities	Significant components of LG&E's deferred income tax assets and liabilities were as follows: 2021 2020 Deferred Tax Assets Contributions in aid of construction $ 15 $ 15 Regulatory liabilities 18 20 Deferred investment tax credits 8 8 Income taxes due to customers 125 132 State tax credit carryforwards 11 12 Lease liabilities 4 5 Valuation allowances (11) (12) Other 11 11 Total deferred tax assets 181 191 Deferred Tax Liabilities Plant - net 854 833 Regulatory assets 65 66 Lease right-of-use assets 4 4 Other 9 4 Total deferred tax liabilities 932 907 Net deferred tax liability $ 751 $ 716
Components of Income Tax Expense (Benefit)	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were: 2021 2020 2019 Income Tax Expense (Benefit) Current - Federal $ 41 $ 53 $ 4 Current - State 5 7 4 Total Current Expense (Benefit) 46 60 8 Deferred - Federal 1 (4) 46 Deferred - State 8 7 10 Total Deferred Expense (Benefit) 9 3 56 Amortization of investment tax credit - Federal (1) (1) (1) Total income tax expense (benefit) $ 54 $ 62 $ 63 Total income tax expense (benefit) - Federal $ 41 $ 48 $ 49 Total income tax expense (benefit) - State 13 14 14 Total income tax expense (benefit) $ 54 $ 62 $ 63
Reconciliation of Income Tax Expense Derived From Statutory Tax Rate	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were: 2021 2020 2019 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 64 $ 64 $ 62 Increase (decrease) due to: State income taxes, net of federal income tax benefit 12 12 12 Amortization of excess deferred federal and state income taxes (20) (11) (10) Kentucky recycling credit, net of federal income tax expense (a) — — (14) Valuation allowance adjustments (a) — — 14 Other (2) (3) (1) Total increase (decrease) (10) (2) 1 Total income tax expense (benefit) $ 54 $ 62 $ 63 Effective income tax rate 17.8% 20.3% 21.4%
Details of Taxes Other Than Income	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were: 2021 2020 2019 Taxes, other than income Property and other $ 46 $ 40 $ 39 Total $ 46 $ 40 $ 39
Kentucky Utilities Co [Member]
Income Taxes [Line Items]
Components of Deferred Tax Assets and Liabilities	Significant components of KU's deferred income tax assets and liabilities were as follows: 2021 2020 Deferred Tax Assets Contributions in aid of construction $ 9 $ 8 Regulatory liabilities 23 23 Deferred investment tax credits 22 22 Income taxes due to customers 143 150 State tax credit carryforwards 4 5 Lease liabilities 7 8 Valuation allowances (3) (4) Other 4 4 Total deferred tax assets 209 216 Deferred Tax Liabilities Plant - net 1,012 992 Regulatory assets 41 43 Pension and postretirement costs 13 8 Lease right-of-use assets 6 7 Other 2 1 Total deferred tax liabilities 1,074 1,051 Net deferred tax liability $ 865 $ 835
Components of Income Tax Expense (Benefit)	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were: 2021 2020 2019 Income Tax Expense (Benefit) Current - Federal $ 58 $ 40 $ 35 Current - State 8 3 5 Total Current Expense (Benefit) 66 43 40 Deferred - Federal (4) 11 28 Deferred - State 7 11 13 Total Deferred Expense (Benefit) 3 22 41 Amortization of investment tax credit - Federal (2) (2) (2) Total income tax expense (benefit) $ 67 $ 63 $ 79 Total income tax expense (benefit) - Federal $ 52 $ 49 $ 61 Total income tax expense (benefit) - State 15 14 18 Total income tax expense (benefit) $ 67 $ 63 $ 79
Reconciliation of Income Tax Expense Derived From Statutory Tax Rate	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were: 2021 2020 2019 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 76 $ 72 $ 78 Increase (decrease) due to: State income taxes, net of federal income tax benefit 14 14 15 Amortization of investment tax credit (2) (2) (2) Amortization of excess deferred federal and state income taxes (20) (17) (13) Kentucky recycling credit, net of federal income tax expense (a) — — (4) Valuation allowance adjustments (a) — — 4 Other (1) (4) 1 Total increase (decrease) (9) (9) 1 Total income tax expense (benefit) $ 67 $ 63 $ 79 Effective income tax rate 18.4% 18.4% 21.2%
Details of Taxes Other Than Income	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were: 2021 2020 2019 Taxes, other than income Property and other $ 41 $ 37 $ 35 Total $ 41 $ 37 $ 35

Utility Rate Regulation (Tables

Utility Rate Regulation (Tables)	12 Months Ended
	Dec. 31, 2021
Regulated Operations [Line Items]
Regulatory Assets and Liabilities	The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations at December 31: PPL PPL Electric 2021 2020 2021 2020 Current Regulatory Assets: Plant outage costs $ — $ 46 $ — $ — Gas supply clause 21 4 — — Smart meter rider 11 17 11 17 Transmission formula rate 6 15 6 15 Storm costs — 7 — 7 Fuel adjustment clause 11 — — — Other 15 10 5 1 Total current regulatory assets (a) $ 64 $ 99 $ 22 $ 40 Noncurrent Regulatory Assets: Defined benefit plans $ 523 $ 570 $ 256 $ 290 Plant outage cost 54 — — — Storm costs 11 17 — — Unamortized loss on debt 24 30 4 8 Interest rate swaps 18 23 — — Terminated interest rate swaps 70 75 — — Accumulated cost of removal of utility plant 228 240 228 240 AROs 302 300 — — Other 6 7 — 3 Total noncurrent regulatory assets $ 1,236 $ 1,262 $ 488 $ 541 PPL PPL Electric 2021 2020 2021 2020 Current Regulatory Liabilities: Generation supply charge $ 10 $ 21 $ 10 $ 21 Transmission service charge 21 1 21 1 Universal service rider 17 22 17 22 TCJA customer refund 22 11 22 11 Act 129 compliance rider 10 7 10 7 Transmission formula rate return on equity (b) 73 — 73 — Economic relief billing rate 27 — — — Other 2 17 — 6 Total current regulatory liabilities $ 182 $ 79 $ 153 $ 68 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 639 $ 653 $ — $ — Power purchase agreement - OVEC 35 43 — — Net deferred taxes 1,591 1,690 531 560 Defined benefit plans 95 60 28 18 Terminated interest rate swaps 62 66 — — Other — 18 — — Total noncurrent regulatory liabilities $ 2,422 $ 2,530 $ 559 $ 578 LG&E KU 2021 2020 2021 2020 Current Regulatory Assets: Gas supply clause $ 21 $ 4 $ — $ — Fuel adjustment clause 4 — 7 — Gas line tracker 3 4 — — Generation formula rate — — 2 2 Plant outage costs — 12 — 34 Other 5 3 — — Total current regulatory assets $ 33 $ 23 $ 9 $ 36 Noncurrent Regulatory Assets: Defined benefit plans $ 164 $ 174 $ 103 $ 106 Storm costs 8 11 3 6 Unamortized loss on debt 12 13 8 9 Interest rate swaps 18 23 — — Terminated interest rate swaps 41 44 29 31 AROs 75 85 227 215 Plant outage costs 15 — 39 — Other 4 1 2 3 Total noncurrent regulatory assets $ 337 $ 351 $ 411 $ 370 LG&E KU 2021 2020 2021 2020 Current Regulatory Liabilities: Economic relief billing credit $ 21 $ — $ 6 $ — Fuel adjustment clauses — — — 5 Environmental cost recovery — — — 4 Other — — 2 2 Total current regulatory liabilities $ 21 $ — $ 8 $ 11 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 262 $ 274 $ 377 $ 379 Power purchase agreement - OVEC 24 30 11 13 Net deferred taxes 491 528 569 602 Defined benefit plans 10 — 57 42 Terminated interest rate swaps 31 33 31 33 Other — 17 — 1 Total noncurrent regulatory liabilities $ 818 $ 882 $ 1,045 $ 1,070 (a) For PPL, these amounts are included in "Other current assets" on the Balance Sheets. (b) See “Regulatory Matters - Federal Matters - PPL Electric Transmission Formula Rate Return on Equity” below for additional information.

Financing Activities (Tables)

Financing Activities (Tables)	12 Months Ended
	Dec. 31, 2021
Debt Disclosure [Line Items]
Credit Facilities in Place at Period End	The following credit facilities were in place at: December 31, 2021 December 31, 2020 Expiration Capacity Borrowed Letters of Unused Capacity Borrowed Letters of PPL PPL Capital Funding Syndicated Credit Facility (a) (b) Dec 2026 $ 1,250 $ — $ — $ 1,250 $ — $ 402 Bilateral Credit Facility (a) (b) Mar 2022 50 — — 50 — — Bilateral Credit Facility (a) (b) Mar 2022 50 — 15 35 — 15 Term Loan Credit Facility (a) (b) Mar 2021 — — — — 200 — Term Loan Credit Facility (a) (b) Mar 2021 — — — — 100 — Term Loan Credit Facility (a) (b) Mar 2022 — — — — 100 — Total PPL Capital Funding Credit Facilities $ 1,350 $ — $ 15 $ 1,335 $ 400 $ 417 PPL Electric Syndicated Credit Facility (a) (b) Dec 2026 $ 650 $ — $ 1 $ 649 $ — $ 1 LG&E Syndicated Credit Facility (a) (b) Dec 2026 $ 500 $ — $ 69 $ 431 $ — $ 262 KU Syndicated Credit Facility (a) (b) Dec 2026 $ 400 $ — $ — $ 400 $ — $ 203 (a) Each company pays customary fees under its respective facility and borrowings generally bear interest at LIBOR-based rates plus an applicable margin. (b) The facilities contain a financial covenant requiring debt to total capitalization not to exceed 70% for PPL Capital Funding, PPL Electric, LG&E and KU, as calculated in accordance with the facilities and other customary covenants. Additionally, subject to certain conditions, PPL Capital Funding may request that the capacity of one of its bilateral credit facilities expiring in March 2022 be increased by up to $30 million and PPL Capital Funding, PPL Electric, LG&E and KU may each request up to a $250 million increase in its syndicated credit facility's capacity. Participation in any such increase is at the sole discretion of each lender.
Commercial paper	The following commercial paper programs were in place at: December 31, 2021 December 31, 2020 Weighted - Capacity Commercial Unused Weighted - Commercial PPL Capital Funding $ 1,500 $ — $ 1,500 0.25% $ 402 PPL Electric 650 — 650 — LG&E (a) 0.31% 425 69 356 0.28% 262 KU 350 — 350 0.28% 203 Total $ 2,925 $ 69 $ 2,856 $ 867 (a) In March 2021, the capacity for the LG&E commercial paper program was increased from $350 million to $425 million.
Long-term Debt	Long-term Debt (All Registrants) December 31, Weighted-Average Maturities (d) 2021 2020 PPL Senior Unsecured Notes 3.81 % 2026 - 2047 $ 1,566 $ 4,850 Senior Secured Notes/First Mortgage Bonds (a) (b) (c) 3.59 % 2022 - 2050 9,205 8,955 Junior Subordinated Notes 2.89 % 2067 480 930 Term Loan Credit Facility — 100 Total Long-term Debt before adjustments 11,251 14,835 Unamortized premium and (discount), net (34) (40) Unamortized debt issuance costs (77) (106) Total Long-term Debt 11,140 14,689 Less current portion of Long-term Debt 474 1,074 Total Long-term Debt, noncurrent $ 10,666 $ 13,615 December 31, Weighted-Average Maturities (d) 2021 2020 PPL Electric Senior Secured Notes/First Mortgage Bonds (a) (b) 3.37 % 2022 - 2049 $ 4,539 $ 4,289 Total Long-term Debt Before Adjustments 4,539 4,289 Unamortized discount (22) (23) Unamortized debt issuance costs (33) (30) Total Long-term Debt 4,484 4,236 Less current portion of Long-term Debt 474 400 Total Long-term Debt, noncurrent $ 4,010 $ 3,836 LG&E First Mortgage Bonds (a) (c) 3.59 % 2025 - 2049 $ 2,024 $ 2,024 Total Long-term Debt Before Adjustments 2,024 2,024 Unamortized discount (4) (4) Unamortized debt issuance costs (14) (13) Total Long-term Debt 2,006 2,007 Less current portion of Long-term Debt — 292 Total Long-term Debt, noncurrent $ 2,006 $ 1,715 KU First Mortgage Bonds (a) (c) 3.97 % 2023 - 2050 $ 2,642 $ 2,642 Total Long-term Debt Before Adjustments 2,642 2,642 Unamortized premium 5 5 Unamortized discount (9) (9) Unamortized debt issuance costs (20) (20) Total Long-term Debt 2,618 2,618 Less current portion of Long-term Debt — 132 Total Long-term Debt, noncurrent $ 2,618 $ 2,486 (a) Includes PPL Electric's senior secured and first mortgage bonds that are secured by the lien of PPL Electric's 2001 Mortgage Indenture, which covers substantially all of PPL Electric’s tangible distribution properties and certain of its tangible transmission properties located in Pennsylvania, subject to certain exceptions and exclusions. The carrying value of PPL Electric's property, plant and equipment was approximately $11.3 billion and $10.8 billion at December 31, 2021 and 2020. Includes LG&E's first mortgage bonds that are secured by the lien of the LG&E 2010 Mortgage Indenture which creates a lien, subject to certain exceptions and exclusions, on substantially all of LG&E's real and tangible personal property located in Kentucky and used or to be used in connection with the generation, transmission and distribution of electricity and the storage and distribution of natural gas. The aggregate carrying value of the property subject to the lien was $5.7 billion and $5.5 billion at December 31, 2021 and 2020. Includes KU's first mortgage bonds that are secured by the lien of the KU 2010 Mortgage Indenture which creates a lien, subject to certain exceptions and exclusions, on substantially all of KU's real and tangible personal property located in Kentucky and used or to be used in connection with the generation, transmission and distribution of electricity. The aggregate carrying value of the property subject to the lien was $6.9 billion and $6.7 billion at December 31, 2021 and 2020. (b) Includes PPL Electric's series of senior secured bonds that secure its obligations to make payments with respect to each series of Pollution Control Bonds that were issued by the LCIDA and the PEDFA on behalf of PPL Electric. These senior secured bonds were issued in the same principal amount, contain payment and redemption provisions that correspond to and bear the same interest rate as such Pollution Control Bonds. These senior secured bonds were issued under PPL Electric's 2001 Mortgage Indenture and are secured as noted in (a) above. This amount includes $224 million of which PPL Electric is allowed to convert the interest rate mode on the bonds from time to time to a commercial paper rate, daily rate, weekly rate, or term rate of at least one year and $90 million which is subject to mandatory redemption upon determination that the interest rate on the bonds would be included in the holders' gross income for federal tax purposes. Includes $250 million of notes that may be called on or after September 28, 2021 and $650 million of notes that may be called on or after June 24, 2022, at a redemption price equal to 100% of the principal amount of the bonds, plus accrued and unpaid interest to, but excluding, such redemption date. (c) Includes LG&E's and KU's series of first mortgage bonds that were issued to the respective trustees of tax-exempt revenue bonds to secure its respective obligations to make payments with respect to each series of bonds. The first mortgage bonds were issued in the same principal amounts, contain payment and redemption provisions that correspond to and bear the same interest rate as such tax-exempt revenue bonds. These first mortgage bonds were issued under the LG&E 2010 Mortgage Indenture and the KU 2010 Mortgage Indenture and are secured as noted in (a) above. The related tax-exempt revenue bonds were issued by various governmental entities, principally counties in Kentucky, on behalf of LG&E and KU. The related revenue bond documents allow LG&E and KU to convert the interest rate mode on the bonds from time to time to a commercial paper rate, daily rate, weekly rate, term rate of at least one year or, in some cases, an auction rate or a LIBOR index rate. At December 31, 2021, the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a term rate mode totaled $782 million for PPL, comprised of $473 million and $309 million for LG&E and KU. At December 31, 2021, the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a variable rate mode totaled $66 million and $33 million for LG&E and KU. These variable rate tax-exempt revenue bonds are subject to tender for purchase by LG&E and KU at the option of the holder and to mandatory tender for purchase by LG&E and KU upon the occurrence of certain events. (d) The table reflects principal maturities only, based on stated maturities or earlier put dates, and the weighted-average rates as of December 31, 2021.
Long-term Debt Maturities	The aggregate maturities of long-term debt, based on stated maturities or earlier put dates, for the periods 2022 through 2026 and thereafter are as follows: PPL PPL LG&E KU 2022 $ 474 $ 474 $ — $ — 2023 353 340 — 13 2024 650 650 — — 2025 550 — 300 250 2026 904 — 90 164 Thereafter 8,320 3,075 1,634 2,215 Total $ 11,251 $ 4,539 $ 2,024 $ 2,642

Acquisitions, Development and_2

Acquisitions, Development and Divestures (Tables)	12 Months Ended
	Dec. 31, 2021
Acquisitions, Development and Divestitures [Line Items]
Disposal Group, Including Discontinued Operation, Components of Gain (loss) on Sale	The following table summarizes the pre-tax loss recorded upon completion of the sale. Loss on sale for the year ended December 31, 2021 Sales proceeds, net of realized foreign currency hedge losses (a) $ 10,732 Unrealized foreign currency hedge losses recognized in 2020 125 Less: Costs to sell (b) 69 Less: Carrying value (c) 12,397 Loss on sale $ (1,609) (a) Includes the fixed and additional consideration of £7,881 million specified in the WPD SPA, converted at a spot rate of $1.4107 per GBP, offset by $386 million of realized foreign currency hedge losses to hedge the proceeds from the sale. (b) I ncludes bank advisory, legal and accounting fees to facilitate the transaction. (c) Represents the carrying value of the U.K. utility business at the time of sale and includes the realization of AOCI of $3.6 billion, which arose primarily from currency translation adjustments and defined benefit plans associated with the U.K. utility business.
Disposal Group, Including Discontinued Operation, Income Statement Line Items	Following are the components of discontinued operations in the Statements of Income for the years ended December 31: 2021 2020 2019 Operating Revenues $ 1,344 $ 2,133 $ 2,167 Operating Expenses 467 916 853 Other Income (Expense) - net 202 167 295 Interest Expense (a) 209 367 373 Income before income taxes 870 1,017 1,236 Loss on sale (1,609) — — Income Taxes 759 188 226 Income (Loss) from Discontinued Operations (net of income taxes) $ (1,498) $ 829 $ 1,010 (a) No interest from corporate level debt was allocated to discontinued operations.
Disposal Group, Including Discontinued Operation, Assets and Liabilities	The following major classes of assets and liabilities of the U.K. utility business were reclassified on PPL's Balance Sheet to "Current assets held for sale" and "Current liabilities held for sale" as of December 31, 2020: Held for Sale at December 31, 2020 Cash and cash equivalents $ 266 Accounts receivable and unbilled revenues 389 Price risk management assets 146 Property, plant and equipment, net (a) 14,392 Goodwill 2,558 Other intangibles 413 Pension benefit asset 682 Other assets 137 Total Assets $ 18,983 Short-term debt and long-term debt due within one year $ 994 Accounts payable 220 Customer deposits 217 Accrued interest 190 Long-term debt 7,938 Total deferred income taxes 1,032 Price risk management liabilities 137 Other deferred credits and liabilities 295 Total Liabilities $ 11,023 Net assets (b) $ 7,960 (a) Depreciation of fixed assets ceased upon classification as held for sale in the first quarter of 2021.

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2021
Leases [Line Items]
Lease, Cost [Table Text Block]	The following table provides the components of lease cost for the Registrants' operating leases for the years ended December 31: 2021 2020 2019 PPL Lease cost: Operating lease cost $ 24 $ 28 $ 30 Short-term lease cost 6 7 5 Total lease cost $ 30 $ 35 $ 35 LG&E Lease cost: Operating lease cost $ 6 $ 8 $ 12 Short-term lease cost 1 1 1 Total lease cost $ 7 $ 9 $ 13 KU Lease cost: Operating lease cost $ 10 $ 13 $ 13 Short-term lease cost 1 1 1 Total lease cost $ 11 $ 14 $ 14 The following table provides other key information related to the Registrants' operating leases at December 31: 2021 2020 2019 PPL Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 23 $ 24 $ 26 Right-of-use asset obtained in exchange for new operating lease liabilities 12 17 45 LG&E Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 6 $ 7 $ 9 Right-of-use asset obtained in exchange for new operating lease liabilities 4 6 5 KU Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 10 $ 11 $ 11 Right-of-use asset obtained in exchange for new operating lease liabilities 7 9 11
Lessee, Operating Lease, Liability, Maturity [Table Text Block]	The following table provides the total future minimum rental payments for operating leases, as well as a reconciliation of these undiscounted cash flows to the lease liabilities recognized on the Balance Sheets as of December 31, 2021. PPL LG&E KU 2022 $ 23 $ 6 $ 10 2023 20 5 8 2024 15 4 6 2025 8 3 4 2026 3 1 1 Thereafter 5 1 1 Total $ 74 $ 20 $ 30 Weighted-average discount rate 3.38% 3.48% 3.67% Weighted-average remaining lease term (in years) 4 4 4 Current lease liabilities (a) $ 22 $ 6 $ 9 Non-current lease liabilities (a) 47 12 17 Right-of-use assets (b) 62 15 24 (a) Current lease liabilities are included in " Other Current Liabilities Other deferred credits and noncurrent liabilities (b) Right-of-use assets are included in "Other noncurrent assets" on the Balance Sheets.
Lessor, Operating Lease, Payments to be Received, Maturity [Table Text Block]	for the years ended December 31: PPL LG&E KU Lease income recognized for the twelve months ended December 31, 2021 $ 11 $ 5 $ 5 Lease income recognized for the twelve months ended December 31, 2020 16 6 9 Lease income recognized for the twelve months ended December 31, 2019 14 5 8
Louisville Gas And Electric Co [Member]
Leases [Line Items]
Lease, Cost [Table Text Block]	The following table provides the components of lease cost for the Registrants' operating leases for the years ended December 31: 2021 2020 2019 PPL Lease cost: Operating lease cost $ 24 $ 28 $ 30 Short-term lease cost 6 7 5 Total lease cost $ 30 $ 35 $ 35 LG&E Lease cost: Operating lease cost $ 6 $ 8 $ 12 Short-term lease cost 1 1 1 Total lease cost $ 7 $ 9 $ 13 KU Lease cost: Operating lease cost $ 10 $ 13 $ 13 Short-term lease cost 1 1 1 Total lease cost $ 11 $ 14 $ 14 The following table provides other key information related to the Registrants' operating leases at December 31: 2021 2020 2019 PPL Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 23 $ 24 $ 26 Right-of-use asset obtained in exchange for new operating lease liabilities 12 17 45 LG&E Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 6 $ 7 $ 9 Right-of-use asset obtained in exchange for new operating lease liabilities 4 6 5 KU Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 10 $ 11 $ 11 Right-of-use asset obtained in exchange for new operating lease liabilities 7 9 11
Lessee, Operating Lease, Liability, Maturity [Table Text Block]	The following table provides the total future minimum rental payments for operating leases, as well as a reconciliation of these undiscounted cash flows to the lease liabilities recognized on the Balance Sheets as of December 31, 2021. PPL LG&E KU 2022 $ 23 $ 6 $ 10 2023 20 5 8 2024 15 4 6 2025 8 3 4 2026 3 1 1 Thereafter 5 1 1 Total $ 74 $ 20 $ 30 Weighted-average discount rate 3.38% 3.48% 3.67% Weighted-average remaining lease term (in years) 4 4 4 Current lease liabilities (a) $ 22 $ 6 $ 9 Non-current lease liabilities (a) 47 12 17 Right-of-use assets (b) 62 15 24 (a) Current lease liabilities are included in " Other Current Liabilities Other deferred credits and noncurrent liabilities (b) Right-of-use assets are included in "Other noncurrent assets" on the Balance Sheets.
Lessor, Operating Lease, Payments to be Received, Maturity [Table Text Block]	for the years ended December 31: PPL LG&E KU Lease income recognized for the twelve months ended December 31, 2021 $ 11 $ 5 $ 5 Lease income recognized for the twelve months ended December 31, 2020 16 6 9 Lease income recognized for the twelve months ended December 31, 2019 14 5 8
Kentucky Utilities Co [Member]
Leases [Line Items]
Lease, Cost [Table Text Block]	The following table provides the components of lease cost for the Registrants' operating leases for the years ended December 31: 2021 2020 2019 PPL Lease cost: Operating lease cost $ 24 $ 28 $ 30 Short-term lease cost 6 7 5 Total lease cost $ 30 $ 35 $ 35 LG&E Lease cost: Operating lease cost $ 6 $ 8 $ 12 Short-term lease cost 1 1 1 Total lease cost $ 7 $ 9 $ 13 KU Lease cost: Operating lease cost $ 10 $ 13 $ 13 Short-term lease cost 1 1 1 Total lease cost $ 11 $ 14 $ 14 The following table provides other key information related to the Registrants' operating leases at December 31: 2021 2020 2019 PPL Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 23 $ 24 $ 26 Right-of-use asset obtained in exchange for new operating lease liabilities 12 17 45 LG&E Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 6 $ 7 $ 9 Right-of-use asset obtained in exchange for new operating lease liabilities 4 6 5 KU Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 10 $ 11 $ 11 Right-of-use asset obtained in exchange for new operating lease liabilities 7 9 11
Lessee, Operating Lease, Liability, Maturity [Table Text Block]	The following table provides the total future minimum rental payments for operating leases, as well as a reconciliation of these undiscounted cash flows to the lease liabilities recognized on the Balance Sheets as of December 31, 2021. PPL LG&E KU 2022 $ 23 $ 6 $ 10 2023 20 5 8 2024 15 4 6 2025 8 3 4 2026 3 1 1 Thereafter 5 1 1 Total $ 74 $ 20 $ 30 Weighted-average discount rate 3.38% 3.48% 3.67% Weighted-average remaining lease term (in years) 4 4 4 Current lease liabilities (a) $ 22 $ 6 $ 9 Non-current lease liabilities (a) 47 12 17 Right-of-use assets (b) 62 15 24 (a) Current lease liabilities are included in " Other Current Liabilities Other deferred credits and noncurrent liabilities (b) Right-of-use assets are included in "Other noncurrent assets" on the Balance Sheets.
Lessor, Operating Lease, Payments to be Received, Maturity [Table Text Block]	for the years ended December 31: PPL LG&E KU Lease income recognized for the twelve months ended December 31, 2021 $ 11 $ 5 $ 5 Lease income recognized for the twelve months ended December 31, 2020 16 6 9 Lease income recognized for the twelve months ended December 31, 2019 14 5 8

