LG&E & KU Energy 10-K 18 Feb 21 2019 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2020	Jan. 31, 2021
Document Entity Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2020
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		768,984,785
Entity Public Float	$ 19,865,342,074
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	2019
Document Fiscal Period Focus	FY
Documents Incorporated by Reference	PPL Corporation has incorporated herein by reference certain sections of PPL Corporation's 2021 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, 2020 and which will provide the information required by Part III of this Report.
ICFR Auditor Attestation Flag	true
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
2013 Series B Due 2073 [Member]
Document Entity Information [Line Items]
Title of 12(b) Security	2013 Series B due 2073
Trading Symbol	PPX
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 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
LG And E And KU Energy LLC [Member]
Document Entity Information [Line Items]
Entity File Number	333-173665
Entity Registrant Name	LG&E and KU Energy LLC
Entity Tax Identification Number	20-0523163
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 Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Shell Company	false
Amendment Flag	false
Entity Central Index Key	0001518339
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	false
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 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
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 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

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Thousands, $ in Millions		12 Months Ended
		Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Operating Revenues
Operating Revenues		$ 7,607	$ 7,769	$ 7,785
Operation
Fuel		632	709	799
Energy purchases		634	723	745
Other operation and maintenance		1,944	1,985	1,983
Depreciation		1,287	1,199	1,094
Taxes, other than income		307	313	312
Total Operating Expenses		4,804	4,929	4,933
Operating Income		2,803	2,840	2,852
Other Income (Expense) - net		169	309	396
Interest Expense		1,001	994	963
Income Before Income Taxes		1,971	2,155	2,285
Income Taxes		502	409	458
Net income		$ 1,469	$ 1,746	$ 1,827
Net Income Available to PPL Common Shareowners
Basic (in dollars per share)		$ 1.91	$ 2.39	$ 2.59
Diluted (in dollars per share)		$ 1.91	$ 2.37	$ 2.58
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic		768,590	728,512	704,439
Diluted		769,384	736,754	708,619
PPL Electric Utilities Corp [Member]
Operating Revenues
Operating Revenues		$ 2,331	$ 2,358	$ 2,277
Operation
Energy purchases		491	549	544
Other operation and maintenance		513	566	578
Depreciation		403	386	352
Taxes, other than income		107	112	109
Total Operating Expenses		1,514	1,613	1,583
Operating Income		817	745	694
Other Income (Expense) - net		18	25	23
Interest Income from Affiliate		2	6	8
Interest Expense		173	170	159
Income Before Income Taxes		664	606	566
Income Taxes		167	149	136
Net income	[1]	497	457	430
LG And E And KU Energy LLC [Member]
Operating Revenues
Operating Revenues		3,106	3,206	3,214
Operation
Fuel		632	709	799
Energy purchases		143	174	201
Other operation and maintenance		834	861	848
Depreciation		606	547	475
Taxes, other than income		77	74	70
Total Operating Expenses		2,292	2,365	2,393
Operating Income		814	841	821
Other Income (Expense) - net		2	(13)	(16)
Interest Expense		223	226	206
Interest Expense with Affiliates		37	31	25
Income Before Income Taxes		556	571	574
Income Taxes		106	103	129
Net income		450	468	445
Louisville Gas And Electric Co [Member]
Operating Revenues
Retail and wholesale		1,435	1,473	1,467
Electric revenue from affiliates		21	27	29
Operating Revenues		1,456	1,500	1,496
Operation
Fuel		246	289	308
Energy purchases		125	154	183
Energy purchases from affiliate		19	7	13
Other operation and maintenance		373	387	376
Depreciation		259	231	195
Taxes, other than income		40	39	36
Total Operating Expenses		1,062	1,107	1,111
Operating Income		394	393	385
Other Income (Expense) - net		(1)	(11)	(12)
Interest Expense		87	87	76
Income Before Income Taxes		306	295	297
Income Taxes		62	63	64
Net income	[2]	244	232	233
Kentucky Utilities Co [Member]
Operating Revenues
Retail and wholesale		1,671	1,733	1,747
Electric revenue from affiliates		19	7	13
Operating Revenues		1,690	1,740	1,760
Operation
Fuel		386	420	491
Energy purchases		18	20	18
Energy purchases from affiliate		21	27	29
Other operation and maintenance		429	438	441
Depreciation		346	315	279
Taxes, other than income		37	35	34
Total Operating Expenses		1,237	1,255	1,292
Operating Income		453	485	468
Other Income (Expense) - net		3	(4)	(6)
Interest Expense		113	109	100
Income Before Income Taxes		343	372	362
Income Taxes		63	79	76
Net income	[3]	$ 280	$ 293	$ 286
[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, 2020	Dec. 31, 2019	Dec. 31, 2018
Net income	$ 1,469	$ 1,746	$ 1,827
Amounts arising during the period - gains (losses), net of tax (expense) benefit:
Foreign currency translation adjustments, net of tax	267	108	(444)
Qualifying derivatives, net of tax	(19)	(11)	36
Defined benefit plans:
Prior service costs, net of tax	(1)	(1)	(11)
Net actuarial gain (loss), net of tax	(341)	(592)	(187)
Reclassifications from AOCI - (gains) losses, net of tax expense (benefit):
Qualifying derivatives, net of tax	24	13	(29)
Defined benefit plans:
Prior service costs, net of tax	3	2	2
Net actuarial (gain) loss, net of tax	205	87	142
Total other comprehensive income (loss)	138	(394)	(491)
Comprehensive income	1,607	1,352	1,336
LG And E And KU Energy LLC [Member]
Net income	450	468	445
Defined benefit plans:
Prior service costs, net of tax	(1)	(1)	0
Net actuarial gain (loss), net of tax	(7)	(6)	7
Defined benefit plans:
Prior service costs, net of tax	2	1	2
Net actuarial (gain) loss, net of tax	13	2	8
Total other comprehensive income (loss)	7	(4)	17
Comprehensive income	$ 457	$ 464	$ 462