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2021
Disclosure Of Compensation Related Costs Sharebased Payments [Line Items]
Stock-Based Compensation, Plan Award Limits	The following table details the award limits under each of the Plans. Total Plan Annual Grant Limit Annual Grant Annual Grant Limit Award PPL Common Stock Limit For awards For awards Plan (Shares) Each Calendar Year (Shares) shares (Shares) cash (in dollars) SIP 15,000,000 2,000,000 750,000 $ 15,000,000 ICPKE 14,199,796 2 % 3,000,000
Restricted Stock and Restricted Stock Units, Weighted Average Grant Date Fair Value	The weighted-average grant date fair value of restricted stock units granted was: 2021 2020 2019 PPL $ 28.00 $ 35.30 $ 31.95 PPL Electric 27.96 35.37 32.33
Restricted Stock and Restricted Stock Units, Activity Rollforward	Restricted stock unit activity for 2021 was: Restricted Weighted- PPL Nonvested, beginning of period 896,336 $ 32.56 Granted 458,610 28.00 Vested (303,890) 30.57 Forfeited (46,473) 30.23 Nonvested, end of period 1,004,583 31.19 PPL Electric Nonvested, beginning of period 210,720 $ 32.73 Transfer between registrants (92,596) 32.99 Granted 51,587 27.96 Vested (32,266) 29.98 Forfeited (6,158) 32.16 Nonvested, end of period 131,287 31.50
Restricted Stock and Restricted Stock Units, Total Fair Value Vested at Year End	The total fair value of restricted stock units vesting for the years ended December 31 was: 2021 2020 2019 PPL $ 8 $ 19 $ 13 PPL Electric 1 3 2
Performance Units, Valuation Assumptions	The weighted-average assumptions used in the model were: 2021 2020 2019 Expected stock volatility 27.81% 15.64% 17.57% Expected life 3 years 3 years 3 years
Performance Units, Weighted Average Grant Date Fair Value	The weighted-average grant date fair value of TSR performance units granted was: 2021 2020 2019 PPL $ 32.44 $ 37.63 $ 35.83 PPL Electric 32.92 38.64 35.68 The weighted-average grant date fair value of ROE performance units granted was: 2021 2020 2019 PPL $ 30.08 $ 34.95 $ 30.89 PPL Electric 29.39 35.59 30.76
Performance Units, Activity Rollforward	TSR performance unit activity for 2021 was: TSR Performance Units Weighted- PPL Nonvested, beginning of period 626,254 $ 36.98 Granted 306,009 32.44 Vested (53,340) 34.47 Forfeited (a) (245,150) 37.75 Nonvested, end of period 633,773 34.68 TSR Performance Units Weighted- PPL Electric Nonvested, beginning of period 61,807 $ 37.44 Transfer between registrants (53,663) 37.42 Granted 10,010 32.92 Forfeited (a) (2,800) 38.47 Nonvested, end of period 15,354 34.36 (a) Primarily related to the forfeiture of 2018 domestic performance units as performance during the period was below the minimum established performance threshold, which resulted in no payout. ROE performance unit activity for 2021 was: ROE Performance Unit Weighted- PPL Nonvested, beginning of period 728,664 $ 32.81 Granted 572,571 30.08 Vested (570,722) 32.02 Forfeited (8,160) 30.44 Nonvested, end of period 722,353 31.28 PPL Electric Nonvested, beginning of period 61,807 $ 33.01 Transfer between registrants (53,663) 33.00 Granted 12,895 29.39 Vested (5,685) 32.27 Nonvested, end of period 15,354 30.27
Share-based Compensation Arrangements by Share-based Payment Award, Performance-Based Units, Vested and Expected to Vest	The total fair value of ROE performance units vesting for the years ended December 31 was: 2021 2020 PPL $ 16 $ 8 PPL Electric — 1
Stock Options, Activity Rollforward	Stock option activity for 2021 was: Number Weighted Weighted- Aggregate PPL Outstanding at beginning of period 1,103,016 $ 26.22 Exercised (337,014) 25.42 Outstanding and exercisable at end of period 766,002 26.57 1 $ 3
Compensation Costs for Restricted Stock, Restricted Stock Units, Performance Units and Stock Options	Compensation expense for restricted stock, restricted stock units, performance units and stock options accounted for as equity awards, which for PPL Electric includes an allocation of PPL Services' expense, was: 2021 2020 2019 PPL $ 34 $ 28 $ 35 PPL Electric 11 10 12 The income tax benefit related to above compensation expense was as follows: 2021 2020 2019 PPL $ 10 $ 8 $ 10 PPL Electric 3 3 3
Unrecognized Compensation Cost, Nonvested Restricted Stock, Restricted Stock Units, Performance Units and Stock Option Awards	At December 31, 2021, unrecognized compensation expense related to nonvested stock awards was: Unrecognized Weighted- PPL $ 19 1.7 PPL Electric 2 1.8
PPL Electric Utilities Corp [Member]
Disclosure Of Compensation Related Costs Sharebased Payments [Line Items]
Stock-Based Compensation, Plan Award Limits	The following table details the award limits under each of the Plans. Total Plan Annual Grant Limit Annual Grant Annual Grant Limit Award PPL Common Stock Limit For awards For awards Plan (Shares) Each Calendar Year (Shares) shares (Shares) cash (in dollars) SIP 15,000,000 2,000,000 750,000 $ 15,000,000 ICPKE 14,199,796 2 % 3,000,000
Restricted Stock and Restricted Stock Units, Weighted Average Grant Date Fair Value	The weighted-average grant date fair value of restricted stock units granted was: 2021 2020 2019 PPL $ 28.00 $ 35.30 $ 31.95 PPL Electric 27.96 35.37 32.33
Restricted Stock and Restricted Stock Units, Activity Rollforward	Restricted stock unit activity for 2021 was: Restricted Weighted- PPL Nonvested, beginning of period 896,336 $ 32.56 Granted 458,610 28.00 Vested (303,890) 30.57 Forfeited (46,473) 30.23 Nonvested, end of period 1,004,583 31.19 PPL Electric Nonvested, beginning of period 210,720 $ 32.73 Transfer between registrants (92,596) 32.99 Granted 51,587 27.96 Vested (32,266) 29.98 Forfeited (6,158) 32.16 Nonvested, end of period 131,287 31.50
Restricted Stock and Restricted Stock Units, Total Fair Value Vested at Year End	The total fair value of restricted stock units vesting for the years ended December 31 was: 2021 2020 2019 PPL $ 8 $ 19 $ 13 PPL Electric 1 3 2
Performance Units, Valuation Assumptions	The weighted-average assumptions used in the model were: 2021 2020 2019 Expected stock volatility 27.81% 15.64% 17.57% Expected life 3 years 3 years 3 years
Performance Units, Weighted Average Grant Date Fair Value	The weighted-average grant date fair value of TSR performance units granted was: 2021 2020 2019 PPL $ 32.44 $ 37.63 $ 35.83 PPL Electric 32.92 38.64 35.68 The weighted-average grant date fair value of ROE performance units granted was: 2021 2020 2019 PPL $ 30.08 $ 34.95 $ 30.89 PPL Electric 29.39 35.59 30.76
Performance Units, Activity Rollforward	TSR performance unit activity for 2021 was: TSR Performance Units Weighted- PPL Nonvested, beginning of period 626,254 $ 36.98 Granted 306,009 32.44 Vested (53,340) 34.47 Forfeited (a) (245,150) 37.75 Nonvested, end of period 633,773 34.68 TSR Performance Units Weighted- PPL Electric Nonvested, beginning of period 61,807 $ 37.44 Transfer between registrants (53,663) 37.42 Granted 10,010 32.92 Forfeited (a) (2,800) 38.47 Nonvested, end of period 15,354 34.36 (a) Primarily related to the forfeiture of 2018 domestic performance units as performance during the period was below the minimum established performance threshold, which resulted in no payout. ROE performance unit activity for 2021 was: ROE Performance Unit Weighted- PPL Nonvested, beginning of period 728,664 $ 32.81 Granted 572,571 30.08 Vested (570,722) 32.02 Forfeited (8,160) 30.44 Nonvested, end of period 722,353 31.28 PPL Electric Nonvested, beginning of period 61,807 $ 33.01 Transfer between registrants (53,663) 33.00 Granted 12,895 29.39 Vested (5,685) 32.27 Nonvested, end of period 15,354 30.27
Share-based Compensation Arrangements by Share-based Payment Award, Performance-Based Units, Vested and Expected to Vest	The total fair value of ROE performance units vesting for the years ended December 31 was: 2021 2020 PPL $ 16 $ 8 PPL Electric — 1
Compensation Costs for Restricted Stock, Restricted Stock Units, Performance Units and Stock Options	Compensation expense for restricted stock, restricted stock units, performance units and stock options accounted for as equity awards, which for PPL Electric includes an allocation of PPL Services' expense, was: 2021 2020 2019 PPL $ 34 $ 28 $ 35 PPL Electric 11 10 12 The income tax benefit related to above compensation expense was as follows: 2021 2020 2019 PPL $ 10 $ 8 $ 10 PPL Electric 3 3 3
Unrecognized Compensation Cost, Nonvested Restricted Stock, Restricted Stock Units, Performance Units and Stock Option Awards	At December 31, 2021, unrecognized compensation expense related to nonvested stock awards was: Unrecognized Weighted- PPL $ 19 1.7 PPL Electric 2 1.8

Retirement and Postemployment_2

Retirement and Postemployment Benefits (Tables)	12 Months Ended
	Dec. 31, 2021
Defined Benefit Plan Disclosure [Line Items]
Schedule Of Net Periodic Defined Benefit Costs (Credits)	The following table provides the components of net periodic defined benefit costs (credits) for PPL's pension and other postretirement benefit plans for the years ended December 31. Pension Benefits Other Postretirement Benefits 2021 2020 2019 2021 2020 2019 Net periodic defined benefit costs (credits): Service cost $ 56 $ 56 $ 50 $ 6 $ 6 $ 6 Interest cost 121 146 164 16 19 22 Expected return on plan assets (255) (246) (245) (23) (21) (18) Amortization of: Prior service cost (credit) 8 9 8 1 1 (1) Actuarial (gain) loss 93 89 56 (1) — 1 Net periodic defined benefit costs (credits) prior to settlements and termination benefits 23 54 33 (1) 5 10 Settlements (a) 18 23 1 — — — Net periodic defined benefit costs (credits) $ 41 $ 77 $ 34 $ (1) $ 5 $ 10 Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: Settlement (18) (23) (1) — — — Net (gain) loss 42 (221) (121) (53) (6) (18) Prior service cost (credit) 3 1 2 — 5 — Amortization of: Prior service (cost) credit (8) (9) (8) (1) (1) 1 Actuarial gain (loss) (93) (89) (56) 1 — (1) Total recognized in OCI and regulatory assets/liabilities (74) (341) (184) (53) (2) (18) Total recognized in net periodic defined benefit costs, OCI and regulatory assets/liabilities $ (33) $ (264) $ (150) $ (54) $ 3 $ (8) (a) 2021 and 2020 include a settlement charge for a retired PPL executive as well as a settlement charge incurred as a result of the amount of lump sum payment distributions from the LKE qualified pension plan. In accordance with existing regulatory accounting treatment, LG&E and KU have primarily maintained the settlement charge in regulatory assets to be amortized in accordance with existing regulatory practice. The portion of the settlement attributed to LKE's operations outside of the jurisdiction of the KPSC has been charged to expense.
Schedule of Amounts Recognized in Other Comprehensive Income and Regulatory Assets and Liabilities	For PPL's pension and postretirement benefits, the amounts recognized in OCI and regulatory assets/liabilities for the years ended December 31 were as follows: Pension Benefits Other Postretirement Benefits 2021 2020 2019 2021 2020 2019 OCI $ (70) $ (428) $ (194) $ (42) $ (12) $ (13) Regulatory assets/liabilities (4) 87 10 (11) 10 (5) Total recognized in OCI and $ (74) $ (341) $ (184) $ (53) $ (2) $ (18)
Schedule of Net Periodic Defined Benefit Costs Included in Income Statement	The following net periodic defined benefit costs (credits) were charged to expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts. Pension Benefits Other Postretirement Benefits 2021 2020 2019 2021 2020 2019 PPL $ 12 $ 40 $ 18 $ (1) $ 4 $ 8 PPL Electric (a) (9) (2) (4) (1) 2 4 LG&E (a) (b) (1) 4 3 2 2 2 KU (a) (b) (3) 1 (1) — — — (a) PPL Electric and KU do not directly sponsor any defined benefit plans. PPL Electric and KU were allocated these costs of defined benefit plans sponsored by PPL Services (for PPL Electric) and by LKE (for KU), based on their participation in those plans, which management believes are reasonable. KU is also allocated costs of defined benefit plans from LKS for defined benefit plans sponsored by LKE. Effective January 1, 2020, the LKE and LG&E defined benefit pension plans were merged into a combined defined benefit pension plan, sponsored by LKE, therefore LG&E does not directly sponsor any defined benefit plans. LG&E and KU were allocated these costs of defined benefit plans sponsored by LKE, based on their participation in those plans, which management believes are reasonable. LG&E and KU are also allocated costs of defined benefit plans from LKS for defined benefit plans sponsored by LKE. See Note 15 for additional information on costs allocated to LG&E and KU from LKS.
Schedule of Funded Status of Defined Benefit Plans	The funded status of PPL's plans at December 31 was as follows: Pension Benefits Other Postretirement Benefits 2021 2020 2021 2020 Change in Benefit Obligation Benefit Obligation, beginning of period $ 4,251 $ 4,146 $ 573 $ 557 Service cost 56 56 6 6 Interest cost 121 146 16 19 Participant contributions — — 14 15 Plan amendments 2 2 — 5 Actuarial (gain) loss (88) 256 (50) 29 Settlements (106) (114) — — Gross benefits paid (247) (241) (55) (58) Benefit Obligation, end of period 3,989 4,251 504 573 Change in Plan Assets Plan assets at fair value, beginning of period 4,068 3,585 367 340 Actual return on plan assets 125 723 25 56 Employer contributions 47 115 18 18 Participant contributions — — 11 11 Settlements (106) (114) — — Gross benefits paid (247) (241) (54) (58) Plan assets at fair value, end of period 3,887 4,068 367 367 Funded Status, end of period $ (102) $ (183) $ (137) $ (206) Amounts recognized in the Balance Sheets consist of: Noncurrent asset $ 91 $ 24 $ — $ — Current liability (10) (18) (15) (22) Noncurrent liability (183) (189) (122) (184) Net amount recognized, end of period $ (102) $ (183) $ (137) $ (206) Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: Prior service cost (credit) $ 22 $ 27 $ 12 $ 14 Net actuarial (gain) loss 626 695 (51) — Total $ 648 $ 722 $ (39) $ 14 Total accumulated benefit obligation $ 3,786 $ 4,024 For PPL's pension and other postretirement benefit plans, the amounts recognized in AOCI and regulatory assets/liabilities at December 31 were as follows: Pension Benefits Other Postretirement Benefits 2021 2020 2021 2020 AOCI $ 239 $ 270 $ (2) $ 10 Regulatory assets/liabilities 409 452 (37) 4 Total $ 648 $ 722 $ (39) $ 14
Schedule of Projected or Accumulated Benefit Obligations In Excess of Plan Assets	The following tables provide information on pension plans where the projected benefit obligation (PBO) or accumulated benefit obligation (ABO) exceed the fair value of plan assets: PBO in excess of plan assets 2021 2020 Projected benefit obligation $ 193 $ 1,875 Fair value of plan assets — 1,668 ABO in excess of plan assets 2021 2020 Accumulated benefit obligation $ 177 $ 184 Fair value of plan assets — —
Schedules of Asset Allocation of U.S. Pension Trusts Assets	The asset allocation for the trust and the target allocation by portfolio at December 31 are as follows: Percentage of trust assets 2021 2021 2020 Target Asset Growth Portfolio 55 % 56 % 55 % Equity securities 32 % 34 % Debt securities (a) 13 % 13 % Alternative investments 10 % 9 % Immunizing Portfolio 43 % 43 % 43 % Debt securities (a) 35 % 33 % Derivatives 8 % 10 % Liquidity Portfolio 2 % 1 % 2 % Total 100 % 100 % 100 % (a) Includes commingled debt funds, which PPL treats as debt securities for asset allocation purposes.
Schedule of Fair Value of Financial Assets for U.S. Pension Plan Assets	The fair value of net assets in the Master Trust by asset class and level within the fair value hierarchy was: December 31, 2021 December 31, 2020 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Services Corporation Master Trust Cash and cash equivalents $ 266 $ 266 $ — $ — $ 300 $ 300 $ — $ — Equity securities: U.S. Equity 41 41 — — 60 60 — — U.S. Equity fund measured at NAV (a) 754 — — — 742 — — — International equity fund at NAV (a) 511 — — — 566 — — — Commingled debt measured at NAV (a) 677 — — — 712 — — — December 31, 2021 December 31, 2020 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Debt securities: U.S. Treasury and U.S. government sponsored 281 280 1 — 336 335 1 — Corporate 1,039 — 1,019 20 1,045 — 1,030 15 Other 14 — 14 — 13 — 13 — Alternative investments: Real estate measured at NAV (a) 69 — — — 76 — — — Private equity measured at NAV (a) 94 — — — 68 — — — Hedge funds measured at NAV (a) 236 — — — 223 — — — Limited Partnerships at NAV (a) — — — — 6 — — — Derivatives 35 — 35 — (37) — (37) — PPL Services Corporation Master Trust assets, at 4,017 $ 587 $ 1,069 $ 20 4,110 $ 695 $ 1,007 $ 15 Receivables and payables, net (b) 25 116 401(h) accounts restricted for other (155) (158) Total PPL Services Corporation Master Trust $ 3,887 $ 4,068 (a) In accordance with accounting guidance certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position. (b) Receivables and payables, net represents amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received.
Reconciliation of U.S. Pension Trust Assets Classified as Level 3 Included in Earnings	A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2021 is as follows: Corporate Total Balance at beginning of period $ 15 $ 15 Purchases, sales and settlements 5 5 Balance at end of period $ 20 $ 20 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2020 is as follows: Corporate Insurance Total Balance at beginning of period $ 20 $ 4 $ 24 Purchases, sales and settlements (5) (4) (9) Balance at end of period $ 15 $ — $ 15
Schedules of Target Allocation of U.S. Other Postretirement Benefit Plans VEBA Trust	The asset allocation for the PPL VEBA trusts and the target allocation, by asset class, at December 31 are detailed below. Percentage of plan assets Target Asset 2021 2020 2021 Asset Class U.S. Equity securities 45 % 42 % 45 % Debt securities (a) 52 % 55 % 50 % Cash and cash equivalents (b) 3 % 3 % 5 % Total 100 % 100 % 100 % (a) Includes commingled debt funds and debt securities. (b) Includes money market funds.
Schedule of Fair Value of Financial Assets for U.S. Postretirement Benefits	The fair value of assets in the other postretirement benefit plans by asset class and level within the fair value hierarchy was: December 31, 2021 December 31, 2020 Fair Value Measurement Using Fair Value Measurement Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Money market funds $ 6 $ 6 $ — $ — $ 5 $ 5 $ — $ — U.S. Equity securities: Large-cap equity fund measure at NAV (a) 96 — — — 89 — — — Commingled debt fund measured at NAV (a) 75 — — — 77 — — — Debt securities: Corporate bonds 38 — 38 — 37 — 37 — U.S. Treasury and U.S. government sponsored — — — — 2 — 2 — Total VEBA trust assets, at fair value 215 $ 6 $ 38 $ — 210 $ 5 $ 39 $ — Receivables and payables, net (b) (3) (1) 401(h) account assets 155 158 Total other postretirement benefit plan assets $ 367 $ 367 (a) In accordance with accounting guidance certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position. (b) Receivables and payables represent amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received.
Schedule of Expected Cash Flows - U.S. Defined Benefit Plans - Expected Payments and Related Federal Subsidy	The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid by the plans and the following federal subsidy payments are expected to be received by PPL. Other Postretirement Pension Benefit Expected 2022 $ 207 $ 44 $ 1 2023 207 42 — 2024 204 41 — 2025 204 40 — 2026 202 38 — 2027-2030 946 176 1
Expected Employer Contributions to U.S. Savings Plans	Substantially all employees of PPL's subsidiaries are eligible to participate in deferred savings plans (401(k)s). Employer contributions to the plans were: 2021 2020 2019 PPL $ 29 $ 29 $ 30 PPL Electric 5 6 6 LG&E 7 6 6 KU 5 5 5
LKE [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan Assumptions and Impact of One Point Change on Postretirement Plans	The following weighted-average assumptions were used in the valuation of the benefit obligations at December 31. Pension Benefits Other Postretirement Benefits 2021 2020 2021 2020 PPL Discount rate 3.15 % 2.92 % 3.13 % 2.84 % Rate of compensation increase 3.76 % 3.76 % 3.77 % 3.75 % The following weighted-average assumptions were used to determine the net periodic defined benefit costs for the years ended December 31. Pension Benefits Other Postretirement Benefits 2021 2020 2019 2021 2020 2019 PPL Discount rate 2.92 % 3.64 % 4.35 % 2.84 % 3.60 % 4.31 % Rate of compensation increase 3.76 % 3.79 % 3.79 % 3.75 % 3.76 % 3.76 % Expected return on plan assets 7.25 % 7.25 % 7.25 % 6.48 % 6.44 % 6.46 % LG&E Discount rate — % — % 4.33 % Expected return on plan assets (a) — % — % 7.25 % (a) The expected long-term rates of return for pension and other postretirement benefits are based on management's projections using a best-estimate of expected returns, volatilities and correlations for each asset class. Each plan's specific current and expected asset allocations are also considered in developing a reasonable return assumption. (PPL) The following table provides the assumed health care cost trend rates for the years ended December 31: 2021 2020 2019 PPL Health care cost trend rate assumed for next year – obligations 6.25 % 6.50 % 6.60 % – cost 6.50 % 6.60 % 6.60 % Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) – obligations 5.00 % 5.00 % 5.00 % – cost 5.00 % 5.00 % 5.00 % Year that the rate reaches the ultimate trend rate – obligations 2027 2027 2024 – cost 2027 2024 2023
Schedules of Asset Allocation of U.S. Pension Trusts Assets	The asset allocation for the trust and the target allocation by portfolio at December 31 are as follows: Percentage of trust assets 2021 2021 2020 Target Asset Growth Portfolio 55 % 56 % 55 % Equity securities 32 % 34 % Debt securities (a) 13 % 13 % Alternative investments 10 % 9 % Immunizing Portfolio 43 % 43 % 43 % Debt securities (a) 35 % 33 % Derivatives 8 % 10 % Liquidity Portfolio 2 % 1 % 2 % Total 100 % 100 % 100 % (a) Includes commingled debt funds, which PPL treats as debt securities for asset allocation purposes.
Schedule of Fair Value of Financial Assets for U.S. Pension Plan Assets	The fair value of net assets in the Master Trust by asset class and level within the fair value hierarchy was: December 31, 2021 December 31, 2020 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Services Corporation Master Trust Cash and cash equivalents $ 266 $ 266 $ — $ — $ 300 $ 300 $ — $ — Equity securities: U.S. Equity 41 41 — — 60 60 — — U.S. Equity fund measured at NAV (a) 754 — — — 742 — — — International equity fund at NAV (a) 511 — — — 566 — — — Commingled debt measured at NAV (a) 677 — — — 712 — — — December 31, 2021 December 31, 2020 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Debt securities: U.S. Treasury and U.S. government sponsored 281 280 1 — 336 335 1 — Corporate 1,039 — 1,019 20 1,045 — 1,030 15 Other 14 — 14 — 13 — 13 — Alternative investments: Real estate measured at NAV (a) 69 — — — 76 — — — Private equity measured at NAV (a) 94 — — — 68 — — — Hedge funds measured at NAV (a) 236 — — — 223 — — — Limited Partnerships at NAV (a) — — — — 6 — — — Derivatives 35 — 35 — (37) — (37) — PPL Services Corporation Master Trust assets, at 4,017 $ 587 $ 1,069 $ 20 4,110 $ 695 $ 1,007 $ 15 Receivables and payables, net (b) 25 116 401(h) accounts restricted for other (155) (158) Total PPL Services Corporation Master Trust $ 3,887 $ 4,068 (a) In accordance with accounting guidance certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position. (b) Receivables and payables, net represents amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received.
Reconciliation of U.S. Pension Trust Assets Classified as Level 3 Included in Earnings	A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2021 is as follows: Corporate Total Balance at beginning of period $ 15 $ 15 Purchases, sales and settlements 5 5 Balance at end of period $ 20 $ 20 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2020 is as follows: Corporate Insurance Total Balance at beginning of period $ 20 $ 4 $ 24 Purchases, sales and settlements (5) (4) (9) Balance at end of period $ 15 $ — $ 15
PPL Electric Utilities Corp [Member]
Defined Benefit Plan Disclosure [Line Items]
Schedule of Funded Status of Defined Benefit Plans	Allocations to PPL Electric resulted in assets/(liabilities) at December 31 as follows: 2021 2020 Pension $ 42 $ 4 Other postretirement benefits (78) (99)
Louisville Gas And Electric Co [Member]
Defined Benefit Plan Disclosure [Line Items]
Schedule Of Net Periodic Defined Benefit Costs (Credits)	The following table provides the components of net periodic defined benefit costs for LG&E's pension benefit plan for the year ended December 31. Pension Benefits 2019 (a) Net periodic defined benefit costs (credits): Service cost $ 1 Interest cost 11 Expected return on plan assets (21) Amortization of: Prior service cost (credit) 5 Actuarial loss (b) 9 Net periodic defined benefit costs (credits) (c) $ 5 Other Changes in Plan Assets and Benefit Obligations Net (gain) loss $ (19) Amortization of: Prior service credit (5) Actuarial gain (9) Total recognized in regulatory assets/liabilities (33) Total recognized in net periodic defined benefit costs and regulatory assets $ (28) (a) The pension plans sponsored by LKE and LG&E were merged effective January 1, 2020 into the LG&E and KU Pension Plan, sponsored by LKE. (b) As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, the difference between actuarial (gain)/loss calculated in accordance with LG&E's pension accounting policy and actuarial (gain)/loss calculated using a 15 year amortization period was $3 million in 2019. (c) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, settlement charges of $5 million in 2019 was incurred. In accordance with existing regulatory accounting treatment, LG&E has maintained the settlement charge in regulatory assets. The amount will be amortized in accordance with existing regulatory practice.
Defined Benefit Plan Assumptions and Impact of One Point Change on Postretirement Plans	The following weighted-average assumptions were used in the valuation of the benefit obligations at December 31. Pension Benefits Other Postretirement Benefits 2021 2020 2021 2020 PPL Discount rate 3.15 % 2.92 % 3.13 % 2.84 % Rate of compensation increase 3.76 % 3.76 % 3.77 % 3.75 % The following weighted-average assumptions were used to determine the net periodic defined benefit costs for the years ended December 31. Pension Benefits Other Postretirement Benefits 2021 2020 2019 2021 2020 2019 PPL Discount rate 2.92 % 3.64 % 4.35 % 2.84 % 3.60 % 4.31 % Rate of compensation increase 3.76 % 3.79 % 3.79 % 3.75 % 3.76 % 3.76 % Expected return on plan assets 7.25 % 7.25 % 7.25 % 6.48 % 6.44 % 6.46 % LG&E Discount rate — % — % 4.33 % Expected return on plan assets (a) — % — % 7.25 % (a) The expected long-term rates of return for pension and other postretirement benefits are based on management's projections using a best-estimate of expected returns, volatilities and correlations for each asset class. Each plan's specific current and expected asset allocations are also considered in developing a reasonable return assumption.
Schedule of Funded Status of Defined Benefit Plans	Allocations to LG&E resulted in assets/(liabilities) at December 31 as follows: 2021 2020 Pension $ 85 $ 78 Other postretirement benefits (51) (68)
Kentucky Utilities Co [Member]
Defined Benefit Plan Disclosure [Line Items]
Schedule of Funded Status of Defined Benefit Plans	Allocations to KU resulted in assets/(liabilities) at December 31 as follows. 2021 2020 Pension $ 75 $ 62 Other postretirement benefits (6) (16)

Jointly Owned Utility Facilitie

Jointly Owned Utility Facilities (Tables)	12 Months Ended
	Dec. 31, 2021
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2021 and 2020, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL December 31, 2021 Trimble County Unit 1 75.00 % $ 457 $ 79 $ — Trimble County Unit 2 75.00 % 1,360 247 121 December 31, 2020 Trimble County Unit 1 75.00 % $ 440 $ 64 $ 2 Trimble County Unit 2 75.00 % 1,340 227 106 Ownership Electric Plant Accumulated Construction LG&E December 31, 2021 E.W. Brown Units 6-7 38.00 % $ 53 $ 24 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 25 — Trimble County Unit 1 75.00 % 457 79 — Trimble County Unit 2 14.25 % 379 57 64 Trimble County Units 5-6 29.00 % 36 15 — Trimble County Units 7-10 37.00 % 81 34 — Cane Run Unit 7 22.00 % 125 19 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 2 — — December 31, 2020 E.W. Brown Units 6-7 38.00 % $ 46 $ 22 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 22 — Trimble County Unit 1 75.00 % 440 64 2 Trimble County Unit 2 14.25 % 370 51 54 Trimble County Units 5-6 29.00 % 33 14 1 Trimble County Units 7-10 37.00 % 77 31 1 Cane Run Unit 7 22.00 % 123 15 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 2 — — KU December 31, 2021 E.W. Brown Units 6-7 62.00 % $ 88 $ 40 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 22 — Trimble County Unit 2 60.75 % 981 190 57 Trimble County Units 5-6 71.00 % 84 36 — Trimble County Units 7-10 63.00 % 133 57 — Cane Run Unit 7 78.00 % 444 70 — E.W. Brown Solar Unit 61.00 % 16 4 — Solar Share 56.00 % 3 — — December 31, 2020 E.W. Brown Units 6-7 62.00 % $ 76 $ 37 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 20 — Trimble County Unit 2 60.75 % 970 176 52 Trimble County Units 5-6 71.00 % 77 33 4 Trimble County Units 7-10 63.00 % 129 53 2 Cane Run Unit 7 78.00 % 443 57 2 E.W. Brown Solar Unit 61.00 % 16 3 — Solar Share 56.00 % 2 — —
Louisville Gas And Electric Co [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2021 and 2020, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL December 31, 2021 Trimble County Unit 1 75.00 % $ 457 $ 79 $ — Trimble County Unit 2 75.00 % 1,360 247 121 December 31, 2020 Trimble County Unit 1 75.00 % $ 440 $ 64 $ 2 Trimble County Unit 2 75.00 % 1,340 227 106 Ownership Electric Plant Accumulated Construction LG&E December 31, 2021 E.W. Brown Units 6-7 38.00 % $ 53 $ 24 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 25 — Trimble County Unit 1 75.00 % 457 79 — Trimble County Unit 2 14.25 % 379 57 64 Trimble County Units 5-6 29.00 % 36 15 — Trimble County Units 7-10 37.00 % 81 34 — Cane Run Unit 7 22.00 % 125 19 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 2 — — December 31, 2020 E.W. Brown Units 6-7 38.00 % $ 46 $ 22 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 22 — Trimble County Unit 1 75.00 % 440 64 2 Trimble County Unit 2 14.25 % 370 51 54 Trimble County Units 5-6 29.00 % 33 14 1 Trimble County Units 7-10 37.00 % 77 31 1 Cane Run Unit 7 22.00 % 123 15 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 2 — — KU December 31, 2021 E.W. Brown Units 6-7 62.00 % $ 88 $ 40 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 22 — Trimble County Unit 2 60.75 % 981 190 57 Trimble County Units 5-6 71.00 % 84 36 — Trimble County Units 7-10 63.00 % 133 57 — Cane Run Unit 7 78.00 % 444 70 — E.W. Brown Solar Unit 61.00 % 16 4 — Solar Share 56.00 % 3 — — December 31, 2020 E.W. Brown Units 6-7 62.00 % $ 76 $ 37 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 20 — Trimble County Unit 2 60.75 % 970 176 52 Trimble County Units 5-6 71.00 % 77 33 4 Trimble County Units 7-10 63.00 % 129 53 2 Cane Run Unit 7 78.00 % 443 57 2 E.W. Brown Solar Unit 61.00 % 16 3 — Solar Share 56.00 % 2 — —
Kentucky Utilities Co [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2021 and 2020, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL December 31, 2021 Trimble County Unit 1 75.00 % $ 457 $ 79 $ — Trimble County Unit 2 75.00 % 1,360 247 121 December 31, 2020 Trimble County Unit 1 75.00 % $ 440 $ 64 $ 2 Trimble County Unit 2 75.00 % 1,340 227 106 Ownership Electric Plant Accumulated Construction LG&E December 31, 2021 E.W. Brown Units 6-7 38.00 % $ 53 $ 24 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 25 — Trimble County Unit 1 75.00 % 457 79 — Trimble County Unit 2 14.25 % 379 57 64 Trimble County Units 5-6 29.00 % 36 15 — Trimble County Units 7-10 37.00 % 81 34 — Cane Run Unit 7 22.00 % 125 19 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 2 — — December 31, 2020 E.W. Brown Units 6-7 38.00 % $ 46 $ 22 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 22 — Trimble County Unit 1 75.00 % 440 64 2 Trimble County Unit 2 14.25 % 370 51 54 Trimble County Units 5-6 29.00 % 33 14 1 Trimble County Units 7-10 37.00 % 77 31 1 Cane Run Unit 7 22.00 % 123 15 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 2 — — KU December 31, 2021 E.W. Brown Units 6-7 62.00 % $ 88 $ 40 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 22 — Trimble County Unit 2 60.75 % 981 190 57 Trimble County Units 5-6 71.00 % 84 36 — Trimble County Units 7-10 63.00 % 133 57 — Cane Run Unit 7 78.00 % 444 70 — E.W. Brown Solar Unit 61.00 % 16 4 — Solar Share 56.00 % 3 — — December 31, 2020 E.W. Brown Units 6-7 62.00 % $ 76 $ 37 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 20 — Trimble County Unit 2 60.75 % 970 176 52 Trimble County Units 5-6 71.00 % 77 33 4 Trimble County Units 7-10 63.00 % 129 53 2 Cane Run Unit 7 78.00 % 443 57 2 E.W. Brown Solar Unit 61.00 % 16 3 — Solar Share 56.00 % 2 — —

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2021
Commitments And Contingencies [Line Items]
Unrecorded Unconditional Purchase Obligations	LG&E and KU enter into purchase contracts to supply the coal and natural gas requirements for generation facilities and LG&E's retail natural gas supply operations. These contracts include the following commitments: Contract Type Maximum Maturity Natural Gas Fuel 2024 Natural Gas Retail Supply 2023 Coal 2026 Coal Transportation and Fleeting Services 2027 Natural Gas Transportation 2026 LG&E KU Total 2022 $ 23 $ 10 $ 33 2023 23 10 33 2024 22 10 32 2025 22 10 32 2026 22 10 32 Thereafter 218 96 314 Total $ 330 $ 146 $ 476 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2021 2020 2019 LG&E $ 13 $ 12 $ 15 KU 6 6 7 Total $ 19 $ 18 $ 22
Guarantees	The table below details guarantees provided as of December 31, 2021. Exposure at December 31, 2021 Expiration PPL Indemnifications related to the sale of the U.K. utility business (a) Indemnifications related to certain tax liabilities related to the sale of the U.K. utility business £ 50 (b) 2028 LG&E and KU LG&E and KU obligation of shortfall related to OVEC (c) (a) PPL WPD Limited agreed to provide a standard indemnity regarding “leakage” amounts, which included amounts taken out of the sold assets through dividends, return of capital, bonuses or similar method, received or waived by WPD (or its affiliates defined as members of the Sellers Group in the SPA) during the period from April 1, 2020 through June 14, 2021, except such amounts permitted under the WPD SPA. The amount of the cap on this indemnity was £7,881 million, the amount paid to PPL WPD Limited at closing. This indemnification expired in December 2021 and no claims have been made. (b) PPL WPD Limited entered into a Tax Deed dated June 9, 2021 in which it agreed to a tax indemnity regarding certain potential tax liabilities of the entities sold with respect to periods prior to the completion of the sale, subject to customary exclusions and limitations. Because National Grid Holdings One plc, the buyer, agreed to purchase indemnity insurance, the amount of the cap on the indemnity for these liabilities is £1, except with respect to certain surrenders of tax losses, for which the amount of the cap on the indemnity is £50 million. (c) Pursuant to the OVEC power purchase contract, LG&E and KU are obligated to pay for their share of OVEC's excess debt service, post-retirement and decommissioning costs, as well as any shortfall from amounts included within a demand charge designed and expected to cover these costs over the term of the contract. PPL's proportionate share of OVEC's outstanding debt was $92 million at December 31, 2021, consisting of LG&E's share of $64 million and KU's share of $28 million. The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchase Commitments" above for additional information on the OVEC power purchase contract. In March 2018, a sponsor with a 4.85% pro-rata share of OVEC obligations filed for bankruptcy under Chapter 11 and, in August 2018, received a rejection order for the OVEC power purchase contract in the bankruptcy proceeding. OVEC and other entities challenged the contract rejection, the bankruptcy plan confirmation and regulatory aspects of the plan in various forums. In May 2020, OVEC and the relevant sponsor announced a settlement resolving all disputed matters in the bankruptcy and other proceedings, including providing that the sponsor will withdraw its request to reject the power purchase agreement. The settlement was implemented in July 2020.
Louisville Gas And Electric Co [Member]
Commitments And Contingencies [Line Items]
Unrecorded Unconditional Purchase Obligations	LG&E and KU enter into purchase contracts to supply the coal and natural gas requirements for generation facilities and LG&E's retail natural gas supply operations. These contracts include the following commitments: Contract Type Maximum Maturity Natural Gas Fuel 2024 Natural Gas Retail Supply 2023 Coal 2026 Coal Transportation and Fleeting Services 2027 Natural Gas Transportation 2026 LG&E KU Total 2022 $ 23 $ 10 $ 33 2023 23 10 33 2024 22 10 32 2025 22 10 32 2026 22 10 32 Thereafter 218 96 314 Total $ 330 $ 146 $ 476 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2021 2020 2019 LG&E $ 13 $ 12 $ 15 KU 6 6 7 Total $ 19 $ 18 $ 22
Kentucky Utilities Co [Member]
Commitments And Contingencies [Line Items]
Unrecorded Unconditional Purchase Obligations	LG&E and KU enter into purchase contracts to supply the coal and natural gas requirements for generation facilities and LG&E's retail natural gas supply operations. These contracts include the following commitments: Contract Type Maximum Maturity Natural Gas Fuel 2024 Natural Gas Retail Supply 2023 Coal 2026 Coal Transportation and Fleeting Services 2027 Natural Gas Transportation 2026 LG&E KU Total 2022 $ 23 $ 10 $ 33 2023 23 10 33 2024 22 10 32 2025 22 10 32 2026 22 10 32 Thereafter 218 96 314 Total $ 330 $ 146 $ 476 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2021 2020 2019 LG&E $ 13 $ 12 $ 15 KU 6 6 7 Total $ 19 $ 18 $ 22

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2021
PPL Electric Utilities Corp [Member]
Related Party Transactions [Line Items]
Intercompany Support Cost Allocations	PPL Services, PPL EU Services and LKS charged the following amounts for the years ended December 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable. 2021 2020 2019 PPL Electric from PPL Services $ 54 $ 50 $ 59 PPL Electric from PPL EU Services 222 176 152 LG&E from LKS 169 170 160 KU from LKS 179 180 178
Louisville Gas And Electric Co [Member]
Related Party Transactions [Line Items]
Intercompany Support Cost Allocations	PPL Services, PPL EU Services and LKS charged the following amounts for the years ended December 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable. 2021 2020 2019 PPL Electric from PPL Services $ 54 $ 50 $ 59 PPL Electric from PPL EU Services 222 176 152 LG&E from LKS 169 170 160 KU from LKS 179 180 178
Kentucky Utilities Co [Member]
Related Party Transactions [Line Items]
Intercompany Support Cost Allocations	PPL Services, PPL EU Services and LKS charged the following amounts for the years ended December 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable. 2021 2020 2019 PPL Electric from PPL Services $ 54 $ 50 $ 59 PPL Electric from PPL EU Services 222 176 152 LG&E from LKS 169 170 160 KU from LKS 179 180 178

Other Income (Expense) - net (T

Other Income (Expense) - net (Tables)	12 Months Ended
	Dec. 31, 2021
Other Income (Expense) Net [Line Items]
Other Income (Expense) - net	The components of "Other Income (Expense) - net" for the years ended December 31, were: 2021 2020 2019 Other Income Defined benefit plans - non-service credits (Note 12) $ 21 $ (2) $ 8 Interest income 12 9 15 AFUDC - equity component 18 20 23 Miscellaneous 10 7 7 Total Other Income 61 34 53 Other Expense Charitable contributions 14 3 17 Miscellaneous 32 29 22 Total Other Expense 46 32 39 Other Income (Expense) - net $ 15 $ 2 $ 14
PPL Electric Utilities Corp [Member]
Other Income (Expense) Net [Line Items]
Other Income (Expense) - net	(PPL Electric) The components of "Other Income (Expense) - net" for the years ended December 31, were: 2021 2020 2019 Other Income Defined benefit plans - non-service credits (Note 12) $ 9 $ 4 $ 4 Interest income — 2 2 AFUDC - equity component 18 19 23 Total Other Income 27 25 29 Other Expense Charitable contributions 3 3 3 Miscellaneous 3 4 1 Total Other Expense 6 7 4 Other Income (Expense) - net $ 21 $ 18 $ 25

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2021
Fair Value [Line Items]
Fair Value of Assets and Liabilities Measured on Recurring Basis	The assets and liabilities measured at fair value were: December 31, 2021 December 31, 2020 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 3,571 $ 3,571 $ — $ — $ 442 $ 442 $ — $ — Restricted cash and cash equivalents (a) 1 1 — — 1 1 — — Special use funds (a): Money market fund 2 2 — — — — — — Commingled debt fund measured at NAV (b) 22 — — — 26 — — — Commingled equity fund measured at NAV (b) 21 — — — 25 — — — Total special use funds 45 2 — — 51 — — — Total assets $ 3,617 $ 3,574 $ — $ — $ 494 $ 443 $ — $ — Liabilities Price risk management liabilities (c): Interest rate swaps $ 18 $ — $ 18 $ — $ 23 $ — $ 23 $ — Total price risk management liabilities $ 18 $ — $ 18 $ — $ 23 $ — $ 23 $ — PPL Electric Assets Cash and cash equivalents $ 21 $ 21 $ — $ — $ 40 $ 40 $ — $ — Total assets $ 21 $ 21 $ — $ — $ 40 $ 40 $ — $ — LG&E Assets Cash and cash equivalents $ 9 $ 9 $ — $ — $ 7 $ 7 $ — $ — Total assets $ 9 $ 9 $ — $ — $ 7 $ 7 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 18 $ — $ 18 $ — $ 23 $ — $ 23 $ — Total price risk management liabilities $ 18 $ — $ 18 $ — $ 23 $ — $ 23 $ — KU Assets Cash and cash equivalents $ 13 $ 13 $ — $ — $ 22 $ 22 $ — $ — Total assets $ 13 $ 13 $ — $ — $ 22 $ 22 $ — $ — (a) Current portion is included in "Other current assets" and long-term portion is included in "Other noncurrent assets" on the Balance Sheets. (b) In accordance with accounting guidance, certain investments that are measured at fair value using net asset value per share (NAV), or its equivalent, have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position. (c) Current portion is included in "Other current liabilities" and noncurrent portion is included in "Other deferred credits and noncurrent liabilities" on the Balance Sheets.
Fair Value of Financial Instruments Not Recorded at Fair Value - Other	The carrying amounts of long-term debt on the Balance Sheets and their estimated fair values are set forth below. December 31, 2021 December 31, 2020 Carrying Fair Value Carrying Fair Value PPL $ 11,140 $ 12,955 $ 14,689 $ 17,774 PPL Electric 4,484 5,272 4,236 5,338 LG&E 2,006 2,363 2,007 2,499 KU 2,618 3,120 2,618 3,334 (a) Amounts are net of debt issuance costs.

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2021
Derivative Instruments And Hedging Activities [Line Items]
Fair Value and Balance Sheet Location of Derivative Instruments	The following table presents the fair value and location of derivative instruments recorded on the Balance Sheets: December 31, 2021 December 31, 2020 Derivatives designated as Derivatives not designated Derivatives designated as Derivatives not designated Assets Liabilities Assets Liabilities Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) $ — $ — $ — $ 1 $ — $ — $ — $ 2 Cross-currency swaps (c) — — — — 94 — — — Foreign currency contracts (c) — — — — — — — 137 Total current — — — 1 94 — — 139 Noncurrent: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) — — — 17 — — — 21 Cross-currency swaps (c) — — — — 52 — — — Total noncurrent — — — 17 52 — — 21 Total derivatives $ — $ — $ — $ 18 $ 146 $ — $ — $ 160 (a) Current portion is included in "Price risk management assets" and "Other current liabilities" and noncurrent portion is included in "Price risk management assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets. (b) Excludes accrued interest, if applicable. (c) Included in "Current assets held for sale" and "Current liabilities held for sale" on the Balance Sheet.
Pre-tax Gain (Loss) on Derivative Instruments Recognized in Income or on the Balance Sheet	The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities: Derivative Derivative Gain Location of Gain (Loss) Gain (Loss) Reclassified 2021 Cash Flow Hedges: Interest rate swaps $ — Interest Expense $ 11 Income (Loss) from Discontinued operations (net of taxes) (2) Cross-currency swaps (50) Income (Loss) from Discontinued operations (net of taxes) (39) Total $ (50) $ (30) Net Investment Hedges: Foreign currency contracts in Discontinued operations $ 1 2020 Cash Flow Hedges: Interest rate swaps $ (9) Interest Expense $ (8) Income (Loss) from Discontinued operations (net of taxes) (2) Cross-currency swaps (15) Income (Loss) from Discontinued operations (net of taxes) (22) Total $ (24) $ (32) Net Investment Hedges: Foreign currency contracts in Discontinued operations $ 1 2019 Cash Flow Hedges: Interest rate swaps $ (30) Interest Expense $ (9) Cross-currency swaps 17 Income (Loss) from Discontinued operations (net of taxes) (9) Total $ (13) $ (18) Net Investment Hedges: Foreign currency contracts in Discontinued operations $ 2 Derivatives Not Designated as Location of Gain (Loss) Recognized in 2021 2020 2019 Foreign currency contracts Income (Loss) from Discontinued Operations (net of taxes) $ (266) $ (98) $ (14) Interest rate swaps Interest Expense (2) (5) (5) Total $ (268) $ (103) $ (19) Derivatives Not Designated as Location of Gain (Loss) Recognized as 2021 2020 2019 Interest rate swaps Regulatory assets - noncurrent $ 5 $ (2) $ (1) The following table presents the effect of cash flow hedge activity on the Statement of Income for the year ended December 31, 2021: Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Interest Expense Income (Loss) from Discontinued Operations (net of income taxes) Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 918 $ (1,498) The effects of cash flow hedges: Gain (Loss) on cash flow hedging relationships: Interest rate swaps: Amount of gain (loss) reclassified from AOCI to income 11 (2) Cross-currency swaps: Hedged items — 39 Amount of gain (loss) reclassified from AOCI to income — (39) The following table presents the effect of cash flow hedge activity on the Statement of Income for the year ended December 31, 2020: Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Interest Expense Income (Loss) from Discontinued Operations (net of income taxes) Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 634 $ 829 The effects of cash flow hedges: Gain (Loss) on cash flow hedging relationships: Interest rate swaps: Amount of gain (loss) reclassified from AOCI to income (8) (2) Cross-currency swaps: Hedged items — 22 Amount of gain (loss) reclassified from AOCI to income — (22) The following table presents the effect of cash flow hedge activity on the Statement of Income for the year ended December 31,2019: Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Interest Expense Income (Loss) from Discontinued Operations (net of income taxes) Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 621 $ 1,010 The effects of cash flow hedges: Gain (Loss) on cash flow hedging relationships: Interest rate swaps: Amount of gain (loss) reclassified from AOCI to income (9) — Cross-currency swaps: Hedged items — 9 Amount of gain (loss) reclassified from AOCI to income — (9)
Derivative Positions Eligible for Offset with Related Cash Collateral	The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged. Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Cash Net Gross Derivative Cash Net December 31, 2021 Treasury Derivatives PPL $ — $ — $ — $ — $ 18 $ — $ — $ 18 LG&E — — — — 18 — — 18 December 31, 2020 Treasury Derivatives PPL $ 146 $ 34 $ — $ 112 $ 160 $ 34 $ — $ 126 LG&E — — — — 23 — — 23
Louisville Gas And Electric Co [Member]
Derivative Instruments And Hedging Activities [Line Items]
Fair Value and Balance Sheet Location of Derivative Instruments	The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments: December 31, 2021 December 31, 2020 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ 1 $ — $ 2 Total current — 1 — 2 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 17 — 21 Total noncurrent — 17 — 21 Total derivatives $ — $ 18 $ — $ 23
Pre-tax Gain (Loss) on Derivative Instruments Recognized in Income or on the Balance Sheet	The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets: Derivative Instruments Location of Gain (Loss) 2021 2020 2019 Interest rate swaps Interest Expense $ (2) $ (5) $ (5) Derivative Instruments Location of Gain (Loss) 2021 2020 2019 Interest rate swaps Regulatory assets - noncurrent $ 5 $ (2) $ (1)
Derivative Positions Eligible for Offset with Related Cash Collateral	The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged. Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Cash Net Gross Derivative Cash Net December 31, 2021 Treasury Derivatives PPL $ — $ — $ — $ — $ 18 $ — $ — $ 18 LG&E — — — — 18 — — 18 December 31, 2020 Treasury Derivatives PPL $ 146 $ 34 $ — $ 112 $ 160 $ 34 $ — $ 126 LG&E — — — — 23 — — 23
Kentucky Utilities Co [Member]
Derivative Instruments And Hedging Activities [Line Items]
Derivative Positions Eligible for Offset with Related Cash Collateral	The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged. Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Cash Net Gross Derivative Cash Net December 31, 2021 Treasury Derivatives PPL $ — $ — $ — $ — $ 18 $ — $ — $ 18 LG&E — — — — 18 — — 18 December 31, 2020 Treasury Derivatives PPL $ 146 $ 34 $ — $ 112 $ 160 $ 34 $ — $ 126 LG&E — — — — 23 — — 23

Goodwill and Other Intangible_2

Goodwill and Other Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2021
Goodwill and Other Intangible Assets [Line Items]
Other Intangible Assets	The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2021 December 31, 2020 Gross Accumulated Gross Accumulated Subject to amortization: Contracts (a) $ 125 $ 90 $ 125 $ 82 Land rights and easements 406 135 401 133 Licenses and other 20 6 21 4 Total subject to amortization 551 231 547 219 Not subject to amortization due to indefinite life: Land rights and easements 17 — 17 — Other 6 — 6 — Total not subject to amortization due to indefinite life 23 — 23 — Total $ 574 $ 231 $ 570 $ 219 (a) Gross carrying amount in 2021 and 2020 includes the fair value at the acquisition date of the OVEC power purchase contract with terms favorable to market recognized as a result of the 2010 acquisition of LKE by PPL.
Amortization Expense, Excluding Consumption of Emission Allowances / Renewable Energy Credits	Amortization expense was as follows: 2021 2020 2019 Intangible assets with no regulatory offset $ 9 $ 7 $ 6 Intangible assets with regulatory offset 8 8 9 Total $ 17 $ 15 $ 15
Future Amortization Expense	Amortization expense for each of the next five years is estimated to be: 2022 2023 2024 2025 2026 Intangible assets with no regulatory offset $ 5 $ 5 $ 5 $ 5 $ 5 Intangible assets with regulatory offset 8 8 9 9 2 Total $ 13 $ 13 $ 14 $ 14 $ 7
PPL Electric Utilities Corp [Member]
Goodwill and Other Intangible Assets [Line Items]
Other Intangible Assets	The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2021 December 31, 2020 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 382 $ 130 $ 379 $ 129 Licenses and other 2 1 2 1 Total subject to amortization 384 131 381 130 Not subject to amortization due to indefinite life: Land rights and easements 17 — 17 — Total $ 401 $ 131 $ 398 $ 130
Amortization Expense, Excluding Consumption of Emission Allowances / Renewable Energy Credits	Amortization expense was as follows: 2021 2020 2019 Intangible assets with no regulatory offset $ 4 $ 4 $ 4
Future Amortization Expense	Amortization expense for each of the next five years is estimated to be: 2022 2023 2024 2025 2026 Intangible assets with no regulatory offset $ 4 $ 4 $ 4 $ 4 $ 4
Louisville Gas And Electric Co [Member]
Goodwill and Other Intangible Assets [Line Items]
Other Intangible Assets	The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2021 December 31, 2020 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 7 $ 1 $ 7 $ 1 OVEC power purchase agreement (a) 86 62 86 57 Total subject to amortization $ 93 $ 63 $ 93 $ 58 (a) Gross carrying amount represents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability was recorded related to this contract, which is being amortized over the same period as the intangible asset, eliminating any income statement impact. See Note 7 for additional information.
Amortization Expense, Excluding Consumption of Emission Allowances / Renewable Energy Credits	Amortization expense was as follows: 2021 2020 2019 Intangible assets with regulatory offset $ 5 $ 6 $ 6
Future Amortization Expense	Amortization expense for each of the next five years is estimated to be: 2022 2023 2024 2025 2026 Intangible assets with regulatory offset $ 6 $ 6 $ 6 $ 6 $ 1
Kentucky Utilities Co [Member]
Goodwill and Other Intangible Assets [Line Items]
Other Intangible Assets	The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2021 December 31, 2020 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 16 $ 4 $ 15 $ 3 OVEC power purchase agreement (a) 39 28 39 25 Total subject to amortization $ 55 $ 32 $ 54 $ 28 (a) Gross carrying amount represents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability was recorded related to this contract, which is being amortized over the same period as the intangible asset, eliminating any income statement impact. See Note 7 for additional information.
Amortization Expense, Excluding Consumption of Emission Allowances / Renewable Energy Credits	Amortization expense was as follows: 2021 2020 2019 Intangible assets with no regulatory offset $ 1 $ — $ — Intangible assets with regulatory offset 3 2 3
Future Amortization Expense	Amortization expense for each of the next five years is estimated to be: 2022 2023 2024 2025 2026 Intangible assets with regulatory offset $ 2 $ 2 $ 3 $ 3 $ 1

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2021
Asset Retirement Obligation [Line Items]
Asset Retirement Obligation Roll Forward	The changes in the carrying amounts of AROs were as follows: PPL LG&E KU 2021 2020 2021 2020 2021 2020 ARO at beginning of period $ 182 $ 215 $ 67 $ 73 $ 115 $ 142 Accretion 16 15 5 5 11 10 Changes in estimated timing or cost 56 40 40 13 16 27 Obligations settled (65) (88) (28) (24) (37) (64) ARO at end of period $ 189 $ 182 $ 84 $ 67 $ 105 $ 115
Louisville Gas And Electric Co [Member]
Asset Retirement Obligation [Line Items]
Asset Retirement Obligation Roll Forward	The changes in the carrying amounts of AROs were as follows: PPL LG&E KU 2021 2020 2021 2020 2021 2020 ARO at beginning of period $ 182 $ 215 $ 67 $ 73 $ 115 $ 142 Accretion 16 15 5 5 11 10 Changes in estimated timing or cost 56 40 40 13 16 27 Obligations settled (65) (88) (28) (24) (37) (64) ARO at end of period $ 189 $ 182 $ 84 $ 67 $ 105 $ 115
Kentucky Utilities Co [Member]
Asset Retirement Obligation [Line Items]
Asset Retirement Obligation Roll Forward	The changes in the carrying amounts of AROs were as follows: PPL LG&E KU 2021 2020 2021 2020 2021 2020 ARO at beginning of period $ 182 $ 215 $ 67 $ 73 $ 115 $ 142 Accretion 16 15 5 5 11 10 Changes in estimated timing or cost 56 40 40 13 16 27 Obligations settled (65) (88) (28) (24) (37) (64) ARO at end of period $ 189 $ 182 $ 84 $ 67 $ 105 $ 115

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Income (Loss) (Tables)	12 Months Ended
	Dec. 31, 2021
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss)	The after-tax changes in AOCI by component for the years ended December 31 were as follows: Defined benefit plans Foreign Unrealized gains (losses) on Prior Actuarial Total PPL December 31, 2018 $ (1,533) $ (7) $ (19) $ (2,405) $ (3,964) Amounts arising during the year 108 (11) (1) (592) (496) Reclassifications from AOCI — 13 2 87 102 Net OCI during the year 108 2 1 (505) (394) December 31, 2019 $ (1,425) $ (5) $ (18) $ (2,910) $ (4,358) Amounts arising during the year 267 (19) (1) (341) (94) Reclassifications from AOCI — 24 3 205 232 Net OCI during the year 267 5 2 (136) 138 December 31, 2020 $ (1,158) $ — $ (16) $ (3,046) $ (4,220) Defined benefit plans Foreign Unrealized gains (losses) on Prior Actuarial Total Amounts arising during the year 372 (39) — (1) 332 Reclassifications from AOCI — 25 2 126 153 Reclassifications from AOCI due to the sale of the U.K. utility business (Note 9) 786 15 8 2,769 3,578 Net OCI during the year 1,158 1 10 2,894 4,063 December 31, 2021 $ — $ 1 $ (6) $ (152) $ (157)
Reclassification out of Other Comprehensive Income (Loss)	The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the years ended December 31, 2021, 2020 and 2019. The defined benefit plan components of AOCI are not reflected in their entirety in the statement of income; rather, they are included in the computation of net periodic defined benefit costs (credits) and subject to capitalization. See Note 12 for additional information. PPL Details about AOCI 2021 2020 2019 Affected Line Item on the Qualifying derivatives Interest rate swaps $ 11 $ (8) $ (9) Interest Expense (2) (2) — Income (Loss) from Discontinued Operations (net of income taxes) Cross-currency swaps (39) (22) (9) Income (Loss) from Discontinued Operations (net of income taxes) Total Pre-tax (30) (32) (18) Income Taxes 5 8 5 Total After-tax (25) (24) (13) Defined benefit plans Prior service costs (3) (4) (3) Net actuarial loss (159) (256) (109) Total Pre-tax (162) (260) (112) Income Taxes 34 52 23 Total After-tax (128) (208) (89) Sale of the U.K. utility business (Note 9) Foreign currency translation adjustments (646) — — Income (Loss) from Discontinued Operations (net of income taxes) Qualifying derivatives (15) — — Income (Loss) from Discontinued Operations (net of income taxes) Defined benefit plans (3,577) — — Income (Loss) from Discontinued Operations (net of income taxes) Total Pre-tax (4,238) — — Income Taxes 660 — — Total After-tax (3,578) — — Total reclassifications during the year $ (3,731) $ (232) $ (102)

Summary of Significant Accoun_4

Summary of Significant Accounting Policies (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Jun. 30, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Jul. 31, 2021	Dec. 31, 2018
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Asset Impairment Charges	$ 37
Asset Impairment Impairment Charges (After-Tax)	$ 28
Solar Panel Inventory		$ 32
Other		58	$ 86
Cumulative Effect, Period of Adoption, Adjustment
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount			2
Debt Instrument, Redemption, Period One [Member] | Senior Notes Due 2021 [Member] | Senior Notes [Member]
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Stated interest rate					4.375%
Principal amount					$ 250
Debt Instrument, Redemption, Period One [Member] | LKE [Member] | Senior Notes Due 2021 [Member] | Senior Notes [Member]
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Stated interest rate					4.375%
Principal amount					$ 250
Allowance For Doubtful Accounts [Member]
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount		69	73	$ 56		$ 54
Additions charged to income		26	28	34
Additions charged to other accounts		0	0	3
Deductions		30	13	35
SEC Schedule, 12-09, Valuation Allowances and Reserves, Adjusted for CECL, Amount				58
Other		32	30
PPL Electric Utilities Corp [Member]
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Other		22	17
PPL Electric Utilities Corp [Member] | Allowance For Doubtful Accounts [Member]
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount		35	41	28		$ 27
Additions charged to income		13	19	26
Additions charged to other accounts		0	0	0
Deductions		19	8	25
SEC Schedule, 12-09, Valuation Allowances and Reserves, Adjusted for CECL, Amount				$ 30
Other		$ 3	$ 3

Accounting Policies (Details)

Accounting Policies (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Utility Revenue (Details) [Abstract]
Operating Revenues	$ 5,783	$ 5,474	$ 5,602
Restricted Cash and Cash Equivalents [Abstract]
Cash and cash equivalents	3,571	442
Restricted cash - current	1	1
Total Cash, Cash Equivalents and Restricted Cash	3,572	443	660	$ 621
Property, Plant and Equipment (Numeric) [Abstract]
Interest costs, capitalized during the period	$ 6	7	$ 9
Discount Rate Change For United Kingdom Pension Plans Numeric [Abstract]
Percentage in excess of gains and losses equal to the plan's projected benefit obligation to use accelerated amortization	30.00%
Minimum percentage of gains and losses under the accelerated method that are amortized on a straight line basis	10.00%
Maximum percentage of gains and losses under the accelerated that are amortized on a straight line basis	30.00%
Income Taxes [Abstract]
Minimum percentage to be attained of likelihood of uncertain tax position being realized	50.00%
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	$ 322	302
Balance Sheet Classification of Deferred Taxes [Abstract]
Goodwill	716	716
Fuel [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	90	95
Natural Gas Stored Underground [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	54	30
Material And Supplies [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	$ 178	$ 177
Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates	3.61%	3.53%	3.54%
Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period	$ 73	$ 56	$ 54
Additions charged to income	26	28	34
Additions charged to other accounts	0	0	3
Deductions	30	13	35
Balance at end of period	69	73	56
PPL Electric Utilities Corp [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues	2,402	2,331	2,358
Restricted Cash and Cash Equivalents [Abstract]
Cash and cash equivalents	21	40
Total Cash, Cash Equivalents and Restricted Cash	21	40	264	269
Property, Plant and Equipment (Numeric) [Abstract]
Interest costs, capitalized during the period	$ 6	7	$ 8
Discount Rate Change For United Kingdom Pension Plans Numeric [Abstract]
Percentage in excess of gains and losses equal to the plan's projected benefit obligation to use accelerated amortization	30.00%
Minimum percentage of gains and losses under the accelerated method that are amortized on a straight line basis	10.00%
Maximum percentage of gains and losses under the accelerated that are amortized on a straight line basis	30.00%
Income Taxes [Abstract]
Minimum percentage to be attained of likelihood of uncertain tax position being realized	50.00%
Intercompany tax receivables (payables)	$ (4)	(9)
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	61	59
PPL Electric Utilities Corp [Member] | Fuel [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	0	0
PPL Electric Utilities Corp [Member] | Natural Gas Stored Underground [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	0	0
PPL Electric Utilities Corp [Member] | Material And Supplies [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	$ 61	$ 59
PPL Electric Utilities Corp [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates	3.05%	2.99%	3.05%
PPL Electric Utilities Corp [Member] | Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period	$ 41	$ 28	$ 27
Additions charged to income	13	19	26
Additions charged to other accounts	0	0	0
Deductions	19	8	25
Balance at end of period	35	41	28
Louisville Gas And Electric Co [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues	1,569	1,456	1,500
Restricted Cash and Cash Equivalents [Abstract]
Cash and cash equivalents	$ 9	7	$ 15	10
Discount Rate Change For United Kingdom Pension Plans Numeric [Abstract]
Percentage in excess of gains and losses equal to the plan's projected benefit obligation to use accelerated amortization	30.00%
Minimum percentage of gains and losses under the accelerated method that are amortized on a straight line basis	10.00%
Maximum percentage of gains and losses under the accelerated that are amortized on a straight line basis	30.00%
Income Taxes [Abstract]
Minimum percentage to be attained of likelihood of uncertain tax position being realized	50.00%
Intercompany tax receivables (payables)	$ 4	(1)
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	137	119
Balance Sheet Classification of Deferred Taxes [Abstract]
Goodwill	389	389
Louisville Gas And Electric Co [Member] | Fuel [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	32	38
Louisville Gas And Electric Co [Member] | Natural Gas Stored Underground [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	54	30
Louisville Gas And Electric Co [Member] | Material And Supplies [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	$ 51	$ 51
Louisville Gas And Electric Co [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates	3.99%	4.00%	3.87%
Louisville Gas And Electric Co [Member] | Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period	$ 3	$ 1	$ 1
Additions charged to income	4	4	2
Additions charged to other accounts	0	0	2
Deductions	4	2	4
Balance at end of period	3	3	1
Kentucky Utilities Co [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues	1,826	1,690	1,740
Restricted Cash and Cash Equivalents [Abstract]
Cash and cash equivalents	$ 13	22	$ 12	$ 14
Discount Rate Change For United Kingdom Pension Plans Numeric [Abstract]
Percentage in excess of gains and losses equal to the plan's projected benefit obligation to use accelerated amortization	30.00%
Minimum percentage of gains and losses under the accelerated method that are amortized on a straight line basis	10.00%
Maximum percentage of gains and losses under the accelerated that are amortized on a straight line basis	30.00%
Income Taxes [Abstract]
Minimum percentage to be attained of likelihood of uncertain tax position being realized	50.00%
Intercompany tax receivables (payables)	$ 1	(5)
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	124	123
Balance Sheet Classification of Deferred Taxes [Abstract]
Goodwill	607	607
Kentucky Utilities Co [Member] | Fuel [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	58	57
Kentucky Utilities Co [Member] | Natural Gas Stored Underground [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	0	0
Kentucky Utilities Co [Member] | Material And Supplies [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	$ 66	$ 66
Kentucky Utilities Co [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates	4.17%	4.00%	4.02%
Kentucky Utilities Co [Member] | Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period	$ 2	$ 1	$ 2
Additions charged to income	8	4	4
Additions charged to other accounts	0	0	1
Deductions	7	3	6
Balance at end of period	$ 3	$ 2	$ 1

New Accounting Guidance Adopted

New Accounting Guidance Adopted (Details) $ in Millions	Dec. 31, 2021USD ($)
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Lease Liability - Current	$ 22
Lease Liability - Noncurrent	47
Other Noncurrent Assets [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset	62
Louisville Gas And Electric Co [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Lease Liability - Current	6
Lease Liability - Noncurrent	12
Louisville Gas And Electric Co [Member] | Other Noncurrent Assets [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset	15
Kentucky Utilities Co [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Lease Liability - Current	9
Lease Liability - Noncurrent	17
Kentucky Utilities Co [Member] | Other Noncurrent Assets [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset	$ 24

Segment and Related Informati_3

Segment and Related Information (Income Statement and Balance Sheet Data) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Statement Data
Operating Revenues from external customers	$ 5,783,000,000	$ 5,474,000,000	$ 5,602,000,000
Depreciation	1,082,000,000	1,022,000,000	949,000,000
Amortization	39,000,000	58,000,000	58,000,000
Interest Expense	918,000,000	634,000,000	621,000,000
Income Before Income Taxes	521,000,000	954,000,000	919,000,000
Income Taxes	503,000,000	314,000,000	183,000,000
Deferred income taxes and investment tax credits	87,000,000	169,000,000	169,000,000
Net income	(1,480,000,000)	1,469,000,000	1,746,000,000
Cash Flow Data
Expenditures for long-lived assets	1,979,000,000	2,278,000,000	2,250,000,000
Balance Sheet Data
Total Assets	33,223,000,000	48,116,000,000
Kentucky Regulated [Member]
Income Statement Data
Operating Revenues from external customers	3,348,000,000	3,106,000,000	3,206,000,000
Depreciation	647,000,000	606,000,000	547,000,000
Amortization	15,000,000	19,000,000	27,000,000
Interest Expense	249,000,000	300,000,000	298,000,000
Income Before Income Taxes	562,000,000	516,000,000	530,000,000
Income Taxes	94,000,000	98,000,000	94,000,000
Deferred income taxes and investment tax credits	272,000,000	64,000,000	82,000,000
Net income	468,000,000	418,000,000	436,000,000
Cash Flow Data
Expenditures for long-lived assets	1,026,000,000	966,000,000	1,097,000,000
Balance Sheet Data
Total Assets	16,360,000,000	15,943,000,000
Segment Information (Numeric) [Abstract]
Financing Costs Allocated to Segment, Net of Tax		32,000,000	32,000,000
Income Taxes Allocated to Segment		8,000,000	9,000,000
Pennsylvania Regulated [Member]
Income Statement Data
Operating Revenues from external customers	2,402,000,000	2,330,000,000	2,358,000,000
Depreciation	424,000,000	403,000,000	386,000,000
Amortization	19,000,000	26,000,000	24,000,000
Interest Expense	162,000,000	172,000,000	169,000,000
Income Before Income Taxes	599,000,000	664,000,000	607,000,000
Income Taxes	154,000,000	167,000,000	149,000,000
Deferred income taxes and investment tax credits	79,000,000	82,000,000	90,000,000
Net income	445,000,000	497,000,000	458,000,000
Cash Flow Data
Expenditures for long-lived assets	904,000,000	1,154,000,000	1,121,000,000
Balance Sheet Data
Total Assets	13,336,000,000	12,347,000,000
Corporate And Other [Member]
Income Statement Data
Operating Revenues from external customers	33,000,000	38,000,000	38,000,000
Depreciation	11,000,000	13,000,000	16,000,000
Amortization	5,000,000	13,000,000	7,000,000
Interest Expense	507,000,000	162,000,000	154,000,000
Income Before Income Taxes	(640,000,000)	(226,000,000)	(218,000,000)
Income Taxes	255,000,000	49,000,000	(60,000,000)
Deferred income taxes and investment tax credits	(264,000,000)	23,000,000	(3,000,000)
Net income	(895,000,000)	(275,000,000)	(158,000,000)
Cash Flow Data
Expenditures for long-lived assets	49,000,000	158,000,000	32,000,000
Balance Sheet Data
Total Assets	3,527,000,000	843,000,000
Discontinued Operations Segment
Income Statement Data
Net income	(1,498,000,000)	829,000,000	$ 1,010,000,000
Balance Sheet Data
Total Assets	$ 0	$ 18,983,000,000

Segment and Related Informati_4

Segment and Related Information (Geographic Data) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)Integer	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues from external customers | $	$ 5,783	$ 5,474	$ 5,602
Number of reportable segments	2
PPL Electric Utilities Corp [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues from external customers | $	$ 2,402	2,331	2,358
Number of reportable segments	1
Number of operating segments	2
LOUISVILLE GAS And ELECTRIC CO [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues from external customers | $	$ 1,569	1,456	1,500
Number of reportable segments	1
Number of operating segments	1
Kentucky Utilities Co [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues from external customers | $	$ 1,826	$ 1,690	$ 1,740
Number of reportable segments	1
Number of operating segments	1

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)Days	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)
Revenue from contracts with customers [Line Items]
Operating Revenues	$ 5,783	$ 5,474	$ 5,602
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs	77	(24)	(30)
Other Revenue	(22)	(21)	(31)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	5,838	5,429	5,541
Credit loss from contract with customer [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	22	25	27
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	42	40	37	$ 40
Contract with Customer, Liability, Revenue Recognized	24	22	25
Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	2,715	2,585	2,610
Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	1,278	1,185	1,257
Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	639	582	621
Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	386	347	367
Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	24	20	43
Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	66	40	49
Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	730	670	594
Pennsylvania Regulated [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues	$ 2,402	2,330	2,358
Number Of Days Due From Invoice Date | Days	21
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	$ 2,482	2,316	2,342
Pennsylvania Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	1,299	1,238	1,288
Pennsylvania Regulated [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	350	314	349
Pennsylvania Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	53	44	59
Pennsylvania Regulated [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	50	50	52
Pennsylvania Regulated [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0	0	0
Pennsylvania Regulated [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0	0	0
Pennsylvania Regulated [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	730	670	594
Kentucky Regulated [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues	$ 3,348	3,106	3,206
Number Of Days Due From Invoice Date | Days	22
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	$ 3,325	3,077	3,161
Kentucky Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	1,416	1,347	1,322
Kentucky Regulated [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	928	871	908
Kentucky Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	586	538	562
Kentucky Regulated [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	305	261	277
Kentucky Regulated [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	24	20	43
Kentucky Regulated [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	66	40	49
Kentucky Regulated [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0	0	0
Corporate Segment [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues	33	38	38
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	31	36	38
Corporate Segment [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0	0	0
Corporate Segment [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0	0	0
Corporate Segment [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0	0	0
Corporate Segment [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	31	36	38
Corporate Segment [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0	0	0
Corporate Segment [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0	0	0
Corporate Segment [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	$ 0	0	0
PPL Electric [Member]
Revenue from contracts with customers [Line Items]
Number Of Days Due From Invoice Date | Days	21
LGE [Member]
Revenue from contracts with customers [Line Items]
Number Of Days Due From Invoice Date | Days	22
KU [Member]
Revenue from contracts with customers [Line Items]
Number Of Days Due From Invoice Date | Days	22
PPL Electric Utilities Corp [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues	$ 2,402	2,331	2,358
Number Of Days Due From Invoice Date | Days	21
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs	$ 83	(12)	(6)
Other Revenue	(3)	(3)	(10)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	2,482	2,316	2,342
Credit loss from contract with customer [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	10	17	21
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	25	23	21	23
Contract with Customer, Liability, Revenue Recognized	11	9	11
Revenue Reserve for ROE Challenge	78
PPL Electric Utilities Corp [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	1,299	1,238	1,288
PPL Electric Utilities Corp [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	350	314	349
PPL Electric Utilities Corp [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	53	44	59
PPL Electric Utilities Corp [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	50	50	52
PPL Electric Utilities Corp [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0	0	0
PPL Electric Utilities Corp [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0	0	0
PPL Electric Utilities Corp [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	730	670	594
Louisville Gas And Electric Co [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues	$ 1,569	1,456	1,500
Number Of Days Due From Invoice Date | Days	22
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs	$ (3)	(8)	(10)
Other Revenue	(8)	(7)	(9)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	1,558	1,441	1,481
Credit loss from contract with customer [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	4	4	2
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	6	5	5	5
Contract with Customer, Liability, Revenue Recognized	5	5	5
Louisville Gas And Electric Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	711	676	668
Louisville Gas And Electric Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	473	444	466
Louisville Gas And Electric Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	180	173	180
Louisville Gas And Electric Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	145	114	121
Louisville Gas And Electric Co [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0	0	0
Louisville Gas And Electric Co [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	49	34	46
Louisville Gas And Electric Co [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0	0	0
Kentucky Utilities Co [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues	$ 1,826	1,690	1,740
Number Of Days Due From Invoice Date | Days	22
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs	$ (3)	(4)	(14)
Other Revenue	(9)	(10)	(12)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	1,814	1,676	1,714
Credit loss from contract with customer [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	8	4	4
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	6	6	4	$ 4
Contract with Customer, Liability, Revenue Recognized	6	4	4
Kentucky Utilities Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	705	671	654
Kentucky Utilities Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	455	427	442
Kentucky Utilities Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	406	365	382
Kentucky Utilities Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	160	147	156
Kentucky Utilities Co [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	24	20	43
Kentucky Utilities Co [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	64	46	37
Kentucky Utilities Co [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	$ 0	$ 0	$ 0

Revenue, Remaining Performance

Revenue, Remaining Performance Obligation (Details) - Corporate Segment [Member] - Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-12-31 - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount		$ 46
Forecast [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 41
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	12 months

Disaggregation of Revenue (Deta

Disaggregation of Revenue (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	$ 5,838	$ 5,429	$ 5,541
Pennsylvania Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	2,482	2,316	2,342
Kentucky Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	3,325	3,077	3,161
Corporate Segment [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	31	36	38
Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	2,715	2,585	2,610
Residential [Member] | Pennsylvania Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,299	1,238	1,288
Residential [Member] | Kentucky Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,416	1,347	1,322
Residential [Member] | Corporate Segment [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,278	1,185	1,257
Commercial [Member] | Pennsylvania Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	350	314	349
Commercial [Member] | Kentucky Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	928	871	908
Commercial [Member] | Corporate Segment [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	639	582	621
Industrial [Member] | Pennsylvania Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	53	44	59
Industrial [Member] | Kentucky Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	586	538	562
Industrial [Member] | Corporate Segment [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	386	347	367
Other [Member] | Pennsylvania Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	50	50	52
Other [Member] | Kentucky Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	305	261	277
Other [Member] | Corporate Segment [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	31	36	38
Wholesale Municipal [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	24	20	43
Wholesale Municipal [Member] | Pennsylvania Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
Wholesale Municipal [Member] | Kentucky Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	24	20	43
Wholesale Municipal [Member] | Corporate Segment [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
Wholesale Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	66	40	49
Wholesale Other [Member] | Pennsylvania Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
Wholesale Other [Member] | Kentucky Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	66	40	49
Wholesale Other [Member] | Corporate Segment [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
Transmission [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	730	670	594
Transmission [Member] | Pennsylvania Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	730	670	594
Transmission [Member] | Kentucky Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
Transmission [Member] | Corporate Segment [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
PPL Electric Utilities Corp [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	2,482	2,316	2,342
PPL Electric Utilities Corp [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,299	1,238	1,288
PPL Electric Utilities Corp [Member] | Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	350	314	349
PPL Electric Utilities Corp [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	53	44	59
PPL Electric Utilities Corp [Member] | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	50	50	52
PPL Electric Utilities Corp [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
PPL Electric Utilities Corp [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
PPL Electric Utilities Corp [Member] | Transmission [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	730	670	594
Kentucky Utilities Co [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,814	1,676	1,714
Kentucky Utilities Co [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	705	671	654
Kentucky Utilities Co [Member] | Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	455	427	442
Kentucky Utilities Co [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	406	365	382
Kentucky Utilities Co [Member] | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	160	147	156
Kentucky Utilities Co [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	24	20	43
Kentucky Utilities Co [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	64	46	37
Kentucky Utilities Co [Member] | Transmission [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
LOUISVILLE GAS And ELECTRIC CO [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,558	1,441	1,481
LOUISVILLE GAS And ELECTRIC CO [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	711	676	668
LOUISVILLE GAS And ELECTRIC CO [Member] | Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	473	444	466
LOUISVILLE GAS And ELECTRIC CO [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	180	173	180
LOUISVILLE GAS And ELECTRIC CO [Member] | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	145	114	121
LOUISVILLE GAS And ELECTRIC CO [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
LOUISVILLE GAS And ELECTRIC CO [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	49	34	46
LOUISVILLE GAS And ELECTRIC CO [Member] | Transmission [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	$ 0	$ 0	$ 0

Preferred Securities (Details)

Preferred Securities (Details) - $ / shares	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Preferred Stock [Member]
Preferred Securities [Line Items]
Shares authorized	10,000,000
Preferred Stock, Shares Issued	0	0	0
Preferred Stock, Shares Outstanding	0	0	0
PPL Electric Utilities Corp [Member] | Preferred Stock [Member]
Preferred Securities [Line Items]
Shares authorized	20,629,936
Preferred Stock, Shares Issued	0	0	0
Preferred Stock, Shares Outstanding	0	0	0
Louisville Gas And Electric Co [Member] | Preferred Stock [Member]
Preferred Securities [Line Items]
Shares authorized	1,720,000
Preferred Stock, Shares Issued	0	0	0
Preferred Stock, Shares Outstanding	0	0	0
Par value of stock	$ 25
Louisville Gas And Electric Co [Member] | Preferred Stock Without Par Value [Member]
Preferred Securities [Line Items]
Shares authorized	6,750,000
Preferred Stock, Shares Issued	0	0	0
Preferred Stock, Shares Outstanding	0	0	0
Kentucky Utilities Co [Member] | Preferred Stock Without Par Value [Member]
Preferred Securities [Line Items]
Shares authorized	5,300,000
Preferred Stock, Shares Issued	0	0	0
Preferred Stock, Shares Outstanding	0	0	0
Kentucky Utilities Co [Member] | Preference Stock Without Par Value [Member]
Preferred Securities [Line Items]
Shares authorized	2,000,000
Preferred Stock, Shares Issued	0	0	0
Preferred Stock, Shares Outstanding	0	0	0

Earnings Per Share (Details)

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income (Numerator)
Net income	$ (1,480)	$ 1,469	$ 1,746
Less amounts allocated to participating securities	0	1	1
Net Income (Loss) Available to Common Stockholders, Basic	(1,480)	1,468	1,745
Net Income (Loss) from Continuing Operations Available to Common Shareholders, Diluted	18	639	735
Net income available to PPL common shareowners - Basic	18	639	735
Net income available to PPL common shareowners - Diluted	$ (1,480)	$ 1,468	$ 1,745
Shares of Common Stock (Denominator)
Weighted-average shares - Basic EPS (in shares)	762,902	768,590	728,512
Add incremental non-participating securities:
Share-based payment awards (in shares)	1,917	794	1,101
Forward sales agreements	0	0	7,141
Weighted-average shares - Diluted EPS (in shares)	764,819	769,384	736,754
Income (Loss) from Continuing Operations, Per Basic Share	$ 0.03	$ 0.83	$ 1.01
Income (Loss) from Discontinued Operations (Net of tax)	(1.96)	1.08	1.38
Basic EPS - Available to PPL common shareowners:
Net Income (Loss)	(1.93)	1.91	2.39
Income (Loss) from Continuing Operations, Per Diluted Share	0.03	0.83	1
Income (Loss) from Discontinued Operations and Disposal of Discontinued Operations, Net of Tax, Per Diluted Share	(1.96)		1.37
Diluted EPS - Available to PPL common shareowners:
Net Income (in dollars per share)	$ (1.93)	$ 1.91	$ 2.37
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Common stock issued under DRIP (in shares)	0	943
Shares Issued (Numeric) [Abstract]
Common stock issued under stock-based compensation plans (in shares)	983	731
Income (Loss) from Continuing Operations After Income Taxes	$ 18	$ 640	$ 736
Stock Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS	1,783	452	8

Income and Other Taxes (Tax Ref

Income and Other Taxes (Tax Reform) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Tax Reform [Line Items]
Income Tax Expense (Benefit)	$ 503	$ 314	$ 183
Net Increase in Regulatory Liability	(52)	63	88
Deferred Tax Liabilities, Net	3,139	2,519
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, U.K. Finance Act 2021, Amount	383
Deferred Tax Assets, Valuation Allowance, Increase due to Loss on Extinguishment of Debt	31
PPL Electric Utilities Corp [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	154	167	149
Net Increase in Regulatory Liability	(96)	40	43
Deferred Tax Liabilities, Net	1,668	1,559
Louisville Gas And Electric Co [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	54	62	63
Net Increase in Regulatory Liability	23	0	19
Deferred Tax Liabilities, Net	751	716
Kentucky Utilities Co [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	67	63	79
Net Increase in Regulatory Liability	22	26	$ 26
Deferred Tax Liabilities, Net	$ 865	$ 835

Income and Other Taxes (Deferre

Income and Other Taxes (Deferred Tax Assets and Liabilities and Loss Carryforwards) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Before Income Taxes (Details) [Abstract]
Income (Loss) from Continuing Operations Before Income Taxes	$ 521	$ 954	$ 919
Deferred Tax Assets
Deferred investment tax credits	30	30
Regulatory liabilities	94	68
Income taxes due to customer	422	444
Accrued pension and postretirement costs	75	106
Federal loss carryforwards	0	234
State loss carryforwards	483	448
Deferred Tax Assets, Leases	67	68
Contributions in aid of construction	120	115
Leases	84	68
Valuation allowances	(462)	(536)
Total deferred tax assets	928	1,446
Deferred Tax Liabilities
Domestic plant - net	3,812	3,700
Regulatory assets	180	195
Domestic - other	75	70
Total deferred tax liabilities	4,067	3,965
Net deferred tax liability	3,139	2,519
Loss carryforwards
Federal loss carryforwards	0	234
State loss carryforwards	483	448
Deferred tax asset tax credit carryforwards	15	401
State [Member]
Deferred Tax Assets
State loss carryforwards	483
Loss carryforwards
Net operating losses	6,468
State loss carryforwards	483
Loss carryforward valuation allowance on net operating losses	(459)
State [Member] | General Business Tax Credit Carryforward [Member]
Loss carryforwards
Deferred tax asset tax credit carryforwards	1
Other Noncurrent Assets [Member]
Deferred Tax Liabilities
Deferred Tax Assets, State Taxes	12	17
PPL Electric Utilities Corp [Member]
Income Before Income Taxes (Details) [Abstract]
Income (Loss) from Continuing Operations Before Income Taxes	599	664	606
Deferred Tax Assets
Regulatory liabilities	52	24
Income taxes due to customer	154	162
Accrued pension and postretirement costs	14	25
Federal loss carryforwards	0	52
Contributions in aid of construction	95	91
Leases	21	29
Total deferred tax assets	336	383
Deferred Tax Liabilities
Domestic plant - net	1,891	1,826
Regulatory assets	74	86
Domestic - other	39	30
Total deferred tax liabilities	2,004	1,942
Net deferred tax liability	1,668	1,559
Loss carryforwards
Federal loss carryforwards	0	52
Louisville Gas And Electric Co [Member]
Income Before Income Taxes (Details) [Abstract]
Income (Loss) from Continuing Operations Before Income Taxes	303	306	295
Deferred Tax Assets
Deferred investment tax credits	8	8
Regulatory liabilities	18	20
Income taxes due to customer	125	132
Deferred Tax Assets, Lease Liabilities	4	5
State tax credit carryforwards	11	12
Contributions in aid of construction	15	15
Leases	11	11
Valuation allowances	(11)	(12)
Total deferred tax assets	181	191
Deferred Tax Liabilities
Domestic plant - net	854	833
Regulatory assets	65	66
Lease right-of-use assets	4	4
Domestic - other	9	4
Total deferred tax liabilities	932	907
Net deferred tax liability	751	716
Louisville Gas And Electric Co [Member] | Federal [Member] | General Business Tax Credit Carryforward [Member]
Deferred Tax Assets
State tax credit carryforwards	11
Valuation allowances	(11)
Kentucky Utilities Co [Member]
Income Before Income Taxes (Details) [Abstract]
Income (Loss) from Continuing Operations Before Income Taxes	363	343	$ 372
Deferred Tax Assets
Deferred investment tax credits	22	22
Regulatory liabilities	23	23
Income taxes due to customer	143	150
Deferred Tax Assets, Lease Liabilities	7	8
State tax credit carryforwards	4	5
Contributions in aid of construction	9	8
Leases	4	4
Valuation allowances	(3)	(4)
Total deferred tax assets	209	216
Deferred Tax Liabilities
Domestic plant - net	1,012	992
Regulatory assets	41	43
Accrued pension and postretirement costs	13	8
Lease right-of-use assets	6	7
Domestic - other	2	1
Total deferred tax liabilities	1,074	1,051
Net deferred tax liability	865	$ 835
Kentucky Utilities Co [Member] | Federal [Member] | General Business Tax Credit Carryforward [Member]
Deferred Tax Assets
State tax credit carryforwards	4
Valuation allowances	$ (3)

Income and Other Taxes (Credit

Income and Other Taxes (Credit Carryforwards and Valuation Allowances and Reserves) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Credit carryforwards
Deferred tax asset tax credit carryforwards	$ 15	$ 401
Deferred Tax Assets, Valuation Allowances	462	536
Valuation Allowances and Reserves (Details) [Roll Forward]
Deferred Tax Assets, Valuation Allowances	462	536
Recycling Tax Credit [Member] | State [Member]
Credit carryforwards
Deferred tax asset tax credit carryforwards	14
Credit Carryforward Valuation Allowance Other	0
Other [Member] | State [Member]
Credit carryforwards
Deferred tax asset tax credit carryforwards	1
Credit Carryforward Valuation Allowance Other	0
Valuation Allowance Of Deferred Tax Assets [Member]
Valuation Allowances and Reserves (Details) [Roll Forward]
Balance at beginning of period	536	514	$ 495
Additions charged to income	48	26	24
Additions charged to other accounts	0	0	0
Deductions	122	4	5
Balance at end of period	462	536	$ 514
SEC Schedule 12-09, Valuation Allowance, Deduction, Business Disposition	113
Louisville Gas And Electric Co [Member]
Credit carryforwards
State tax credit carryforwards	11	12
Deferred Tax Assets, Valuation Allowances	11	12
Valuation Allowances and Reserves (Details) [Roll Forward]
Deferred Tax Assets, Valuation Allowances	11	12
Louisville Gas And Electric Co [Member] | Other [Member] | Federal [Member]
Credit carryforwards
State tax credit carryforwards	11
Deferred Tax Assets, Valuation Allowances	11
Valuation Allowances and Reserves (Details) [Roll Forward]
Deferred Tax Assets, Valuation Allowances	11
Kentucky Utilities Co [Member]
Credit carryforwards
State tax credit carryforwards	4	5
Deferred Tax Assets, Valuation Allowances	3	4
Valuation Allowances and Reserves (Details) [Roll Forward]
Deferred Tax Assets, Valuation Allowances	3	$ 4
Kentucky Utilities Co [Member] | Other [Member] | Federal [Member]
Credit carryforwards
State tax credit carryforwards	4
Deferred Tax Assets, Valuation Allowances	3
Valuation Allowances and Reserves (Details) [Roll Forward]
Deferred Tax Assets, Valuation Allowances	3
Kentucky Utilities Co [Member] | Other [Member] | Federal [Member] | Tax Credit Carryforward Expiration Year 2028 [Member]
Credit carryforwards
State tax credit carryforwards	3
Kentucky Utilities Co [Member] | Other [Member] | Federal [Member] | Tax Credit Carryforward Expiration Indefinite [Member]
Credit carryforwards
State tax credit carryforwards	$ 1

Income and Other Taxes (Income

Income and Other Taxes (Income Tax Expense and Reconciliation of Income Tax Expense) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Tax Expense (Benefit)
Current - Federal	$ (1)	$ (8)	$ (10)
Current - State	36	24	19
Current - Foreign	(1)	(2)	0
Total Current Expense	34	14	9
Deferred - Federal	28	135	141
Deferred - State	105	94	76
Deferred - Foreign	383	101	(14)
Total Deferred Expense (Benefit), excluding operating loss carry forwards	516	330	203
Amortization of investment tax credit	(3)	(3)	(3)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Deferred - Federal	12	6	7
Deferred - State	(56)	(33)	(33)
Total Tax Expense (Benefit) of Operating Loss Carryforwards	(44)	(27)	(26)
Total income tax from continuing operations	503	314	183
Income tax expense [Abstract]
Total income tax expense - Federal	36	130	135
Total income tax expense - State	85	85	62
Total income tax expense - Foreign	382	99	(14)
Total income tax from continuing operations	503	314	183
Income Tax Expense (Benefit) Excluded From Income Taxes [Abstract]
Income tax related to other comprehensive income	150	(19)	(93)
Total income tax expense (benefits) excluded from income taxes from continuing operations	1,569	169	133
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate	109	200	193
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	23	48	45
Valuation allowance adjustments	48	24	22
Federal and state income tax return adjustments	(3)	(9)	1
Impact of the United Kingdom Finance Acts on deferred tax balances	383	101	(14)
Depreciation and other items not normalized	(5)	(5)	(10)
Amortization of excess deferred federal and state income taxes	(54)	(43)	(40)
Kentucky recycling credit, net of federal income tax expense	0	0	(18)
Other	(4)	(9)	0
Total increase (decrease)	394	114	(10)
Total income tax from continuing operations	$ 503	$ 314	$ 183
Effective income tax rate	96.50%	32.90%	19.90%
Expense related to increased Pennsylvania net operating loss carryforwards expected to be unutilized	$ 15	$ 24	$ 25
Taxes, other than income
State gross receipts	113	100	107
Domestic property and other	94	80	79
Total	207	180	186
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, U.K. Finance Act 2020, Amount	106
Deferred Tax Assets, Valuation Allowances	462	536
Reclassification from AOCI due to sale of UK utility business	660	0	0
Nondeductible officers salary	6	7	4
WPD [Member]
Taxes, other than income
Income tax related to Discontinued Operations	759	188	226
Foreign Tax Authority [Member]
Income Tax Expense (Benefit)
Deferred - Foreign		106
PPL Electric Utilities Corp [Member]
Income Tax Expense (Benefit)
Current - Federal	40	61	44
Current - State	35	23	15
Total Current Expense	75	84	59
Deferred - Federal	59	45	51
Deferred - State	20	38	39
Total Deferred Expense (Benefit), excluding operating loss carry forwards	79	83	90
Tax expense (benefit) of operating loss carryforwards [Abstract]
Total income tax from continuing operations	154	167	149
Income tax expense [Abstract]
Total income tax expense - Federal	99	106	95
Total income tax expense - State	55	61	54
Total income tax from continuing operations	154	167	149
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate	126	139	127
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	46	52	47
Federal and state income tax return adjustments	0	(4)	1
Depreciation and other items not normalized	(5)	(5)	(10)
Amortization of excess deferred federal and state income taxes	(14)	(16)	(18)
Other	1	1	2
Total increase (decrease)	28	28	22
Total income tax from continuing operations	$ 154	$ 167	$ 149
Effective income tax rate	25.70%	25.20%	24.60%
Taxes, other than income
State gross receipts	$ 113	$ 100	$ 107
Domestic property and other	7	7	5
Total	120	107	112
Louisville Gas And Electric Co [Member]
Income Tax Expense (Benefit)
Current - Federal	41	53	4
Current - State	5	7	4
Total Current Expense	46	60	8
Deferred - Federal	1	(4)	46
Deferred - State	8	7	10
Total Deferred Expense (Benefit), excluding operating loss carry forwards	9	3	56
Amortization of investment tax credit	(1)	(1)	(1)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Total income tax from continuing operations	54	62	63
Income tax expense [Abstract]
Total income tax expense - Federal	41	48	49
Total income tax expense - State	13	14	14
Total income tax from continuing operations	54	62	63
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate	64	64	62
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	12	12	12
Valuation allowance adjustments	0	0	14
Amortization of excess deferred federal and state income taxes	(20)	(11)	(10)
Kentucky recycling credit, net of federal income tax expense	0	0	(14)
Other	(2)	(3)	(1)
Total increase (decrease)	(10)	(2)	1
Total income tax from continuing operations	$ 54	$ 62	$ 63
Effective income tax rate	17.80%	20.30%	21.40%
Taxes, other than income
Domestic property and other	$ 46	$ 40	$ 39
Total	46	40	39
Deferred Tax Assets, Valuation Allowances	11	12
Kentucky Utilities Co [Member]
Income Tax Expense (Benefit)
Current - Federal	58	40	35
Current - State	8	3	5
Total Current Expense	66	43	40
Deferred - Federal	(4)	11	28
Deferred - State	7	11	13
Total Deferred Expense (Benefit), excluding operating loss carry forwards	3	22	41
Amortization of investment tax credit	(2)	(2)	(2)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Total income tax from continuing operations	67	63	79
Income tax expense [Abstract]
Total income tax expense - Federal	52	49	61
Total income tax expense - State	15	14	18
Total income tax from continuing operations	67	63	79
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate	76	72	78
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	14	14	15
Valuation allowance adjustments	0	0	4
Amortization of investment tax credit	(2)	(2)	(2)
Amortization of excess deferred federal and state income taxes	(20)	(17)	(13)
Kentucky recycling credit, net of federal income tax expense	0	0	(4)
Other	(1)	(4)	1
Total increase (decrease)	(9)	(9)	1
Total income tax from continuing operations	$ 67	$ 63	$ 79
Effective income tax rate	18.40%	18.40%	21.20%
Taxes, other than income
Domestic property and other	$ 41	$ 37	$ 35
Total	41	37	$ 35
Deferred Tax Assets, Valuation Allowances	$ 3	$ 4

Income and Other Taxes (Unrecog

Income and Other Taxes (Unrecognized to End) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021USD ($)Integer	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Income Tax Examination (Details) [Line Items]
Number of major tax jurisdictions tax returns are filed | Integer	4
Deferred Income Tax Expense (Benefit)	$ 516	$ 330	$ 203
Increase (Decrease) in Regulatory Assets and Liabilities	$ (52)	63	88
US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2017 and prior
Pennsylvania - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2017 and prior
Kentucky - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2014 and prior
United Kingdom - Foreign [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2019 and prior
Federal [Member]
Income Tax Examination (Details) [Line Items]
Net Operating Loss Carryforwards, Used During the Period	$ 1,115
Deferred Tax Assets, Operating Loss Carryforwards, Adjustment, Domestic	506
Federal [Member] | Investment Tax Credit [Member]
Income Tax Examination (Details) [Line Items]
Deferred Tax Assets, Tax Credit Carryforwards, Used during the period	$ 272
PPL Electric Utilities Corp [Member]
Income Tax Examination (Details) [Line Items]
Number of major tax jurisdictions tax returns are filed | Integer	2
Deferred Income Tax Expense (Benefit)	$ 79	83	90
Increase (Decrease) in Regulatory Assets and Liabilities	$ (96)	40	43
PPL Electric Utilities Corp [Member] | US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2017 and prior
PPL Electric Utilities Corp [Member] | Pennsylvania - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2017 and prior
Louisville Gas And Electric Co [Member]
Income Tax Examination (Details) [Line Items]
Number of major tax jurisdictions tax returns are filed | Integer	2
Deferred Income Tax Expense (Benefit)	$ 9	3	56
Increase (Decrease) in Regulatory Assets and Liabilities	$ 23	0	19
Louisville Gas And Electric Co [Member] | US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2017 and prior
Louisville Gas And Electric Co [Member] | Kentucky - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2014 and prior
Kentucky Utilities Co [Member]
Income Tax Examination (Details) [Line Items]
Number of major tax jurisdictions tax returns are filed | Integer	2
Deferred Income Tax Expense (Benefit)	$ 3	22	41
Increase (Decrease) in Regulatory Assets and Liabilities	$ 22	$ 26	$ 26
Kentucky Utilities Co [Member] | US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2017 and prior
Kentucky Utilities Co [Member] | Kentucky - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2014 and prior

Utility Rate Regulation (Regula

Utility Rate Regulation (Regulatory Assets) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Regulatory Assets [Line Items]
Current Regulatory Assets	$ 64	$ 99
Noncurrent Regulatory Assets	1,236	1,262
Defined benefit plans [Member]
Regulatory Assets [Line Items]
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period	98	79
Plant outage costs [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	46
Noncurrent Regulatory Assets	54	0
Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	21	4
Smart meter rider [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	11	17
Transmission Formula Rate [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	6	15
Storm costs [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	7
Noncurrent Regulatory Assets	11	17
Other [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	15	10
Noncurrent Regulatory Assets	6	7
Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	523	570
Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	24	30
Interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	18	23
Terminated interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	70	75
Accumulated cost of removal of utility plant [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	228	240
AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	302	300
Fuel Adjustment Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	11	0
PPL Electric Utilities Corp [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	22	40
Noncurrent Regulatory Assets	488	541
PPL Electric Utilities Corp [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Noncurrent Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Smart meter rider [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	11	17
PPL Electric Utilities Corp [Member] | Transmission Formula Rate [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	6	15
PPL Electric Utilities Corp [Member] | Storm costs [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	7
Noncurrent Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Other [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	5	1
Noncurrent Regulatory Assets	0	3
PPL Electric Utilities Corp [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	256	290
PPL Electric Utilities Corp [Member] | Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	4	8
PPL Electric Utilities Corp [Member] | Interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Terminated interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Accumulated cost of removal of utility plant [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	228	240
PPL Electric Utilities Corp [Member] | AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Louisville Gas And Electric Co [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	33	23
Noncurrent Regulatory Assets	337	351
Louisville Gas And Electric Co [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period	54	44
Louisville Gas And Electric Co [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	12
Noncurrent Regulatory Assets	15	0
Louisville Gas And Electric Co [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	21	4
Louisville Gas And Electric Co [Member] | Gas Line Tracker [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	3	4
Louisville Gas And Electric Co [Member] | Storm costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	8	11
Louisville Gas And Electric Co [Member] | Generation formula rate
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Louisville Gas And Electric Co [Member] | Other [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	5	3
Noncurrent Regulatory Assets	4	1
Louisville Gas And Electric Co [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	164	174
Louisville Gas And Electric Co [Member] | Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	12	13
Louisville Gas And Electric Co [Member] | Interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	18	23
Louisville Gas And Electric Co [Member] | Terminated interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	41	44
Louisville Gas And Electric Co [Member] | AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	75	85
Louisville Gas And Electric Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	4	0
Kentucky Utilities Co [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	9	36
Noncurrent Regulatory Assets	411	370
Kentucky Utilities Co [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period	44	35
Kentucky Utilities Co [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	34
Noncurrent Regulatory Assets	39	0
Kentucky Utilities Co [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Kentucky Utilities Co [Member] | Gas Line Tracker [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Kentucky Utilities Co [Member] | Storm costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	3	6
Kentucky Utilities Co [Member] | Generation formula rate
Regulatory Assets [Line Items]
Current Regulatory Assets	2	2
Kentucky Utilities Co [Member] | Other [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Noncurrent Regulatory Assets	2	3
Kentucky Utilities Co [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	103	106
Kentucky Utilities Co [Member] | Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	8	9
Kentucky Utilities Co [Member] | Interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
Kentucky Utilities Co [Member] | Terminated interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	29	31
Kentucky Utilities Co [Member] | AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	227	215
Kentucky Utilities Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	$ 7	$ 0

Utility Rate Regulation (Regu_2

Utility Rate Regulation (Regulatory Liabilities) (Details) - USD ($) $ in Millions	May 21, 2020	Dec. 31, 2021	Dec. 31, 2020
Regulatory Liabilities [Line Items]
Current regulatory liabilities		$ 182	$ 79
Noncurrent regulatory liabilities		2,422	2,530
Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		10	21
Universal Service Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		17	22
TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		22	11
Act 129 Compliance Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		10	7
Regulatory Liability due to ROE Reserve
Regulatory Liabilities [Line Items]
Current regulatory liabilities		73	0
Economic relief billing credit
Regulatory Liabilities [Line Items]
Current regulatory liabilities		27	0
Accumulated cost of removal of utility plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		639	653
Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		35	43
Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		1,591	1,690
Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		95	60
Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		62	66
Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		2	17
Noncurrent regulatory liabilities		0	18
Transmission Service Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		21	1
PPL Electric Utilities Corp [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		153	68
Noncurrent regulatory liabilities		559	578
Return on equity	11.18%
PPL Electric Utilities Corp [Member] | Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		10	21
PPL Electric Utilities Corp [Member] | Universal Service Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		17	22
PPL Electric Utilities Corp [Member] | TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		22	11
PPL Electric Utilities Corp [Member] | Act 129 Compliance Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		10	7
PPL Electric Utilities Corp [Member] | Regulatory Liability due to ROE Reserve
Regulatory Liabilities [Line Items]
Current regulatory liabilities		73	0
PPL Electric Utilities Corp [Member] | Economic relief billing credit
Regulatory Liabilities [Line Items]
Current regulatory liabilities		0	0
PPL Electric Utilities Corp [Member] | Accumulated cost of removal of utility plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		0	0
PPL Electric Utilities Corp [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		0	0
PPL Electric Utilities Corp [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		531	560
PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		28	18
PPL Electric Utilities Corp [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		0	0
PPL Electric Utilities Corp [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		0	6
Noncurrent regulatory liabilities		0	0
PPL Electric Utilities Corp [Member] | Transmission Service Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		21	1
Louisville Gas And Electric Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		21	0
Noncurrent regulatory liabilities		818	882
Louisville Gas And Electric Co [Member] | Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		0	0
Louisville Gas And Electric Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		0	0
Louisville Gas And Electric Co [Member] | Economic relief billing credit
Regulatory Liabilities [Line Items]
Current regulatory liabilities		21	0
Louisville Gas And Electric Co [Member] | Accumulated cost of removal of utility plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		262	274
Louisville Gas And Electric Co [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		24	30
Louisville Gas And Electric Co [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		491	528
Louisville Gas And Electric Co [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		10	0
Louisville Gas And Electric Co [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		31	33
Louisville Gas And Electric Co [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		0	0
Noncurrent regulatory liabilities		0	17
Kentucky Utilities Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		8	11
Noncurrent regulatory liabilities		1,045	1,070
Kentucky Utilities Co [Member] | Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		0	4
Kentucky Utilities Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		0	5
Kentucky Utilities Co [Member] | Economic relief billing credit
Regulatory Liabilities [Line Items]
Current regulatory liabilities		6	0
Kentucky Utilities Co [Member] | Accumulated cost of removal of utility plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		377	379
Kentucky Utilities Co [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		11	13
Kentucky Utilities Co [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		569	602
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		57	42
Kentucky Utilities Co [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		31	33
Kentucky Utilities Co [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		2	2
Noncurrent regulatory liabilities		$ 0	$ 1

Utility Rate Regulation (Regu_3

Utility Rate Regulation (Regulatory Assets and Liabilities) (Details) - USD ($) $ in Millions	Dec. 06, 2021	May 21, 2020	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities			$ (52)	$ 63	$ 88
Defined Benefit Plans [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period			15 years
Regulatory Assets and Liabilities - Defined Benefit Plans (Numeric) [Abstract]
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period			$ 98	79
PPL Electric [Member] | Storm Costs [Member]
Regulatory Assets and Liabilities - Storm Costs (Numeric) [Abstract]
Period over which storm costs will be recovered (in years)			3 years
PPL Electric [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period			5 years
PPL Electric [Member] | Storm Damage Expense Rider [Member]
Regulatory Assets and Liabilities - Storm Damage Expense Rider (Numeric) [Abstract]
Maximum reportable storm damage expenses to be recovered annually through base rates			$ 20
PPL Electric [Member] | Act 129 Compliance Rider [Member]
Regulatory Assets and Liabilities - Act 129 Compliance Rider (Numeric) [Abstract]
Maximum amount of costs that can be recovered under the Act 129 Phase III plan			$ 313
Period over which program costs can be recovered for Phase III (in years)			5 years
LGE [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period			12 months
LGE [Member] | Gas Supply Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period			18 months
LGE [Member] | Kentucky Public Service Commission [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Return on equity	9.425%
LGE [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period			12 months
Return on equity			9.35%
KU [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period			12 months
KU [Member] | Kentucky Public Service Commission [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Return on equity	9.425%
KU [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period			12 months
Return on equity	9.35%		9.35%
PPL Electric Utilities Corp [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities			$ (96)	40	43
Return on equity		11.18%
PPL Electric Utilities Corp [Member] | Storm Costs [Member]
Regulatory Assets and Liabilities - Storm Costs (Numeric) [Abstract]
Period over which storm costs will be recovered (in years)			3 years
PPL Electric Utilities Corp [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period			5 years
PPL Electric Utilities Corp [Member] | Storm Damage Expense Rider [Member]
Regulatory Assets and Liabilities - Storm Damage Expense Rider (Numeric) [Abstract]
Maximum reportable storm damage expenses to be recovered annually through base rates			$ 20
PPL Electric Utilities Corp [Member] | Act 129 Compliance Rider [Member]
Regulatory Assets and Liabilities - Act 129 Compliance Rider (Numeric) [Abstract]
Maximum amount of costs that can be recovered under the Act 129 Phase III plan			$ 313
Period over which program costs can be recovered for Phase III (in years)			5 years
Louisville Gas And Electric Co [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities			$ 23	0	19
Louisville Gas And Electric Co [Member] | Defined Benefit Plans [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period			15 years
Regulatory Assets and Liabilities - Defined Benefit Plans (Numeric) [Abstract]
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period			$ 54	44
Louisville Gas And Electric Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period			12 months
Louisville Gas And Electric Co [Member] | Gas Supply Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period			18 months
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Return on equity	9.425%
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period			12 months
Return on equity			9.35%
Kentucky Utilities Co [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities			$ 22	26	$ 26
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period			15 years
Regulatory Assets and Liabilities - Defined Benefit Plans (Numeric) [Abstract]
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period			$ 44	$ 35
Kentucky Utilities Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period			12 months
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Return on equity	9.425%
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period			12 months
Return on equity	9.35%		9.35%

Utility Rate Regulation (Regu_4

Utility Rate Regulation (Regulatory Matters) (Details) - USD ($) $ in Millions	Jun. 01, 2023	Dec. 06, 2021	Nov. 25, 2020	May 21, 2020	Aug. 31, 2021	Nov. 30, 2021	May 31, 2023	Dec. 31, 2021	May 31, 2022	May 31, 2026
Kentucky Public Service Commission [Member] | Electric And Gas Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Dollar amount requested increase in base rates with anticipated rate case filing			$ 331
Public Utilities, Approved Rate Increase (Decrease), Amount		$ 207
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Public Utilities, Requested Bill Credit			$ 53
LGE [Member]
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Requested Billing Credit Period		1 year
Stay Out Commitment Period		4 years
LGE [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Return on equity		9.425%
Requested return on equity			10.00%
LGE [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Return on equity								9.35%
Amortization period for the deferred recovery of a regulatory asset								12 months
LGE [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery and Gas Line Tracker
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Return on equity		9.35%
LGE [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Dollar amount requested increase in base rates with anticipated rate case filing			$ 30
Public Utilities, Requested Rate Increase (Decrease), Percentage			8.30%
Public Utilities, Approved Rate Increase (Decrease), Amount		$ 23
LGE [Member] | Kentucky Public Service Commission [Member] | Electric And Gas Rates [Member]
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Public Utilities, Requested Bill Credit			$ 41
LGE [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Dollar amount requested increase in base rates with anticipated rate case filing			$ 131
Public Utilities, Requested Rate Increase (Decrease), Percentage			11.60%
Public Utilities, Approved Rate Increase (Decrease), Amount		$ 74
KU [Member]
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Requested Billing Credit Period		1 year
Stay Out Commitment Period		4 years
KU [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Return on equity		9.425%
Requested return on equity			10.00%
KU [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Return on equity		9.35%						9.35%
Amortization period for the deferred recovery of a regulatory asset								12 months
KU [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Dollar amount requested increase in base rates with anticipated rate case filing			$ 170
Public Utilities, Requested Rate Increase (Decrease), Percentage			10.40%
Public Utilities, Approved Rate Increase (Decrease), Amount		$ 110
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Public Utilities, Requested Bill Credit			$ 12
PPL Electric Utilities Corp [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Return on equity				11.18%
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Amended Proposed Return On Equity From Complaint	10.00%						9.95%		990.00%
Regulatory Liability due to ROE Reserve, After Tax						$ 55
PPL Electric Utilities Corp [Member] | Period of 05-21-2020 to 12-31-2020
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Regulatory Liability due to ROE Reserve, Before Tax						28
Regulatory Liability due to ROE Reserve, After Tax						20
PPL Electric Utilities Corp [Member] | Period of 05-21-2020 to 11-30-2021
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Regulatory Liability due to ROE Reserve, Before Tax						73
Regulatory Liability due to ROE Reserve, After Tax						52
PPL Electric Utilities Corp [Member] | Maximum [Member]
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Public Utilities, Approved Equity Capital Structure, Percentage					56.00%
PPL Electric Utilities Corp [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Return on equity				11.18%
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Amended Proposed Return On Equity From Complaint	10.00%						9.95%		990.00%
Regulatory Liability due to ROE Reserve, Before Tax						78
Regulatory Liability due to ROE Reserve, After Tax						55
PPL Electric Utilities Corp [Member] | Period of 05-21-2020 to 12-31-2020
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Regulatory Liability due to ROE Reserve, Before Tax						28
Regulatory Liability due to ROE Reserve, After Tax						20
PPL Electric Utilities Corp [Member] | Period of 05-21-2020 to 11-30-2021
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Regulatory Liability due to ROE Reserve, Before Tax						73
Regulatory Liability due to ROE Reserve, After Tax						52
PPL Electric Utilities Corp [Member] | Maximum [Member]
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Public Utilities, Approved Equity Capital Structure, Percentage					56.00%
PPL Electric Utilities Corp [Member] | PPL Electric [Member]
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Act 129 Recovery Period Under Phase IV Plan										5 years
PPL Electric Utilities Corp [Member] | PPL Electric Utilities Corp [Member]
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Regulatory Liability due to ROE Reserve, Before Tax						78
PPL Electric Utilities Corp [Member] | PPL Electric Utilities Corp [Member] | Period of 05-21-2020 to 11-30-2021
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Regulatory Liability due to ROE Reserve, Before Tax						$ 73
Louisville Gas And Electric Co [Member]
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Requested Billing Credit Period		1 year
Stay Out Commitment Period		4 years
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Return on equity		9.425%
Requested return on equity			10.00%
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Return on equity								9.35%
Amortization period for the deferred recovery of a regulatory asset								12 months
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery and Gas Line Tracker
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Return on equity		9.35%
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Gas Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Dollar amount requested increase in base rates with anticipated rate case filing			$ 30
Public Utilities, Requested Rate Increase (Decrease), Percentage			8.30%
Public Utilities, Approved Rate Increase (Decrease), Amount		$ 23
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Electric And Gas Rates [Member]
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Public Utilities, Requested Bill Credit			$ 41
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Dollar amount requested increase in base rates with anticipated rate case filing			$ 131
Public Utilities, Requested Rate Increase (Decrease), Percentage			11.60%
Public Utilities, Approved Rate Increase (Decrease), Amount		$ 74
Kentucky Utilities Co [Member]
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Requested Billing Credit Period		1 year
Stay Out Commitment Period		4 years
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Return on equity		9.425%
Requested return on equity			10.00%
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Return on equity		9.35%						9.35%
Amortization period for the deferred recovery of a regulatory asset								12 months
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Electric Rates [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Dollar amount requested increase in base rates with anticipated rate case filing			$ 170
Public Utilities, Requested Rate Increase (Decrease), Percentage			10.40%
Public Utilities, Approved Rate Increase (Decrease), Amount		$ 110
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Public Utilities, Requested Bill Credit			$ 12

Utility Rate Regulation (Other)

Utility Rate Regulation (Other) (Details) - Unaffiliated Third Party Entity [Member] - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
PPL Electric [Member]
Purchases Of Accounts Receivable [Line Items]
Purchases of accounts receivable	$ 1.2	$ 1.1	$ 1.2
PPL Electric Utilities Corp [Member]
Purchases Of Accounts Receivable [Line Items]
Purchases of accounts receivable	$ 1.2	$ 1.1	$ 1.2

Financing Activities - Credit A

Financing Activities - Credit Arrangements (Details) - USD ($) $ in Millions	Dec. 31, 2021	Nov. 30, 2021	Dec. 31, 2020
PPL Capital Funding [Member]
Financing Activities [Line Items]
Capacity	$ 1,350
Borrowed	0		$ 400
Letters of credit and commercial paper issued	15		417
Unused capacity	1,335
PPL Capital Funding [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity	1,250	$ 1,450
Borrowed	0		0
Letters of credit and commercial paper issued	0		402
Unused capacity	$ 1,250
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%
Potential capacity increase	$ 250
PPL Capital Funding [Member] | Bilateral Credit Facility [Member]
Financing Activities [Line Items]
Capacity	50
Borrowed	0		0
Letters of credit and commercial paper issued	0		0
Unused capacity	$ 50
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%
PPL Capital Funding [Member] | Term Loan Credit Facility [Member]
Financing Activities [Line Items]
Capacity	$ 0
Borrowed	0		200
Letters of credit and commercial paper issued	0		0
Unused capacity	$ 0
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%
PPL Capital Funding [Member] | Term Loan Facility
Financing Activities [Line Items]
Capacity	$ 0
Borrowed	0		100
Letters of credit and commercial paper issued	0		0
Unused capacity	$ 0
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%
PPL Capital Funding [Member] | Term Loan Facility
Financing Activities [Line Items]
Capacity	$ 0
Borrowed	0		100
Letters of credit and commercial paper issued	0		0
Unused capacity	$ 0
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%
PPL Capital Funding [Member] | Bilateral Credit Facility
Financing Activities [Line Items]
Capacity	$ 50
Borrowed	0		0
Letters of credit and commercial paper issued	15		15
Unused capacity	$ 35
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%
PPL Capital Funding [Member] | U.S. [Member] | Bilateral Credit Facility [Member]
Financing Activities [Line Items]
Potential capacity increase	$ 30
PPL Electric [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity	650
Borrowed	0		0
Letters of credit and commercial paper issued	1		1
Unused capacity	$ 649
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%
Potential capacity increase	$ 250
LGE [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity	500
Borrowed	0		0
Letters of credit and commercial paper issued	69		262
Unused capacity	$ 431
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%
Potential capacity increase	$ 250
KU [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity	400
Borrowed	0		0
Letters of credit and commercial paper issued	0		203
Unused capacity	$ 400
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%
Potential capacity increase	$ 250
PPL Electric Utilities Corp [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity	650
Borrowed	0		0
Letters of credit and commercial paper issued	1		1
Unused capacity	$ 649
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%
Potential capacity increase	$ 250
Louisville Gas And Electric Co [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity	500
Borrowed	0		0
Letters of credit and commercial paper issued	69		262
Unused capacity	$ 431
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%
Potential capacity increase	$ 250
Kentucky Utilities Co [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity	400
Borrowed	0		0
Letters of credit and commercial paper issued	0		$ 203
Unused capacity	$ 400
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%
Potential capacity increase	$ 250

Financing Activities - Short-te

Financing Activities - Short-term Debt (Details) - Commercial Paper [Member] - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Short-term Debt [Line Items]
Capacity	$ 2,925
Commercial paper issuances	69	$ 867
Unused capacity	$ 2,856
PPL Capital Funding [Member]
Short-term Debt [Line Items]
Weighted-average interest rate		0.25%
Capacity	$ 1,500
Commercial paper issuances	0	$ 402
Unused capacity	$ 1,500
PPL Electric [Member]
Short-term Debt [Line Items]
Weighted-average interest rate
Capacity	$ 650
Commercial paper issuances	0	$ 0
Unused capacity	$ 650
LGE [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	0.31%	0.28%
Capacity	$ 425
Commercial paper issuances	69	$ 262
Unused capacity	$ 356
KU [Member]
Short-term Debt [Line Items]
Weighted-average interest rate		0.28%
Capacity	$ 350
Commercial paper issuances	0	$ 203
Unused capacity	$ 350
PPL Electric Utilities Corp [Member]
Short-term Debt [Line Items]
Weighted-average interest rate
Capacity	$ 650
Commercial paper issuances	0	$ 0
Unused capacity	$ 650
Louisville Gas And Electric Co [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	0.31%	0.28%
Capacity	$ 425
Commercial paper issuances	69	$ 262
Unused capacity	$ 356
Kentucky Utilities Co [Member]
Short-term Debt [Line Items]
Weighted-average interest rate		0.28%
Capacity	$ 350
Commercial paper issuances	0	$ 203
Unused capacity	$ 350

Financing Activities - Long-ter

Financing Activities - Long-term Debt (Details) - USD ($) $ in Millions	1 Months Ended		12 Months Ended
	Jul. 31, 2021	Jun. 30, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Sep. 30, 2021	Jul. 01, 2021	Jun. 24, 2021	May 31, 2021	Apr. 30, 2021	Apr. 01, 2021
Debt Instrument [Line Items]
Principal outstanding			$ 11,251	$ 14,835
Unamortized premium and (discount), net			(34)	(40)
Unamortized debt issuance costs			(77)	(106)
Total Long-term Debt			11,140	14,689
Less current portion of Long-term debt			474	1,074
Long-term Debt			10,666	13,615
Aggregate maturities of long-term debt (Details) [Abstract]
2022			474
2023			353
2024			650
2025			550
2026			904
Thereafter			8,320
Loss on Extinguishment of Debt			$ (395)	0	$ 0
Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Weighted-Average Rate			3.81%
Principal outstanding			$ 1,566	4,850
Senior Secured Notes - First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate			3.59%
Principal outstanding			$ 9,205	8,955
Junior Subordinated Notes [Member]
Debt Instrument [Line Items]
Weighted-Average Rate			2.89%
Principal outstanding			$ 480	930
Term Loan Credit Facility [Member]
Debt Instrument [Line Items]
Principal outstanding			0	100
First Mortgage Bonds [Member] | Tax Exempt Revenue Bonds [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate amount of tax-exempt revenue bonds in a term rate mode			782
Senior Notes [Member] | Senior Notes Due 2021 [Member] | Debt Instrument, Redemption, Period One [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 250
Stated interest rate	4.375%
PPL Capital Funding [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity			1,350
PPL Capital Funding [Member] | Term Loan Credit Facility [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity			0
PPL Capital Funding [Member] | Repayment | Term Loan Credit Facility [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount											$ 100
PPL Capital Funding [Member] | Repayment | Senior Notes due 2022 (4.20%)
Long-term Debt (Numeric) [Abstract]
Stated interest rate	4.20%	4.20%
PPL Capital Funding [Member] | Repayment | Senior Notes due 2022 (3.50%)
Long-term Debt (Numeric) [Abstract]
Stated interest rate	3.50%	3.50%
PPL Capital Funding [Member] | Repayment | Senior Notes due 2023
Long-term Debt (Numeric) [Abstract]
Stated interest rate	3.40%	3.40%
PPL Capital Funding [Member] | Repayment | Senior Notes due 2024
Long-term Debt (Numeric) [Abstract]
Stated interest rate	3.95%	3.95%
PPL Capital Funding [Member] | Repayment | Senior Notes due 2043
Long-term Debt (Numeric) [Abstract]
Stated interest rate		4.70%
PPL Capital Funding [Member] | Repayment | Senior Notes due 2044
Long-term Debt (Numeric) [Abstract]
Stated interest rate		5.00%
PPL Capital Funding [Member] | Repayment | Senior Notes due 2047
Long-term Debt (Numeric) [Abstract]
Stated interest rate		4.00%
PPL Capital Funding [Member] | Repayment | Senior Notes Due 2030 [Member]
Long-term Debt (Numeric) [Abstract]
Stated interest rate		4.125%
PPL Capital Funding [Member] | Repayment | Senior Notes due 2026
Long-term Debt (Numeric) [Abstract]
Stated interest rate		3.10%
PPL Capital Funding [Member] | Repayment | Senior Notes [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Extinguishment of Debt, Aggregate Purchase Price	$ 1,133	$ 1,000
Extinguishment of Debt, Amount	1,072	1,962
Loss on Extinguishment of Debt	(58)	(322)
PPL Capital Funding [Member] | Repayment | Senior Notes 2
Aggregate maturities of long-term debt (Details) [Abstract]
Extinguishment of Debt, Aggregate Purchase Price		$ 2,293
PPL Capital Funding [Member] | Repayment | Junior Subordinated Notes due 2073
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 450
Stated interest rate	5.90%
Aggregate maturities of long-term debt (Details) [Abstract]
Loss on Extinguishment of Debt	$ (15)
PPL Capital Funding [Member] | Senior Notes [Member] | Repayment
Aggregate maturities of long-term debt (Details) [Abstract]
Long-term Debt, Weighted Average Interest Rate, at Point in Time	3.71%	4.14%
PPL Electric [Member] | Senior Secured Notes - First Mortgage Bonds [Member] | Potential To Be Called Within One Year [Member]
Debt Instrument [Line Items]
Principal outstanding			650
PPL Electric [Member] | Senior Secured Notes - First Mortgage Bonds [Member] | Currently Able To Be Called
Debt Instrument [Line Items]
Principal outstanding			250
PPL Electric [Member] | Senior Secured Notes - First Mortgage Bonds [Member] | Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien			11,300	10,800
PPL Electric [Member] | Senior Secured Notes - First Mortgage Bonds [Member] | Pollution Control Revenue Refunding Bonds [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount that may be redeemed at a future date			224
Principal amount that may be redeemed in whole or in part			$ 90
Minimum length of time to convert interest rate mode			1 year
PPL Electric [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds, Floating Rate Series due 2024
Long-term Debt (Numeric) [Abstract]
Principal amount								$ 650
Aggregate maturities of long-term debt (Details) [Abstract]
Proceeds from Issuance of Debt		$ 647
PPL Electric [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds, 3% Series due 2021 | Redemption
Long-term Debt (Numeric) [Abstract]
Principal amount							$ 400
Stated interest rate							3.00%
LGE [Member] | Louisville/Jefferson County Metro Government of Kentucky Pollution Control Revenue Bonds, 2005 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount										$ 128
LGE [Member] | Trimble County Pollution Control Revenue Bonds, 2001 Series B | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount									$ 35
Stated interest rate									1.35%
LGE [Member] | Louisville/Jefferson County Metro Government Pollution Control Revenue Bonds, 2001 Series B | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount									$ 35
Stated interest rate									1.35%
LGE [Member] | Louisville/Jefferson County Metro Government of Kentucky Environmental Facilities Revenue Refunding Bonds, 2007 Series B | Conversion to Weekly Interest Rate
Long-term Debt (Numeric) [Abstract]
Principal amount		31
LGE [Member] | Louisville/Jefferson County Metro Government of Kentucky Environmental Revenue Refunding Bonds, 2007 Series B | Conversion to Weekly Interest Rate
Long-term Debt (Numeric) [Abstract]
Principal amount		35
LGE [Member] | Trimble County Pollution Control Revenue Bonds, 2001 Series A | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount						$ 28
Stated interest rate						0.625%
LGE [Member] | Louisville/Jefferson County Metro Government of Kentucky Pollution Control Revenue Bonds, 2003 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Stated interest rate										2.00%
LGE [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien			$ 5,700	5,500
LGE [Member] | First Mortgage Bonds [Member] | Tax Exempt Revenue Bonds [Member]
Long-term Debt (Numeric) [Abstract]
Minimum length of time to convert interest rate mode			1 year
Aggregate amount of tax-exempt revenue bonds in a variable rate mode			$ 66
LKE [Member] | Senior Notes [Member] | Senior Notes Due 2021 [Member] | Debt Instrument, Redemption, Period One [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 250
Stated interest rate	4.375%
KU [Member] | Carroll County of Kentucky Environmental Facilities Revenue Refunding Bonds, 2006 Series B | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount		$ 54
Stated interest rate		2.125%
KU [Member] | Carroll County of Kentucky Environmental Facilities Revenue Refunding Bonds, | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount		$ 78
Stated interest rate		2.00%
KU [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien			$ 6,900	6,700
KU [Member] | First Mortgage Bonds [Member] | Tax Exempt Revenue Bonds [Member]
Long-term Debt (Numeric) [Abstract]
Minimum length of time to convert interest rate mode			1 year
Aggregate amount of tax-exempt revenue bonds in a variable rate mode			$ 33
PPL Electric Utilities Corp [Member]
Debt Instrument [Line Items]
Principal outstanding			4,539	4,289
Unamortized discount			(22)	(23)
Unamortized debt issuance costs			(33)	(30)
Total Long-term Debt			4,484	4,236
Less current portion of Long-term debt			474	400
Long-term Debt			4,010	3,836
Aggregate maturities of long-term debt (Details) [Abstract]
2022			474
2023			340
2024			650
2025			0
2026			0
Thereafter			$ 3,075
PPL Electric Utilities Corp [Member] | Senior Secured Notes - First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate			3.37%
Principal outstanding			$ 4,539	4,289
PPL Electric Utilities Corp [Member] | Senior Secured Notes - First Mortgage Bonds [Member] | Potential To Be Called Within One Year [Member]
Debt Instrument [Line Items]
Principal outstanding			650
PPL Electric Utilities Corp [Member] | Senior Secured Notes - First Mortgage Bonds [Member] | Currently Able To Be Called
Debt Instrument [Line Items]
Principal outstanding			250
PPL Electric Utilities Corp [Member] | Senior Secured Notes - First Mortgage Bonds [Member] | Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien			11,300	10,800
PPL Electric Utilities Corp [Member] | Senior Secured Notes - First Mortgage Bonds [Member] | Pollution Control Revenue Refunding Bonds [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount that may be redeemed at a future date			224
Principal amount that may be redeemed in whole or in part			$ 90
Minimum length of time to convert interest rate mode			1 year
PPL Electric Utilities Corp [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds, Floating Rate Series due 2024
Long-term Debt (Numeric) [Abstract]
Principal amount								$ 650
Aggregate maturities of long-term debt (Details) [Abstract]
Proceeds from Issuance of Debt		$ 647
PPL Electric Utilities Corp [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds, 3% Series due 2021 | Redemption
Long-term Debt (Numeric) [Abstract]
Principal amount							$ 400
Stated interest rate							3.00%
Louisville Gas And Electric Co [Member]
Debt Instrument [Line Items]
Principal outstanding			$ 2,024	2,024
Unamortized discount			(4)	(4)
Unamortized debt issuance costs			(14)	(13)
Total Long-term Debt			2,006	2,007
Less current portion of Long-term debt			0	292
Long-term Debt			2,006	1,715
Aggregate maturities of long-term debt (Details) [Abstract]
2022			0
2023			0
2024			0
2025			300
2026			90
Thereafter			$ 1,634
Louisville Gas And Electric Co [Member] | Louisville/Jefferson County Metro Government of Kentucky Pollution Control Revenue Bonds, 2005 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount										$ 128
Louisville Gas And Electric Co [Member] | Trimble County Pollution Control Revenue Bonds, 2001 Series B | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount									$ 35
Stated interest rate									1.35%
Louisville Gas And Electric Co [Member] | Louisville/Jefferson County Metro Government Pollution Control Revenue Bonds, 2001 Series B | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount									$ 35
Stated interest rate									1.35%
Louisville Gas And Electric Co [Member] | Louisville/Jefferson County Metro Government of Kentucky Environmental Facilities Revenue Refunding Bonds, 2007 Series B | Conversion to Weekly Interest Rate
Long-term Debt (Numeric) [Abstract]
Principal amount		31
Louisville Gas And Electric Co [Member] | Louisville/Jefferson County Metro Government of Kentucky Environmental Revenue Refunding Bonds, 2007 Series B | Conversion to Weekly Interest Rate
Long-term Debt (Numeric) [Abstract]
Principal amount		35
Louisville Gas And Electric Co [Member] | Trimble County Pollution Control Revenue Bonds, 2001 Series A | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount						$ 28
Stated interest rate						0.625%
Louisville Gas And Electric Co [Member] | Louisville/Jefferson County Metro Government of Kentucky Pollution Control Revenue Bonds, 2003 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Stated interest rate										2.00%
Louisville Gas And Electric Co [Member] | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate			3.59%
Principal outstanding			$ 2,024	2,024
Louisville Gas And Electric Co [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien			$ 5,700	5,500
Louisville Gas And Electric Co [Member] | First Mortgage Bonds [Member] | Tax Exempt Revenue Bonds [Member]
Long-term Debt (Numeric) [Abstract]
Minimum length of time to convert interest rate mode			1 year
Aggregate amount of tax-exempt revenue bonds in a term rate mode			$ 473
Aggregate amount of tax-exempt revenue bonds in a variable rate mode			66
Kentucky Utilities Co [Member]
Debt Instrument [Line Items]
Principal outstanding			2,642	2,642
Debt Instrument, Unamortized Premium			5	5
Unamortized discount			(9)	(9)
Unamortized debt issuance costs			(20)	(20)
Total Long-term Debt			2,618	2,618
Less current portion of Long-term debt			0	132
Long-term Debt			2,618	2,486
Aggregate maturities of long-term debt (Details) [Abstract]
2022			0
2023			13
2024			0
2025			250
2026			164
Thereafter			$ 2,215
Kentucky Utilities Co [Member] | Carroll County of Kentucky Environmental Facilities Revenue Refunding Bonds, 2006 Series B | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount		$ 54
Stated interest rate		2.125%
Kentucky Utilities Co [Member] | Carroll County of Kentucky Environmental Facilities Revenue Refunding Bonds, | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount		$ 78
Stated interest rate		2.00%
Kentucky Utilities Co [Member] | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate			3.97%
Principal outstanding			$ 2,642	2,642
Kentucky Utilities Co [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien			$ 6,900	$ 6,700
Kentucky Utilities Co [Member] | First Mortgage Bonds [Member] | Tax Exempt Revenue Bonds [Member]
Long-term Debt (Numeric) [Abstract]
Minimum length of time to convert interest rate mode			1 year
Aggregate amount of tax-exempt revenue bonds in a term rate mode			$ 309
Aggregate amount of tax-exempt revenue bonds in a variable rate mode			$ 33

Financing Activities Financing

Financing Activities Financing Activities- Equity Securities (Details) - USD ($) shares in Thousands, $ in Millions		12 Months Ended
		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Aug. 01, 2021	Feb. 28, 2018
Equity Programs [Line Items]
Issuance of common stock		$ 9	$ 34	$ 1,167
Stock Repurchase Program, Authorized Amount					$ 3,000
Treasury Stock, Value, Acquired, Cost Method		$ 1,003
Common Stock [Member]
Equity Programs [Line Items]
Common stock shares issued	[1]	983	1,674	46,910
Treasury stock		(34,778)
Treasury Stock
Equity Programs [Line Items]
Treasury Stock, Value, Acquired, Cost Method		$ (1,003)
At The Market Stock Offering Program [Member]
Equity Programs [Line Items]
Common Stock Aggregate Sales Price						$ 1,000
Maximum Percentage Paid To Selling Agents		2.00%
Common stock shares issued		0	0
[1]	Shares in thousands. Each share entitles the holder to one vote on any question presented at any shareowners' meeting.

Financing Activities - Distribu

Financing Activities - Distributions and Capital Contributions (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended		12 Months Ended
	Feb. 28, 2022	Nov. 30, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Distributions [Line Items]
Current quarterly common stock dividend (in dollars per share)		$ 0.415	$ 1.66	$ 1.66	$ 1.65
Annualized current quarterly common stock dividend (in dollars per share)		$ 1.66
Deferred Interest Payment			$ 0
Subsequent Event [Member]
Distributions [Line Items]
Current quarterly common stock dividend (in dollars per share)	$ 0.20
Louisville Gas And Electric Co [Member]
Distributions [Line Items]
Restricted net assets at end of period			1,400
Unrestricted assets at the end of period			$ 1,700
Minimum adjusted equity to total capitalization in order to pay dividends			30.00%
Kentucky Utilities Co [Member]
Distributions [Line Items]
Restricted net assets at end of period			$ 1,900
Unrestricted assets at the end of period			$ 2,000
Minimum adjusted equity to total capitalization in order to pay dividends			30.00%

Acquisitions, Development and_3

Acquisitions, Development and Divestures (Details) $ in Millions	Mar. 31, 2022USD ($)	Jun. 30, 2021USD ($)	Jun. 30, 2021GBP (£)	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Jun. 14, 2021USD ($)
Development Projects [Abstract]
Income (Loss) from Discontinued Operations (net of income taxes)				$ (1,498)	$ 829	$ 1,010
Total current assets held for sale				0	18,983
Total current liabilities held for sale				0	11,023
Forecast [Member]
Development Projects [Abstract]
Payments to Acquire Businesses, Gross	$ 3,800
WPD [Member]
Development Projects [Abstract]
Income tax related to Discontinued Operations				759	188	226
WPD [Member] | Discontinued Operations, Held-for-sale
Development Projects [Abstract]
Loss on Sale				(1,609)	0	0
Operating Revenues related to discontinued operations				1,344	2,133	2,167
Operating Expense related to discontinued operations				467	916	853
Other Income (Expense) - net related to discontinued operations				202	167	295
Interest Expense related to discontinued operations				209	367	373
Income from Discontinued Operations, before Income Tax				870	1,017	1,236
Income tax related to Discontinued Operations				759	188	226
Income (Loss) from Discontinued Operations (net of income taxes)				$ (1,498)	829	$ 1,010
Cash and Cash Equivalents from Disposal Group					266
Accounts receivable and unbilled revenues from Disposal Group					389
Property, Plant and Equipment, net from Disposal Group					14,392
Other intangibles from Disposal Group					413
Price risk management assets from Disposal Group					146
Goodwill from Disposal Group					2,558
Pension benefit asset from Disposal Group					682
Other Assets from Disposal Group					137
Total current assets held for sale					18,983
Short-Term Debt and Long-Term Debt due within one year from Disposal Group					994
Accounts Payable from Disposal Group					220
Customer Deposits from Disposal Group					217
Accrued Interest from Disposal Group					190
Long-term Debt from Disposal Group					7,938
Total deferred income taxes from Disposal Group					1,032
Price risk management liabilities from Disposal Group					137
Other deferred credits and liabilities from Disposal Group					295
Total current liabilities held for sale					11,023
Net Assets from Disposal Group					7,960
Unrealized foreign currency hedge losses recognized in 2020					125
Costs to sell		$ 69
Carrying Value							$ 12,397
Sale proceeds, net of realized foreign currency hedge losses		10,732	£ 7,800,000,000
Proceeds from Daily Dividend, Divestiture of Business | £			548,000
Proceeds from Divestiture of Businesses, before Foreign Currency Hedge Losses | £			£ 7,881,000,000
Disposal Group, Including Discontinued Operation, Loss on Foreign Currency Hedge Against Sale or Disposition		386
Other Comprehensive (Income) Loss, Reclassification Adjustment from AOCI for Sale of Disposal Group, Net of Tax					$ 4,000		$ 3,600
Net Proceeds From Divestiture Of Businesses		$ 10,400

Leases - Lessee (Details)

Leases - Lessee (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Lease, Cost [Abstract]
Operating lease cost	$ 24	$ 28	$ 30
Short-term lease cost	6	7	5
Total lease cost	30	35	35
Operating cash flows from operating leases	23	24	26
Right-of-use asset obtained in exchange for new operating lease liabilities	12	17	45
Lessee, Operating Lease, Liability, Payment, Due [Abstract]
2022	23
2023	20
2024	15
2025	8
2026	3
Thereafter	5
Total	$ 74
Assets and Liabilities, Lessee [Abstract]
Weighted-average discount rate	3.38%
Weighted-average remaining lease term (in years)	4 years
Current lease liabilities	$ 22
Non-current lease liabilities	$ 47
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Other deferred credits and noncurrent liabilities
Operating Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other current liabilities
Other Noncurrent Assets [Member]
Assets and Liabilities, Lessee [Abstract]
Right-of-use assets	$ 62
Louisville Gas And Electric Co [Member]
Lease, Cost [Abstract]
Operating lease cost	6	8	12
Short-term lease cost	1	1	1
Total lease cost	7	9	13
Operating cash flows from operating leases	6	7	9
Right-of-use asset obtained in exchange for new operating lease liabilities	4	6	5
Lessee, Operating Lease, Liability, Payment, Due [Abstract]
2022	6
2023	5
2024	4
2025	3
2026	1
Thereafter	1
Total	$ 20
Assets and Liabilities, Lessee [Abstract]
Weighted-average discount rate	3.48%
Weighted-average remaining lease term (in years)	4 years
Current lease liabilities	$ 6
Non-current lease liabilities	$ 12
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Other deferred credits and noncurrent liabilities
Operating Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other current liabilities
Louisville Gas And Electric Co [Member] | Minimum [Member]
Lessee, Lease, Description [Line Items]
Lessee, Operating Lease, Renewal Term	1 year
Louisville Gas And Electric Co [Member] | Maximum [Member]
Lessee, Lease, Description [Line Items]
Lessee, Operating Lease, Renewal Term	10 years
Louisville Gas And Electric Co [Member] | Other Noncurrent Assets [Member]
Assets and Liabilities, Lessee [Abstract]
Right-of-use assets	$ 15
Kentucky Utilities Co [Member]
Lease, Cost [Abstract]
Operating lease cost	10	13	13
Short-term lease cost	1	1	1
Total lease cost	11	14	14
Operating cash flows from operating leases	10	11	11
Right-of-use asset obtained in exchange for new operating lease liabilities	7	$ 9	$ 11
Lessee, Operating Lease, Liability, Payment, Due [Abstract]
2022	10
2023	8
2024	6
2025	4
2026	1
Thereafter	1
Total	$ 30
Assets and Liabilities, Lessee [Abstract]
Weighted-average discount rate	3.67%
Weighted-average remaining lease term (in years)	4 years
Current lease liabilities	$ 9
Non-current lease liabilities	$ 17
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Other deferred credits and noncurrent liabilities
Operating Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other current liabilities
Kentucky Utilities Co [Member] | Minimum [Member]
Lessee, Lease, Description [Line Items]
Lessee, Operating Lease, Renewal Term	1 year
Kentucky Utilities Co [Member] | Maximum [Member]
Lessee, Lease, Description [Line Items]
Lessee, Operating Lease, Renewal Term	10 years
Kentucky Utilities Co [Member] | Other Noncurrent Assets [Member]
Assets and Liabilities, Lessee [Abstract]
Right-of-use assets	$ 24

Leases Leases - Lessor (Details

Leases Leases - Lessor (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Lessor, Lease, Description [Line Items]
Lease income recognized	$ 11	$ 16	$ 14
Louisville Gas And Electric Co [Member]
Lessor, Lease, Description [Line Items]
Lease income recognized	5	6	5
Kentucky Utilities Co [Member]
Lessor, Lease, Description [Line Items]
Lease income recognized	$ 5	$ 9	$ 8

Stock-Based Compensation (Detai

Stock-Based Compensation (Details)	12 Months Ended
	Dec. 31, 2021USD ($)Integer$ / sharesshares	Dec. 31, 2020USD ($)$ / sharesshares	Dec. 31, 2019USD ($)$ / sharesshares
All Plans [Member] | Restricted Shares And Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested, beginning of period (in shares)	896,336
Granted (in shares)	458,610
Vested (in shares)	(303,890)
Forfeited (in shares)	(46,473)
Nonvested, end of period (in shares)	1,004,583	896,336
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares	$ 32.56
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	28	$ 35.30	$ 31.95
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	30.57
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	30.23
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 31.19	$ 32.56
Total fair value of units vested during the period | $	$ 8,000,000	$ 19,000,000	$ 13,000,000
Fair value assumptions and methodology [Abstract]
Award vesting period (in years)	3 years
All Plans [Member] | Total Shareowner Return Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested, beginning of period (in shares)	626,254
Granted (in shares)	306,009
Vested (in shares)	(53,340)	0	0
Forfeited (in shares)	(245,150)
Nonvested, end of period (in shares)	633,773	626,254
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares	$ 36.98
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	32.44	$ 37.63	$ 35.83
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	34.47
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	37.75
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 34.68	$ 36.98
Total fair value of units vested during the period | $	$ 2,000,000
Period over which performance units fair value is recognized (in years)	3 years
Maximum payout percentage of target award	200.00%
Fair value assumptions and methodology [Abstract]
Expected option life (in years)	3 years	3 years	3 years
Expected stock volatility	27.81%	15.64%	17.57%
All Plans [Member] | Total Shareowner Return Performance Units [Member] | Retirement Eligible [Member]
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Period over which performance units fair value is recognized (in years)	1 year
All Plans [Member] | Total Shareowner Return Performance Units [Member] | Not Retirement Eligible [Member]
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Period over which performance units fair value is recognized (in years)	3 years
Minimum period after which employee stock options become exercisable (in years)	1 year
All Plans [Member] | Return On Equity Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested, beginning of period (in shares)	728,664
Granted (in shares)	572,571
Vested (in shares)	(570,722)
Forfeited (in shares)	(8,160)
Nonvested, end of period (in shares)	722,353	728,664
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares	$ 32.81
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	30.08	$ 34.95	$ 30.89
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	32.02
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	30.44
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 31.28	$ 32.81
Total fair value of units vested during the period | $	$ 16,000,000	$ 8,000,000
Period over which performance units fair value is recognized (in years)	3 years
Maximum payout percentage of target award	200.00%
All Plans [Member] | Stock Options [Member]
Stock option activity [Roll Forward]
Outstanding at beginning of period (in shares)	1,103,016
Exercised (in shares)	(337,014)
Weighted average remaining contractual term (in years)	1 year
Outstanding at end of period (in shares)	766,002	1,103,016
Stock options - additional disclosures [Abstract]
Period after which, employee stock options expire (in years)	10 years
Weighted-average exercise price per share at beginning of period (in dollars per share) | $ / shares	$ 26.22
Weighted average exercise price per share, exercised (in dollars per share) | $ / shares	25.42
Weighted average exercise price per share at end of period (in dollars per share) | $ / shares	$ 26.57	$ 26.22
Aggregate total intrinsic value | $	$ 3,000,000
Cash received from exercise of stock options | $	10,000,000	$ 8,000,000	$ 53,000,000
Total intrinsic value of stock options exercised | $			11,000,000
All Plans [Member] | All Awards [Member]
Aggregate disclosures [Abstract]
Compensation expense | $	34,000,000	28,000,000	35,000,000
Income tax benefit | $	10,000,000	$ 8,000,000	$ 10,000,000
Unrecognized compensation expense | $	$ 19,000,000
Weighted-average period for recognition | Integer	1.7
Stock Incentive Plan [Member]
Stock-Based Compensation [Line Items]
Maximum number of shares approved for awards under the plan (in shares)	15,000,000
Annual grant limit options (in shares)	2,000,000
Annual grant limit for individual participants - performance based awards (in shares)	750,000
Annual grant limit for individual participants - performance based awards | $	$ 15,000,000
Incentive Compensation Plan For Key Employees [Member]
Stock-Based Compensation [Line Items]
Maximum number of shares approved for awards under the plan (in shares)	14,199,796
Annual grant limit total as % of PPL outstanding PPL common stock on first day of each calendar year	2.00%
Annual grant limit options (in shares)	3,000,000
PPL Electric Utilities Corp [Member] | All Plans [Member] | Restricted Shares And Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested, beginning of period (in shares)	210,720
Transfer between registrants	(92,596)
Granted (in shares)	51,587
Vested (in shares)	(32,266)
Forfeited (in shares)	(6,158)
Nonvested, end of period (in shares)	131,287	210,720
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares	$ 32.73
Weighted-average grant date fair value per share, transfer between registrants (in dollars per share) | $ / shares	32.99
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	27.96	$ 35.37	$ 32.33
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	29.98
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	32.16
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 31.50	$ 32.73
Total fair value of units vested during the period | $	$ 1,000,000	$ 3,000,000	$ 2,000,000
Fair value assumptions and methodology [Abstract]
Award vesting period (in years)	3 years
PPL Electric Utilities Corp [Member] | All Plans [Member] | Total Shareowner Return Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested, beginning of period (in shares)	61,807
Transfer between registrants	(53,663)
Granted (in shares)	10,010
Forfeited (in shares)	(2,800)
Nonvested, end of period (in shares)	15,354	61,807
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares	$ 37.44
Weighted-average grant date fair value per share, transfer between registrants (in dollars per share) | $ / shares	37.42
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	32.92	$ 38.64	$ 35.68
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	38.47
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 34.36	$ 37.44
Period over which performance units fair value is recognized (in years)	3 years
Maximum payout percentage of target award	200.00%
PPL Electric Utilities Corp [Member] | All Plans [Member] | Total Shareowner Return Performance Units [Member] | Retirement Eligible [Member]
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Period over which performance units fair value is recognized (in years)	1 year
PPL Electric Utilities Corp [Member] | All Plans [Member] | Total Shareowner Return Performance Units [Member] | Not Retirement Eligible [Member]
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Period over which performance units fair value is recognized (in years)	3 years
Minimum period after which employee stock options become exercisable (in years)	1 year
PPL Electric Utilities Corp [Member] | All Plans [Member] | Return On Equity Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested, beginning of period (in shares)	61,807
Transfer between registrants	(53,663)
Granted (in shares)	12,895
Vested (in shares)	(5,685)
Nonvested, end of period (in shares)	15,354	61,807
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares	$ 33.01
Weighted-average grant date fair value per share, transfer between registrants (in dollars per share) | $ / shares	33
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	29.39	$ 35.59	$ 30.76
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	32.27
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 30.27	$ 33.01
Total fair value of units vested during the period | $	$ 0	$ 1,000,000
Period over which performance units fair value is recognized (in years)	3 years
Maximum payout percentage of target award	200.00%
PPL Electric Utilities Corp [Member] | All Plans [Member] | Performance Units [Member]
Fair value assumptions and methodology [Abstract]
Expected option life (in years)	3 years	3 years	3 years
Expected stock volatility	27.81%	15.64%	17.57%
PPL Electric Utilities Corp [Member] | All Plans [Member] | Stock Options [Member]
Stock options - additional disclosures [Abstract]
Period after which, employee stock options expire (in years)	10 years
PPL Electric Utilities Corp [Member] | All Plans [Member] | All Awards [Member]
Aggregate disclosures [Abstract]
Compensation expense | $	$ 11,000,000	$ 10,000,000	$ 12,000,000
Income tax benefit | $	3,000,000	$ 3,000,000	$ 3,000,000
Unrecognized compensation expense | $	$ 2,000,000
Weighted-average period for recognition | Integer	1.8
PPL Electric Utilities Corp [Member] | Stock Incentive Plan [Member]
Stock-Based Compensation [Line Items]
Maximum number of shares approved for awards under the plan (in shares)	15,000,000
Annual grant limit options (in shares)	2,000,000
Annual grant limit for individual participants - performance based awards (in shares)	750,000
Annual grant limit for individual participants - performance based awards | $	$ 15,000,000
PPL Electric Utilities Corp [Member] | Incentive Compensation Plan For Key Employees [Member]
Stock-Based Compensation [Line Items]
Maximum number of shares approved for awards under the plan (in shares)	14,199,796
Annual grant limit total as % of PPL outstanding PPL common stock on first day of each calendar year	2.00%
Annual grant limit options (in shares)	3,000,000

Retirement and Postemployment_3

Retirement and Postemployment Benefits (Net Period Defined Benefit Costs (Credits) and Other Changes in Plan Assets and Benefit Obligations) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Pension Plan [Member] | U.S. [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost	$ 56	$ 56	$ 50
Interest cost	121	146	164
Expected return on plan assets	(255)	(246)	(245)
Amortization of:
Prior service cost (credit)	8	9	8
Actuarial (gain) loss	93	89	56
Net periodic defined benefit costs (credits) prior to settlements and termination benefits	23	54	33
Settlements	18	23	1
Net Periodic Defined Benefit Costs (Credits)	41	77	34
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Settlement	(18)	(23)	(1)
Net (gain) loss	42	(221)	(121)
Prior service costs (credit)	3	1	2
Amortization of: [Abstract]
Prior service (cost) credit	(8)	(9)	(8)
Actuarial gain (loss)	(93)	(89)	(56)
Total recognized in OCI and regulatory assets/liabilities	(74)	(341)	(184)
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	(33)	(264)	(150)
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
OCI	(70)	(428)	(194)
Regulatory assets/liabilities	(4)	87	10
Total recognized in OCI and regulatory assets/liabilities	(74)	(341)	(184)
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts	12	40	18
Other Postretirement Benefits Plan [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost	6	6	6
Interest cost	16	19	22
Expected return on plan assets	(23)	(21)	(18)
Amortization of:
Prior service cost (credit)	1	1	(1)
Actuarial (gain) loss	(1)	0	1
Net periodic defined benefit costs (credits) prior to settlements and termination benefits	(1)	5	10
Settlements	0	0	0
Net Periodic Defined Benefit Costs (Credits)	(1)	5	10
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Settlement	0	0	0
Net (gain) loss	(53)	(6)	(18)
Prior service costs (credit)	0	5	0
Amortization of: [Abstract]
Prior service (cost) credit	(1)	(1)	1
Actuarial gain (loss)	1	0	(1)
Total recognized in OCI and regulatory assets/liabilities	(53)	(2)	(18)
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	(54)	3	(8)
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
OCI	(42)	(12)	(13)
Regulatory assets/liabilities	(11)	10	(5)
Total recognized in OCI and regulatory assets/liabilities	(53)	(2)	(18)
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts	(1)	4	8
PPL Electric Utilities Corp [Member] | Pension Plan [Member] | U.S. [Member]
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts	(9)	(2)	(4)
PPL Electric Utilities Corp [Member] | Other Postretirement Benefits Plan [Member]
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts	$ (1)	$ 2	4
Louisville Gas And Electric Co [Member] | Pension Plan [Member]
Amortization of:
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period			3
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period			3
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | U.S. [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost			1
Interest cost			11
Expected return on plan assets			(21)
Amortization of:
Prior service cost (credit)			5
Actuarial (gain) loss			9
Net Periodic Defined Benefit Costs (Credits)			$ 5
Amortization period for the deferred recovery of a regulatory asset	15 years	15 years	15 years
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		$ (3)	$ (2)
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Net (gain) loss			(19)
Amortization of: [Abstract]
Prior service (cost) credit			(5)
Actuarial gain (loss)			(9)
Total recognized in OCI and regulatory assets/liabilities			(33)
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities			(28)
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
Total recognized in OCI and regulatory assets/liabilities			(33)
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts	$ (1)	$ 4	$ 3
Amortization period for the deferred recovery of a regulatory asset	15 years	15 years	15 years
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		$ (3)	$ (2)
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | U.S. [Member] | Qualified Plan [Member]
Amortization of:
Settlements			$ 5
Louisville Gas And Electric Co [Member] | Other Postretirement Benefits Plan [Member]
Amortization of:
Amortization period for the deferred recovery of a regulatory asset	15 years	15 years	15 years
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		$ (3)	$ (2)
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts	$ 2	$ 2	$ 2
Amortization period for the deferred recovery of a regulatory asset	15 years	15 years	15 years
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		$ (3)	$ (2)
Kentucky Utilities Co [Member] | Pension Plan [Member] | U.S. [Member]
Amortization of:
Amortization period for the deferred recovery of a regulatory asset	15 years	15 years	15 years
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		$ (1)	$ (1)
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts	$ (3)	$ 1	$ (1)
Amortization period for the deferred recovery of a regulatory asset	15 years	15 years	15 years
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		$ (1)	$ (1)
Kentucky Utilities Co [Member] | Other Postretirement Benefits Plan [Member]
Amortization of:
Amortization period for the deferred recovery of a regulatory asset	15 years	15 years	15 years
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		$ (1)	$ (1)
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts	$ 0	$ 0	$ 0
Amortization period for the deferred recovery of a regulatory asset	15 years	15 years	15 years
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		$ (1)	$ (1)

Retirement and Postemployment_4

Retirement and Postemployment Benefits (Weighted-Average Assumptions, Cost Trend Rates and Funded Status) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Pension Plan [Member] | U.S. [Member]
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]
Benefit obligations valuation discount rate	3.15%	2.92%
Benefit obligations valuation rate of compensation increase	3.76%	3.76%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate	2.92%	3.64%	4.35%
Net periodic benefit costs rate of compensation increase	3.76%	3.79%	3.79%
Net periodic benefit costs expected return on plan assets	7.25%	7.25%	7.25%
Assumed Health Care Cost Trend Rates (Details) [Abstract]
Health care cost trend rate assumed for next year, obligations	6.25%	6.50%	6.60%
Health care cost trend rate assumed for next year, cost	6.50%	6.60%	6.60%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate), obligations	5.00%	5.00%	5.00%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate), cost	5.00%	5.00%	5.00%
Year that the rate reaches the ultimate trend rate, obligations	2027	2027	2024
Year that the rate reaches the ultimate trend rate, cost	2027	2024	2023
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period	$ 4,251	$ 4,146
Service cost	56	56	$ 50
Interest cost	121	146	164
Participant contributions	0	0
Plan Amendments	2	2
Actuarial (gain) loss	(88)	256
Settlements	(106)	(114)
Gross benefits paid	(247)	(241)
Benefit Obligation, end of period	3,989	4,251	4,146
Change in Plan Assets [Roll Forward]
Balance at beginning of period	4,068	3,585
Actual return on plan assets	125	723
Employer contributions	47	115
Participant contributions	0	0
Settlements	(106)	(114)
Gross benefits paid	(247)	(241)
Balance at end of period	3,887	4,068	$ 3,585
Funded Status, end of period	(102)	(183)
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	91	24
Current liability	(10)	(18)
Noncurrent liability	(183)	(189)
Net amount recognized, end of period	(102)	(183)
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)	22	27
Net actuarial (gain) loss	626	695
Total	648	722
Total accumulated benefit obligation for defined benefit pension plans	3,786	4,024
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
AOCI	239	270
Regulatory assets/liabilities	409	452
Total	648	722
Pension Plans Where the Projected or Accumulated Benefit Obligation Exceed the Fair Value of Plan Assets (Details) [Abstract]
Projected benefit obligations	193	1,875
Fair value of plan assets where the projected benefit obligations exceed the value of plan assets	0	1,668
Accumulated benefit obligation	177	184
Fair value of plan assets where the accumulated benefit obligations exceed the value of plan assets	$ 0	$ 0
Other Postretirement Benefits Plan [Member]
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]
Benefit obligations valuation discount rate	3.13%	2.84%
Benefit obligations valuation rate of compensation increase	3.77%	3.75%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate	2.84%	3.60%	4.31%
Net periodic benefit costs rate of compensation increase	3.75%	3.76%	3.76%
Net periodic benefit costs expected return on plan assets	6.48%	6.44%	6.46%
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period	$ 573	$ 557
Service cost	6	6	$ 6
Interest cost	16	19	22
Participant contributions	14	15
Plan Amendments	0	5
Actuarial (gain) loss	(50)	29
Settlements	0	0
Gross benefits paid	(55)	(58)
Benefit Obligation, end of period	504	573	557
Change in Plan Assets [Roll Forward]
Balance at beginning of period	367	340
Actual return on plan assets	25	56
Employer contributions	18	18
Participant contributions	11	11
Settlements	0	0
Gross benefits paid	(54)	(58)
Balance at end of period	367	367	$ 340
Funded Status, end of period	(137)	(206)
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	0	0
Current liability	(15)	(22)
Noncurrent liability	(122)	(184)
Net amount recognized, end of period	(137)	(206)
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)	12	14
Net actuarial (gain) loss	(51)	0
Total	(39)	14
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
AOCI	(2)	10
Regulatory assets/liabilities	(37)	4
Total	(39)	14
PPL Electric Utilities Corp [Member]
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	50	12
PPL Electric Utilities Corp [Member] | Pension Plan [Member] | U.S. [Member] | PPL Services Funded Status Allocation [Member]
Change in Plan Assets [Roll Forward]
Funded Status, end of period	42	4
PPL Electric Utilities Corp [Member] | Other Postretirement Benefits Plan [Member] | PPL Services Funded Status Allocation [Member]
Change in Plan Assets [Roll Forward]
Funded Status, end of period	$ (78)	$ (99)
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | U.S. [Member]
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate	0.00%	0.00%	4.33%
Net periodic benefit costs expected return on plan assets	0.00%	0.00%	7.25%
Change in Benefit Obligation [Roll Forward]
Service cost			$ 1
Interest cost			$ 11
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | U.S. [Member] | LKE Funded Status Allocation [Member]
Change in Plan Assets [Roll Forward]
Funded Status, end of period	$ 85	$ 78
Louisville Gas And Electric Co [Member] | Other Postretirement Benefits Plan [Member] | LKE Funded Status Allocation [Member]
Change in Plan Assets [Roll Forward]
Funded Status, end of period	(51)	(68)
Kentucky Utilities Co [Member] | Pension Plan [Member] | U.S. [Member] | LKE Funded Status Allocation [Member]
Change in Plan Assets [Roll Forward]
Funded Status, end of period	75	62
Kentucky Utilities Co [Member] | Other Postretirement Benefits Plan [Member] | LKE Funded Status Allocation [Member]
Change in Plan Assets [Roll Forward]
Funded Status, end of period	$ (6)	$ (16)

Retirement and Postemployment_5

Retirement and Postemployment Benefits (Plan Assets and Expected Cash Flows) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Pension Plan [Member] | U.S. [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	$ 3,887	$ 4,068
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	4,068	3,585
Balance at end of period	3,887	4,068
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions	47	$ 115
Expected amount of benefit payments in the next period for non-qualified plans	10
Estimated Future Benefit Payments (Details) [Abstract]
2022	207
2023	207
2024	204
2025	204
2026	202
2027-2030	$ 946
Pension Plan [Member] | U.S. [Member] | Master Trust [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	100.00%	100.00%
Target Allocations (Details ) [Abstract]
Target asset allocation	100.00%
Assumptions Used in Calculations (Numeric) [Abstract]
The limited lives of four partnership of private equity investments (in years)	10 years
The amount of potential liability that maybe required to be funded by the master trust during life of the partnership	$ 111
Number Of Days Notice Required To Redeem Shares	45 days
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	$ 3,887	$ 4,068
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	4,068
Balance at end of period	$ 3,887	$ 4,068
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | LKE [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	100.00%	100.00%
Target Allocations (Details ) [Abstract]
Target asset allocation	100.00%
Assumptions Used in Calculations (Numeric) [Abstract]
The limited lives of four partnership of private equity investments (in years)	10 years
The amount of potential liability that maybe required to be funded by the master trust during life of the partnership	$ 111
Number Of Days Notice Required To Redeem Shares	45 days
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	$ 3,887	$ 4,068
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	4,068
Balance at end of period	3,887	4,068
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	587	695
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	695
Balance at end of period	587	695
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Level 1 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	587	695
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	695
Balance at end of period	587	695
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	1,069	1,007
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	1,007
Balance at end of period	1,069	1,007
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Level 2 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	1,069	1,007
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	1,007
Balance at end of period	1,069	1,007
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	20	15
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	15	24
Purchases, sales and settlements	5	(9)
Balance at end of period	20	15
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Level 3 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	20	15
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	15	24
Purchases, sales and settlements	5	(9)
Balance at end of period	20	15
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	266	300
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	266	300
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	266	300
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member] | Level 1 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	266	300
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member] | Level 2 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member] | Level 3 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	754	742
Measured at fair value not using net asset value per share	41	60
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Equity Securities [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	754	742
Measured at fair value not using net asset value per share	41	60
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Equity Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	41	60
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Equity Securities [Member] | Level 1 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	41	60
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Equity Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Equity Securities [Member] | Level 2 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Equity Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Equity Securities [Member] | Level 3 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | International Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	511	566
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | International Equity Securities [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	511	566
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Commingled Debt Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	677	712
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Commingled Debt Equity Securities [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	677	712
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	281	336
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	281	336
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	280	335
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 1 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	280	335
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	1	1
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 2 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	1	1
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 3 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Corporate Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	1,039	1,045
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	1,039	1,045
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 1 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	1,019	1,030
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 2 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	1,019	1,030
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	20	15
Fair value at end of period	20	15
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	15	20
Purchases, sales and settlements	5	(5)
Balance at end of period	20	15
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 3 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	20	15
Fair value at end of period	20	15
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	15	20
Purchases, sales and settlements	5	(5)
Balance at end of period	20	15
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Other Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	14	13
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Other Debt Securities [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	14	13
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Other Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Other Debt Securities [Member] | Level 1 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Other Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	14	13
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Other Debt Securities [Member] | Level 2 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	14	13
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Other Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Other Debt Securities [Member] | Level 3 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Real Estate Alternative Investments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	69	76
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Real Estate Alternative Investments [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	69	76
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Total Trust Assets Prior to Adjustments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	4,017	4,110
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	4,110
Balance at end of period	4,017	4,110
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Total Trust Assets Prior to Adjustments [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	4,017	4,110
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	4,110
Balance at end of period	4,017	4,110
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Private Equity Alternative Investments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	94	68
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Private Equity Alternative Investments [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	94	68
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Hedge Fund Of Funds Alternative Investments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	236	223
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Hedge Fund Of Funds Alternative Investments [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	236	223
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Derivatives [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	35	(37)
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Derivatives [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	35	(37)
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Derivatives [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Derivatives [Member] | Level 1 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Derivatives [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	35	(37)
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Derivatives [Member] | Level 2 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	35	(37)
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Derivatives [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Derivatives [Member] | Level 3 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Insurance Contracts [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		0
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	0	4
Purchases, sales and settlements		(4)
Balance at end of period		0
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Insurance Contracts [Member] | Level 3 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period		0
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	0	4
Purchases, sales and settlements		(4)
Balance at end of period		0
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Receivables And Payables Net [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	25	116
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	116
Balance at end of period	25	116
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Receivables And Payables Net [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	25	116
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	116
Balance at end of period	25	116
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Account 401 H [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	(155)	(158)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	(158)
Balance at end of period	(155)	(158)
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Account 401 H [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	(155)	(158)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	(158)
Balance at end of period	(155)	(158)
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Limited Partner
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	0	6
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Limited Partner | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	$ 0	$ 6
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Growth Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	55.00%	56.00%
Target Allocations (Details ) [Abstract]
Target asset allocation	55.00%
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Growth Portfolio [Member] | LKE [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	55.00%	56.00%
Target Allocations (Details ) [Abstract]
Target asset allocation	55.00%
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Growth Portfolio [Member] | Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	32.00%	34.00%
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Growth Portfolio [Member] | Equity Securities [Member] | LKE [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	32.00%	34.00%
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Growth Portfolio [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	13.00%	13.00%
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Growth Portfolio [Member] | Debt Securities [Member] | LKE [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	13.00%	13.00%
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Growth Portfolio [Member] | Alternative Investments [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	10.00%	9.00%
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Growth Portfolio [Member] | Alternative Investments [Member] | LKE [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	10.00%	9.00%
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Immunizing Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	43.00%	43.00%
Target Allocations (Details ) [Abstract]
Target asset allocation	43.00%
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Immunizing Portfolio [Member] | LKE [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	43.00%	43.00%
Target Allocations (Details ) [Abstract]
Target asset allocation	43.00%
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Immunizing Portfolio [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	35.00%	33.00%
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Immunizing Portfolio [Member] | Debt Securities [Member] | LKE [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	35.00%	33.00%
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Immunizing Portfolio [Member] | Derivatives [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	8.00%	10.00%
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Immunizing Portfolio [Member] | Derivatives [Member] | LKE [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	8.00%	10.00%
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Liquidity Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	2.00%	1.00%
Target Allocations (Details ) [Abstract]
Target asset allocation	2.00%
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Liquidity Portfolio [Member] | LKE [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	2.00%	1.00%
Target Allocations (Details ) [Abstract]
Target asset allocation	2.00%
Other Postretirement Benefits Plan [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	100.00%	100.00%
Target Allocations (Details ) [Abstract]
Target asset allocation	100.00%
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	$ 367	$ 367
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	367	340
Balance at end of period	367	367
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions	18	18
Amount to be contributed to plan in the next fiscal year	22
Estimated Future Benefit Payments (Details) [Abstract]
2022	44
2023	42
2024	41
2025	40
2026	38
2027-2030	176
Expected Federal Subsidy (Details) [Abstract]
Federal subsidy 2022	1
Federal subsidy 2023	0
Federal subsidy 2024	0
Federal subsidy 2025	0
Federal subsidy 2026	0
Federal subsidy 2027-2030	1
Other Postretirement Benefits Plan [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	6	5
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	5
Balance at end of period	6	5
Other Postretirement Benefits Plan [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	38	39
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	39
Balance at end of period	38	39
Other Postretirement Benefits Plan [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	0	0
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	0
Balance at end of period	$ 0	$ 0
Other Postretirement Benefits Plan [Member] | Cash And Cash Equivalents [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	3.00%	3.00%
Target Allocations (Details ) [Abstract]
Target asset allocation	5.00%
Other Postretirement Benefits Plan [Member] | Money Market Funds [Member]
Assumptions Used in Calculations (Numeric) [Abstract]
Number of months from date of purchase that investment must mature	13 months
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	$ 6	$ 5
Other Postretirement Benefits Plan [Member] | Money Market Funds [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	6	5
Other Postretirement Benefits Plan [Member] | Money Market Funds [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Other Postretirement Benefits Plan [Member] | Money Market Funds [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	$ 0	$ 0
Other Postretirement Benefits Plan [Member] | Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	45.00%	42.00%
Target Allocations (Details ) [Abstract]
Target asset allocation	45.00%
Other Postretirement Benefits Plan [Member] | United States Large Cap Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	$ 96	$ 89
Other Postretirement Benefits Plan [Member] | Commingled Debt Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	$ 75	$ 77
Other Postretirement Benefits Plan [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	52.00%	55.00%
Target Allocations (Details ) [Abstract]
Target asset allocation	50.00%
Other Postretirement Benefits Plan [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	$ 0	$ 2
Other Postretirement Benefits Plan [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Other Postretirement Benefits Plan [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	2
Other Postretirement Benefits Plan [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Other Postretirement Benefits Plan [Member] | Corporate Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	38	37
Other Postretirement Benefits Plan [Member] | Corporate Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Other Postretirement Benefits Plan [Member] | Corporate Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	38	37
Other Postretirement Benefits Plan [Member] | Corporate Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Other Postretirement Benefits Plan [Member] | Total Trust Assets Prior to Adjustments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	215	210
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	210
Balance at end of period	215	210
Other Postretirement Benefits Plan [Member] | Receivables And Payables Net [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	(3)	(1)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	(1)
Balance at end of period	(3)	(1)
Other Postretirement Benefits Plan [Member] | Account 401 H [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	155	158
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	158
Balance at end of period	$ 155	$ 158

Retirement and Postemployment_6

Retirement and Postemployment Benefits (Savings Plans and Employee Stock Ownership Plan) (Details) - Deferred Savings Plans 401K [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	$ 29	$ 29	$ 30
PPL Electric Utilities Corp [Member]
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	5	6	6
Louisville Gas And Electric Co [Member]
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	7	6	6
Kentucky Utilities Co [Member]
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	$ 5	$ 5	$ 5

Jointly Owned Facilities (Detai

Jointly Owned Facilities (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Trimble County Unit 1 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	75.00%	75.00%
Electric plant	$ 457	$ 440
Accumulated depreciation	79	64
Construction work in progress	$ 0	$ 2
Trimble County Unit 2 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	75.00%	75.00%
Electric plant	$ 1,360	$ 1,340
Accumulated depreciation	247	227
Construction work in progress	$ 121	$ 106
Louisville Gas And Electric Co [Member] | E W Brown Units 6 And 7 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	38.00%	38.00%
Electric plant	$ 53	$ 46
Accumulated depreciation	24	22
Construction work in progress	$ 0	$ 0
Louisville Gas And Electric Co [Member] | Paddys Run Unit 13 And E W Brown Unit 5 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	53.00%	53.00%
Electric plant	$ 51	$ 51
Accumulated depreciation	25	22
Construction work in progress	$ 0	$ 0
Louisville Gas And Electric Co [Member] | Trimble County Unit 1 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	75.00%	75.00%
Electric plant	$ 457	$ 440
Accumulated depreciation	79	64
Construction work in progress	$ 0	$ 2
Louisville Gas And Electric Co [Member] | Trimble County Unit 2 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	14.25%	14.25%
Electric plant	$ 379	$ 370
Accumulated depreciation	57	51
Construction work in progress	$ 64	$ 54
Louisville Gas And Electric Co [Member] | Trimble County Units 5 And 6 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	29.00%	29.00%
Electric plant	$ 36	$ 33
Accumulated depreciation	15	14
Construction work in progress	$ 0	$ 1
Louisville Gas And Electric Co [Member] | Trimble County Units 7 Through 10 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	37.00%	37.00%
Electric plant	$ 81	$ 77
Accumulated depreciation	34	31
Construction work in progress	$ 0	$ 1
Louisville Gas And Electric Co [Member] | Cane Run Unit 7 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	22.00%	22.00%
Electric plant	$ 125	$ 123
Accumulated depreciation	19	15
Construction work in progress	$ 0	$ 0
Louisville Gas And Electric Co [Member] | E W Brown Solar Unit [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	39.00%	39.00%
Electric plant	$ 10	$ 10
Accumulated depreciation	2	2
Construction work in progress	$ 0	$ 0
Louisville Gas And Electric Co [Member] | Jointly Owned Solar Share [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	44.00%	44.00%
Electric plant	$ 2	$ 2
Accumulated depreciation	0	0
Construction work in progress	$ 0	$ 0
Kentucky Utilities Co [Member] | E W Brown Units 6 And 7 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	62.00%	62.00%
Electric plant	$ 88	$ 76
Accumulated depreciation	40	37
Construction work in progress	$ 0	$ 0
Kentucky Utilities Co [Member] | Paddys Run Unit 13 And E W Brown Unit 5 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	47.00%	47.00%
Electric plant	$ 45	$ 45
Accumulated depreciation	22	20
Construction work in progress	$ 0	$ 0
Kentucky Utilities Co [Member] | Trimble County Unit 2 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	60.75%	60.75%
Electric plant	$ 981	$ 970
Accumulated depreciation	190	176
Construction work in progress	$ 57	$ 52
Kentucky Utilities Co [Member] | Trimble County Units 5 And 6 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	71.00%	71.00%
Electric plant	$ 84	$ 77
Accumulated depreciation	36	33
Construction work in progress	$ 0	$ 4
Kentucky Utilities Co [Member] | Trimble County Units 7 Through 10 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	63.00%	63.00%
Electric plant	$ 133	$ 129
Accumulated depreciation	57	53
Construction work in progress	$ 0	$ 2
Kentucky Utilities Co [Member] | Cane Run Unit 7 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	78.00%	78.00%
Electric plant	$ 444	$ 443
Accumulated depreciation	70	57
Construction work in progress	$ 0	$ 2
Kentucky Utilities Co [Member] | E W Brown Solar Unit [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	61.00%	61.00%
Electric plant	$ 16	$ 16
Accumulated depreciation	4	3
Construction work in progress	$ 0	$ 0
Kentucky Utilities Co [Member] | Jointly Owned Solar Share [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	56.00%	56.00%
Electric plant	$ 3	$ 2
Accumulated depreciation	0	0
Construction work in progress	$ 0	$ 0

Commitments and Contingencies_2

Commitments and Contingencies (Energy Purchases, Energy Sales, Other Commitments and Legal Matters) (Details) $ in Millions	1 Months Ended			12 Months Ended
	Jun. 30, 2017mi	Jul. 31, 2014claim	Dec. 31, 2013resident	Dec. 31, 2021USD ($)	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Jun. 01, 2015
Claim By Former Affiliate [Abstract]
Restructuring And Related Activities Ownership Percentage By Riverstone							35.00%
Power Purchase [Member]
Energy Purchase Commitments (Numeric) [Abstract]
2022				$ 33
2023				33
2024				32
2025				32
2026				32
Thereafter				314
Total				476
Purchases				19	$ 18	$ 22
LGE [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Number of residents that filed class action suit | resident			6
Number of remaining unresolved Clean Air Act violation claims after July 2014 court ruling | claim		1
LGE [Member] | Minimum [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Number of miles within plant that would include a class of residents | mi	1
LGE [Member] | Maximum [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Number of miles within plant that would include a class of residents | mi	3
Louisville Gas And Electric Co [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Number of residents that filed class action suit | resident			6
Number of remaining unresolved Clean Air Act violation claims after July 2014 court ruling | claim		1
Louisville Gas And Electric Co [Member] | Minimum [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Number of miles within plant that would include a class of residents | mi	1
Louisville Gas And Electric Co [Member] | Maximum [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Number of miles within plant that would include a class of residents | mi	3
Louisville Gas And Electric Co [Member] | Power Purchase [Member]
Energy Purchase Commitments (Numeric) [Abstract]
2022				23
2023				23
2024				22
2025				22
2026				22
Thereafter				218
Total				330
Purchases				13	12	15
Kentucky Utilities Co [Member] | Power Purchase [Member]
Energy Purchase Commitments (Numeric) [Abstract]
2022				10
2023				10
2024				10
2025				10
2026				10
Thereafter				96
Total				146
Purchases				6	6	$ 7
PPL Electric Additional Sites [Member] | PPL Electric [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Accrual for Environmental Loss Contingencies				10	10
PPL Electric Additional Sites [Member] | PPL Electric Utilities Corp [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Accrual for Environmental Loss Contingencies				$ 10	$ 10

Commitments and Contingencies_3

Commitments and Contingencies (Environmental Matter and Other) (Details) - PPL Electric Additional Sites [Member] - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
PPL Electric [Member]
Environmental Matters - Superfund And Other Remediation (Numeric) [Abstract]
Environmental site accrual	$ 10	$ 10
PPL Electric Utilities Corp [Member]
Environmental Matters - Superfund And Other Remediation (Numeric) [Abstract]
Environmental site accrual	$ 10	$ 10

Commitments and Contingencies_4

Commitments and Contingencies (Guarantees and Other Assurances) (Details) - Dec. 31, 2021 £ in Millions, $ in Millions	USD ($)	GBP (£)
Other Guarantee (Numeric) [Abstract]
Maximum aggregate coverage bodily injury and property damage	$ 225
Indemnification Cap, Surrenders of Tax Losses | £		£ 50
PPL Guarantee [Member] | Indemnification Guarantee [Member] | Indemnifications related to the sale of the U.K. utility business [Domain]
Guarantor Obligations [Line Items]
Maximum exposure | £		£ 7,881
PPL Guarantee [Member] | Indemnification Guarantee [Member] | Indemnifications related to certain tax liabilities related to the sale of the U.K. utility business [Domain]
Guarantor Obligations [Line Items]
Maximum exposure	50
LGE And KU Guarantee [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Contingent potential proportionate share of OVEC's outstanding debt	92
Louisville Gas And Electric Co [Member] | LGE And KU Guarantee [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Contingent potential proportionate share of OVEC's outstanding debt	64
Kentucky Utilities Co [Member] | LGE And KU Guarantee [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Contingent potential proportionate share of OVEC's outstanding debt	28
LGE [Member] | LGE And KU Guarantee [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Contingent potential proportionate share of OVEC's outstanding debt	64
KU [Member] | LGE And KU Guarantee [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Contingent potential proportionate share of OVEC's outstanding debt	$ 28

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
PPL Electric Utilities Corp [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes Receivable, Related Parties, Current	$ 499	$ 0
PPL Electric Utilities Corp [Member] | PPL Services [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	54	50	$ 59
Intercompany Borrowings (Numeric) [Abstract]
VEBA Funds Receivable	11	22
PPL Electric Utilities Corp [Member] | PPL Services [Member] | Accounts receivable from affiliates [Member]
Intercompany Borrowings (Numeric) [Abstract]
VEBA Funds Receivable	10	10
PPL Electric Utilities Corp [Member] | PPL Services [Member] | Other Noncurrent Assets [Member]
Intercompany Borrowings (Numeric) [Abstract]
VEBA Funds Receivable	1	12
PPL Electric Utilities Corp [Member] | PPL EU Services [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	222	176	152
PPL Electric Utilities Corp [Member] | PPL Energy Funding [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany note with affiliate maximum borrowing capacity	1,200
Notes Receivable, Related Parties, Current	499	0
Louisville Gas And Electric Co [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes payable to affiliates	324	0
Louisville Gas And Electric Co [Member] | Parent And Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes Receivable, Related Parties, Current	324	0
Intercompany Money Pool Agreement Maximum Borrowing Capacity	325
Louisville Gas And Electric Co [Member] | LKS [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	169	170	160
Kentucky Utilities Co [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes payable to affiliates	294	0
Kentucky Utilities Co [Member] | Parent And Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes Receivable, Related Parties, Current	294	0
Intercompany Money Pool Agreement Maximum Borrowing Capacity	300
Kentucky Utilities Co [Member] | LKS [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	$ 179	$ 180	$ 178

Other Income (Expense) - net (D

Other Income (Expense) - net (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Other Income [Line Items]
Defined benefit plans - non-service credits	$ 21	$ (2)	$ 8
Interest income	12	9	15
Allowance for funds used during construction - equity component	18	20	23
Miscellaneous	10	7	7
Total Other Income	61	34	53
Other Expense [Line Items]
Charitable contributions	14	3	17
Miscellaneous	32	29	22
Total Other Expense	46	32	39
Other Income (Expense) - net	15	2	14
PPL Electric Utilities Corp [Member]
Other Income [Line Items]
Defined benefit plans - non-service credits	9	4	4
Interest income	0	2	2
Allowance for funds used during construction - equity component	18	19	23
Total Other Income	27	25	29
Other Expense [Line Items]
Charitable contributions	3	3	3
Miscellaneous	3	4	1
Total Other Expense	6	7	4
Other Income (Expense) - net	$ 21	$ 18	$ 25

Fair Value Measurements (Assets

Fair Value Measurements (Assets and Liabilities Measured on Recurring Basis Table) (Details) - Recurring [Member] - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Assets
Cash and cash equivalents	$ 3,571	$ 442
Restricted cash and cash equivalents	1	1
Money market fund	2	0
Commingled debt fund measured at NAV	22	26
Commingled equity fund measured at NAV	21	25
Total special use funds	45	51
Price risk management assets:
Total Assets	3,617	494
Price risk management liabilities:
Interest rate swaps	18	23
Total price risk management liabilities	18	23
Level 1 [Member]
Assets
Cash and cash equivalents	3,571	442
Restricted cash and cash equivalents	1	1
Money market fund	2	0
Total special use funds	2	0
Price risk management assets:
Total Assets	3,574	443
Price risk management liabilities:
Interest rate swaps	0	0
Total price risk management liabilities	0	0
Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Money market fund	0	0
Total special use funds	0	0
Price risk management assets:
Total Assets	0	0
Price risk management liabilities:
Interest rate swaps	18	23
Total price risk management liabilities	18	23
Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Money market fund	0	0
Total special use funds	0	0
Price risk management assets:
Total Assets	0	0
Price risk management liabilities:
Interest rate swaps	0	0
Total price risk management liabilities	0	0
PPL Electric Utilities Corp [Member]
Assets
Cash and cash equivalents	21	40
Price risk management assets:
Total Assets	21	40
PPL Electric Utilities Corp [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	21	40
Price risk management assets:
Total Assets	21	40
PPL Electric Utilities Corp [Member] | Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Price risk management assets:
Total Assets	0	0
PPL Electric Utilities Corp [Member] | Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Price risk management assets:
Total Assets	0	0
Louisville Gas And Electric Co [Member]
Assets
Cash and cash equivalents	9	7
Price risk management assets:
Total Assets	9	7
Price risk management liabilities:
Interest rate swaps	18	23
Total price risk management liabilities	18	23
Louisville Gas And Electric Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	9	7
Price risk management assets:
Total Assets	9	7
Price risk management liabilities:
Interest rate swaps	0	0
Total price risk management liabilities	0	0
Louisville Gas And Electric Co [Member] | Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Price risk management assets:
Total Assets	0	0
Price risk management liabilities:
Interest rate swaps	18	23
Total price risk management liabilities	18	23
Louisville Gas And Electric Co [Member] | Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Price risk management assets:
Total Assets	0	0
Price risk management liabilities:
Interest rate swaps	0	0
Total price risk management liabilities	0	0
Kentucky Utilities Co [Member]
Assets
Cash and cash equivalents	13	22
Price risk management assets:
Total Assets	13	22
Kentucky Utilities Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	13	22
Price risk management assets:
Total Assets	13	22
Kentucky Utilities Co [Member] | Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Price risk management assets:
Total Assets	0	0
Kentucky Utilities Co [Member] | Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Price risk management assets:
Total Assets	$ 0	$ 0

Fair Value Measurements (Financ

Fair Value Measurements (Financial Instruments Not Recorded at Fair Value) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	$ 11,140	$ 14,689
Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	12,955	17,774
PPL Electric Utilities Corp [Member] | Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	4,484	4,236
PPL Electric Utilities Corp [Member] | Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	5,272	5,338
Louisville Gas And Electric Co [Member] | Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	2,006	2,007
Louisville Gas And Electric Co [Member] | Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	2,363	2,499
Kentucky Utilities Co [Member] | Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	2,618	2,618
Kentucky Utilities Co [Member] | Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	$ 3,120	$ 3,334

Derivative Instruments and He_4

Derivative Instruments and Hedging Activities (Intro) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Master Netting Arrangements (Numeric) [Line Items]
Cash Collateral Obligation Under Master Netting Arrangement	$ 0	$ 0
Cash Collateral Posted Under Master Netting Arrangements	0	0
Louisville Gas And Electric Co [Member]
Master Netting Arrangements (Numeric) [Line Items]
Cash Collateral Obligation Under Master Netting Arrangement	0	0
Cash Collateral Posted Under Master Netting Arrangements	0	0
Kentucky Utilities Co [Member]
Master Netting Arrangements (Numeric) [Line Items]
Cash Collateral Obligation Under Master Netting Arrangement	0	0
Cash Collateral Posted Under Master Netting Arrangements	$ 0	$ 0

Derivative Instruments and He_5

Derivative Instruments and Hedging Activities (Risk Disclosures) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Mar. 31, 2021
Cash Flow Hedges [Member] | Interest Rate Swaps [Member]
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Gain (Loss) on Discontinuation of Interest Rate Cash Flow Hedge Due to Forecasted Transaction Probable of Not Occurring, Net	$ 0	$ 0	$ 0
Cash Flow Hedges [Member] | Cross Currency Interest Rate Swaps [Member]
Interest Rate Risk And Foreign Currency Risk [Line Items]
Derivative, Notional Amount				$ 0
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Principal amount				500
Derivative Notional Amount Matured				$ 500
Net Investment Hedges [Member] | Foreign Currency Contracts [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Gain (Loss) on Derivative Used in Net Investment Hedge, After tax		$ 33
LGE [Member] | Economic Hedges [Member] | Interest Rate Swaps [Member]
Interest Rate Risk And Foreign Currency Risk [Line Items]
Derivative, Notional Amount	64
Louisville Gas And Electric Co [Member] | Economic Hedges [Member] | Interest Rate Swaps [Member]
Interest Rate Risk And Foreign Currency Risk [Line Items]
Derivative, Notional Amount	$ 64

Derivative Instruments and He_6

Derivative Instruments and Hedging Activities (Fair Values) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Derivatives Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	$ 0	$ 146
Liability value	0	0
Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	94
Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	94
Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	52
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	52
Derivatives Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Derivatives Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Derivatives Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Derivatives Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Derivatives Not Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Liability value	18	160
Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	1	139
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	1	2
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Foreign Currency Contracts [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	137
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	17	21
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	17	21
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Cross Currency Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Liability value	18	23
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	1	2
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	1	2
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	17	21
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	$ 17	$ 21

Derivative Instruments and He_7

Derivative Instruments and Hedging Activities (Gains and Losses) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Derivative Instruments Gain Loss [Line Items]
Interest Expense	$ 918	$ 634	$ 621
Other Income (Expense) - net	15	2	14
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Income (Loss) from Discontinued Operations (net of income taxes)	(1,498)	829	1,010
Cash Flow Hedges [Member]
Derivative Instruments Gain Loss [Line Items]
Gain (Loss) Reclassified from AOCI into Income	(30)	(32)	(18)
Cash Flow Hedges [Member] | Other Comprehensive Income [Member]
Derivative Instruments Gain Loss [Line Items]
Derivative Gain (Loss) Recognized in OCI	(50)	(24)	(13)
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Other Comprehensive Income [Member]
Derivative Instruments Gain Loss [Line Items]
Derivative Gain (Loss) Recognized in OCI	0	(9)	(30)
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Interest Expense [Member]
Derivative Instruments Gain Loss [Line Items]
Gain (Loss) Reclassified from AOCI into Income	11	(8)	(9)
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Amount of gain (loss) reclassified from AOCI to income	11	(8)	(9)
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Discontinued Operations (net of income taxes)
Derivative Instruments Gain Loss [Line Items]
Gain (Loss) Reclassified from AOCI into Income	(2)	(2)
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Amount of gain (loss) reclassified from AOCI to income	(2)	(2)	0
Cash Flow Hedges [Member] | Cross Currency Swaps [Member] | Other Comprehensive Income [Member]
Derivative Instruments Gain Loss [Line Items]
Derivative Gain (Loss) Recognized in OCI	(50)	(15)	17
Cash Flow Hedges [Member] | Cross Currency Swaps [Member] | Interest Expense [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Amount of gain (loss) reclassified from AOCI to income	0	0	0
Hedged Items	0	0	0
Cash Flow Hedges [Member] | Cross Currency Swaps [Member] | Discontinued Operations (net of income taxes)
Derivative Instruments Gain Loss [Line Items]
Gain (Loss) Reclassified from AOCI into Income	(39)	(22)	(9)
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Amount of gain (loss) reclassified from AOCI to income	(39)	(22)	(9)
Hedged Items	39	22	9
Net Investment Hedges [Member] | Foreign Currency Contracts [Member] | Discontinued Operations (net of income taxes)
Derivative Instruments Gain Loss [Line Items]
Derivative Gain (Loss) Recognized in OCI	1	1	2
Derivatives Designated As Hedging Instruments [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	146
Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	94
Derivatives Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Current Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	0
Derivatives Designated As Hedging Instruments [Member] | Cross Currency Swaps [Member] | Current Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	94
Derivatives Designated As Hedging Instruments [Member] | Foreign Currency Contracts [Member] | Current Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	0
Derivatives Not Designated As Hedging Instruments [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	(268)	(103)	(19)
Asset value	0	0
Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	0
Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Current Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	0
Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Regulatory Assets Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	5	(2)	(1)
Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Interest Expense [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	(2)	(5)	(5)
Derivatives Not Designated As Hedging Instruments [Member] | Cross Currency Swaps [Member] | Current Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	0
Derivatives Not Designated As Hedging Instruments [Member] | Foreign Currency Contracts [Member] | Current Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	0
Derivatives Not Designated As Hedging Instruments [Member] | Foreign Currency Contracts [Member] | Discontinued Operations (net of income taxes)
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	(266)	(98)	(14)
Louisville Gas And Electric Co [Member]
Derivative Instruments Gain Loss [Line Items]
Interest Expense	81	87	87
Other Income (Expense) - net	(5)	(1)	(11)
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	0
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	0
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Current Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	0
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Regulatory Assets Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	5	(2)	(1)
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Interest Expense [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	(2)	(5)	(5)
Kentucky Utilities Co [Member]
Derivative Instruments Gain Loss [Line Items]
Interest Expense	109	113	109
Other Income (Expense) - net	$ 4	$ 3	$ (4)

Derivative Instruments and He_8

Derivative Instruments and Hedging Activities (Offsetting Derivative Instruments and Credit Risk-Related Features) (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
Offsetting Assets And Liabilities [Line Items]
Cash collateral received eligible for offset - assets	$ 0	$ 0
Cash collateral pledged eligible for offset - liabilities	0	0
Credit Risk-Related Contingent Features [Abstract]
Derivative Net Liability Position Containing Credit Risk Related Contingency Features	0
Treasury Derivatives [Member]
Offsetting Assets And Liabilities [Line Items]
Gross assets	0	146
Derivative instruments eligible for offset - assets	0	34
Cash collateral received eligible for offset - assets	0	0
Net assets	0	112
Gross liabilities	18	160
Derivative instruments eligible for offset - liabilities	0	34
Cash collateral pledged eligible for offset - liabilities	0	0
Net liabilities	18	126
Louisville Gas And Electric Co [Member]
Offsetting Assets And Liabilities [Line Items]
Cash collateral received eligible for offset - assets	0	0
Cash collateral pledged eligible for offset - liabilities	0	0
Louisville Gas And Electric Co [Member] | Treasury Derivatives [Member]
Offsetting Assets And Liabilities [Line Items]
Gross assets	0	0
Derivative instruments eligible for offset - assets	0	0
Cash collateral received eligible for offset - assets	0	0
Net assets	0	0
Gross liabilities	18	23
Derivative instruments eligible for offset - liabilities	0	0
Cash collateral pledged eligible for offset - liabilities	0	0
Net liabilities	18	23
Kentucky Utilities Co [Member]
Offsetting Assets And Liabilities [Line Items]
Cash collateral received eligible for offset - assets	0	0
Cash collateral pledged eligible for offset - liabilities	$ 0	$ 0

Goodwill and Other Intangible_3

Goodwill and Other Intangible Assets (Goodwill) (Details) $ in Millions	Dec. 31, 2021USD ($)
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period	$ 716
Balance at end of period	716
Kentucky Regulated [Member]
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period	662
Balance at end of period	662
Corporate And Other [Member]
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period	53
Balance at end of period	$ 53

Goodwill and Other Intangible_4

Goodwill and Other Intangible Assets (Other Intangibles - Finite-Lived) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Subject to amortization: [Abstract]
Gross carrying amount	$ 551	$ 547
Accumulated amortization	231	219
Contracts [Member]
Subject to amortization: [Abstract]
Gross carrying amount	125	125
Accumulated amortization	90	82
Land Rights And Easements [Member]
Subject to amortization: [Abstract]
Gross carrying amount	406	401
Accumulated amortization	135	133
Licenses And Other [Member]
Subject to amortization: [Abstract]
Gross carrying amount	20	21
Accumulated amortization	6	4
Intangible assets with no regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	9	7	$ 6
Forecasted amortization in 2021	5
Forecasted amortization in 2022	5
Forecasted amortization in 2023	5
Forecasted amortization in 2024	5
Forecasted amortization in 2025	5
Intangible assets with regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	8	8	9
Forecasted amortization in 2021	8
Forecasted amortization in 2022	8
Forecasted amortization in 2023	9
Forecasted amortization in 2024	9
Forecasted amortization in 2025	2
Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits [Member]
Subject to amortization: [Abstract]
Amortization expense	17	15	15
Forecasted amortization in 2021	13
Forecasted amortization in 2022	13
Forecasted amortization in 2023	14
Forecasted amortization in 2024	14
Forecasted amortization in 2025	7
PPL Electric Utilities Corp [Member]
Subject to amortization: [Abstract]
Gross carrying amount	384	381
Accumulated amortization	131	130
PPL Electric Utilities Corp [Member] | Land Rights And Easements [Member]
Subject to amortization: [Abstract]
Gross carrying amount	382	379
Accumulated amortization	130	129
PPL Electric Utilities Corp [Member] | Licenses And Other [Member]
Subject to amortization: [Abstract]
Gross carrying amount	2	2
Accumulated amortization	1	1
PPL Electric Utilities Corp [Member] | Intangible assets with no regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	4	4	4
Forecasted amortization in 2021	4
Forecasted amortization in 2022	4
Forecasted amortization in 2023	4
Forecasted amortization in 2024	4
Forecasted amortization in 2025	4
Louisville Gas And Electric Co [Member]
Subject to amortization: [Abstract]
Gross carrying amount	93	93
Accumulated amortization	63	58
Louisville Gas And Electric Co [Member] | Land Rights And Easements [Member]
Subject to amortization: [Abstract]
Gross carrying amount	7	7
Accumulated amortization	1	1
Louisville Gas And Electric Co [Member] | OVEC power purchase agreement [Member]
Subject to amortization: [Abstract]
Gross carrying amount	86	86
Accumulated amortization	62	57
Louisville Gas And Electric Co [Member] | Intangible assets with regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	5	6	6
Forecasted amortization in 2021	6
Forecasted amortization in 2022	6
Forecasted amortization in 2023	6
Forecasted amortization in 2024	6
Forecasted amortization in 2025	1
Kentucky Utilities Co [Member]
Subject to amortization: [Abstract]
Gross carrying amount	55	54
Accumulated amortization	32	28
Kentucky Utilities Co [Member] | Land Rights And Easements [Member]
Subject to amortization: [Abstract]
Gross carrying amount	16	15
Accumulated amortization	4	3
Kentucky Utilities Co [Member] | OVEC power purchase agreement [Member]
Subject to amortization: [Abstract]
Gross carrying amount	39	39
Accumulated amortization	28	25
Kentucky Utilities Co [Member] | Intangible assets with no regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	1	0	0
Kentucky Utilities Co [Member] | Intangible assets with regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	3	$ 2	$ 3
Forecasted amortization in 2021	2
Forecasted amortization in 2022	2
Forecasted amortization in 2023	3
Forecasted amortization in 2024	3
Forecasted amortization in 2025	$ 1

Goodwill and Other Intangible_5

Goodwill and Other Intangible Assets (Other Intangibles - Indefinite-Lived) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount	$ 23	$ 23
Gross carrying amount - other intangible assets	574	570
Intangible assets with no regulatory offset [Member]
Not subject to amortization due to indefinite life: [Line Items]
Amortization expense	9	7	$ 6
Land Rights and Easements [Member]
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount	17	17
Other [Member]
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount	6	6
PPL Electric Utilities Corp [Member]
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount - other intangible assets	401	398
PPL Electric Utilities Corp [Member] | Intangible assets with no regulatory offset [Member]
Not subject to amortization due to indefinite life: [Line Items]
Amortization expense	4	4	4
PPL Electric Utilities Corp [Member] | Land Rights and Easements [Member]
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount	17	17
Kentucky Utilities Co [Member] | Intangible assets with no regulatory offset [Member]
Not subject to amortization due to indefinite life: [Line Items]
Amortization expense	$ 1	$ 0	$ 0

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	$ 182	$ 215
Accretion	16	15
Changes in estimated cash flow or settlement date	56	40
Obligations settled	(65)	(88)
Balance at End of Period	189	182
Louisville Gas And Electric Co [Member]
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	67	73
Accretion	5	5
Changes in estimated cash flow or settlement date	40	13
Obligations settled	(28)	(24)
Balance at End of Period	84	67
Kentucky Utilities Co [Member]
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	115	142
Accretion	11	10
Changes in estimated cash flow or settlement date	16	27
Obligations settled	(37)	(64)
Balance at End of Period	$ 105	$ 115

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Income (Loss) (After-tax Changes by Component) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	$ (4,220)	$ (4,358)	$ (3,964)
Amounts arising during the year	332	(94)	(496)
Reclassifications from AOCI	153	232	102
Net OCI during the year	4,063	138	(394)
Balance at end of year	(157)	(4,220)	(4,358)
Reclassification out of Accumulated Other Comprehensive Income (Loss) due to Sale of U.K, Utility Business
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassifications from AOCI	3,578
Foreign Currency Translation Adjustments [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(1,158)	(1,425)	(1,533)
Amounts arising during the year	372	267	108
Reclassifications from AOCI	0	0	0
Net OCI during the year	1,158	267	108
Balance at end of year	0	(1,158)	(1,425)
Foreign Currency Translation Adjustments [Member] | Reclassification out of Accumulated Other Comprehensive Income (Loss) due to Sale of U.K, Utility Business
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassifications from AOCI	786
Qualifying Derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	0	(5)	(7)
Amounts arising during the year	(39)	(19)	(11)
Reclassifications from AOCI	25	24	13
Net OCI during the year	1	5	2
Balance at end of year	1	0	(5)
Qualifying Derivatives [Member] | Reclassification out of Accumulated Other Comprehensive Income (Loss) due to Sale of U.K, Utility Business
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassifications from AOCI	15
Prior Service Costs [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(16)	(18)	(19)
Amounts arising during the year	0	(1)	(1)
Reclassifications from AOCI	2	3	2
Net OCI during the year	10	2	1
Balance at end of year	(6)	(16)	(18)
Prior Service Costs [Member] | Reclassification out of Accumulated Other Comprehensive Income (Loss) due to Sale of U.K, Utility Business
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassifications from AOCI	8
Defined Benefit Plans Actuarial Gain (Loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(3,046)	(2,910)	(2,405)
Amounts arising during the year	(1)	(341)	(592)
Reclassifications from AOCI	126	205	87
Net OCI during the year	2,894	(136)	(505)
Balance at end of year	(152)	$ (3,046)	$ (2,910)
Defined Benefit Plans Actuarial Gain (Loss) [Member] | Reclassification out of Accumulated Other Comprehensive Income (Loss) due to Sale of U.K, Utility Business
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassifications from AOCI	$ 2,769

Accumulated Other Comprehensi_4

Accumulated Other Comprehensive Income (Loss) (Income (Expense) Effect of Reclassifications) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Affected Line Item on the Statements of Income
Interest Expense	$ (918)	$ (634)	$ (621)
Other Income (Expense) - net	15	2	14
Total Pre-tax	521	954	919
Income Taxes	(503)	(314)	(183)
Income (Loss) from Discontinued Operations (net of income taxes)	(1,498)	829	1,010
Reclassification out of Accumulated Other Comprehensive Income (Loss) due to Sale of U.K, Utility Business
Affected Line Item on the Statements of Income
Income Taxes	(660)	0	0
Income (Loss) from Discontinued Operations (net of income taxes)	(3,578)	0	0
Income from Discontinued Operations, before Income Tax	(4,238)	0	0
Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Total After-Tax	(3,731)	(232)	(102)
Qualifying Derivatives [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Total Pre-tax	(30)	(32)	(18)
Income Taxes	5	8	5
Total After-Tax	(25)	(24)	(13)
Qualifying Derivatives [Member] | Interest Rate Swaps [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Interest Expense	11	(8)	(9)
Qualifying Derivatives [Member] | Cross Currency Swaps [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Interest Expense	(39)	(22)	(9)
Other Income (Expense) - net	(2)	(2)	0
Defined Benefit Plans [Member] | Reclassification out of Accumulated Other Comprehensive Income (Loss) due to Sale of U.K, Utility Business
Affected Line Item on the Statements of Income
Income from Discontinued Operations, before Income Tax	(3,577)	0	0
Defined Benefit Plans [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Total Pre-tax	(162)	(260)	(112)
Income Taxes	34	52	23
Total After-Tax	(128)	(208)	(89)
Defined Benefit Plans [Member] | Prior Service Costs [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Total Pre-tax	(3)	(4)	(3)
Defined Benefit Plans [Member] | Net Actuarial Loss [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Total Pre-tax	(159)	(256)	(109)
Accumulated Foreign Currency Adjustment Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income (Loss) due to Sale of U.K, Utility Business
Affected Line Item on the Statements of Income
Income from Discontinued Operations, before Income Tax	(646)	0	0
Accumulated Gain (Loss), Net, Cash Flow Hedge, Parent | Reclassification out of Accumulated Other Comprehensive Income (Loss) due to Sale of U.K, Utility Business
Affected Line Item on the Statements of Income
Income from Discontinued Operations, before Income Tax	$ (15)	$ 0	$ 0

New Accounting Guidance Pendi_2

New Accounting Guidance Pending Adoption New Accounting Guidance Pending Adoption (Details) $ in Millions	Dec. 31, 2021USD ($)
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Current lease liabilities	$ 22
Non-current lease liabilities	47
Louisville Gas And Electric Co [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Current lease liabilities	6
Non-current lease liabilities	12
Kentucky Utilities Co [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Current lease liabilities	9
Non-current lease liabilities	$ 17