CONSOLIDATED STATEMENTS OF CO_2

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Tax effect of foreign currency translation adjustments arising during the period	$ 0	$ 0	$ (2)
Tax effect of qualifying derivatives arising during the period	5	2	(9)
Tax effect of defined benefit plans - prior service costs arising during period	0	0	3
Tax effect of defined benefit plans - net actuarial gain (loss) arising during period	74	119	44
Tax effect of qualifying derivatives reclassified from AOCI	8	5	(6)
Tax effect of defined benefit plans - prior service costs reclassified from AOCI	(1)	(1)	0
Tax effect of defined benefit plans - net actuarial (gain) loss reclassified from AOCI	(51)	(22)	(36)
LG And E And KU Energy LLC [Member]
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	2	2	(2)
Tax effect of defined benefit plans - prior service costs reclassified from AOCI	0	0	0
Tax effect of defined benefit plans - net actuarial (gain) loss reclassified from AOCI	$ 4	$ 1	$ 3

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Cash Flows from Operating Activities
Net income		$ 1,469	$ 1,746	$ 1,827
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		1,287	1,199	1,094
Amortization		72	81	78
Defined benefit plans - expense (income)		(201)	(263)	(192)
Deferred income taxes and investment tax credits		402	309	355
Unrealized (gains) losses on derivatives, and other hedging activities		280	73	(186)
Stock compensation expense		29	36	26
Other		(12)	(22)	(3)
Change in current assets and current liabilities
Accounts receivable		(82)	4	28
Accounts payable		10	(77)	78
Unbilled Revenues		10	(5)	41
Fuel, materials and supplies		(17)	(26)	17
Regulatory assets and liabilities, net		(63)	(88)	13
Other current liabilities		(23)	(73)	(22)
Other		(1)	(33)	(2)
Other operating activities
Defined benefit plans - funding		(390)	(350)	(361)
Proceeds from transfer of excess benefit plan funds		0	0	65
Other assets		(59)	(100)	(75)
Other liabilities		35	16	40
Net cash provided by operating activities		2,746	2,427	2,821
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(3,249)	(3,083)	(3,238)
Purchases of investments		0	55	65
Proceeds from the sale of investments		9	69	6
Other investing activities		(18)	(11)	(64)
Net cash provided by (used in) investing activities		(3,258)	(3,080)	(3,361)
Cash Flows from Financing Activities
Issuance of long-term debt		2,167	1,465	1,059
Retirement of long-term debt		(1,172)	(300)	(277)
Proceeds from project financing		173	0	0
Issuance of common stock		34	1,167	698
Payment of common stock dividends		(1,275)	(1,192)	(1,133)
Issuance of term loan		300	0	0
Issuance of commercial paper		73	0	0
Net increase (decrease) in short-term debt		127	(278)	363
Other financing activities		(41)	(26)	(20)
Net cash provided by (used in) financing activities		386	836	690
Effect of Exchange Rates on Cash, Cash Equivalents and Restricted Cash		17	10	(18)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(109)	193	132
Cash and Cash Equivalents at Beginning of Period		815
Cash and Cash Equivalents at End of Period		708	815
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		836	643	511
Cash, Cash Equivalents and Restricted Cash at End of Period		727	836	643
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		939	905	910
Income taxes - net		95	93	127
Accrued expenditures for property, plant and equipment at December 31,		319	340	345
Accrued expenditures for intangible assets at December 31,		85	79	64
PPL Electric Utilities Corp [Member]
Cash Flows from Operating Activities
Net income	[1]	497	457	430
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		403	386	352
Amortization		26	24	22
Deferred income taxes and investment tax credits		83	90	125
Other		(6)	(19)	(1)
Change in current assets and current liabilities
Accounts receivable		(47)	33	47
Accounts payable		21	5	10
Unbilled Revenues		13	(14)	7
Fuel, materials and supplies		(18)	(8)	9
Regulatory assets and liabilities, net		(40)	(43)	(19)
Other		(9)	(3)	6
Other operating activities
Defined benefit plans - funding		(21)	(21)	(28)
Other assets		(28)	15	(37)
Other liabilities		10	11	55
Net cash provided by operating activities		884	913	978
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(1,145)	(1,114)	(1,192)
Expenditures for intangible assets		(9)	(7)	(4)
Other investing activities		3	4	3
Net cash provided by (used in) investing activities		(1,151)	(1,117)	(1,193)
Cash Flows from Financing Activities
Issuance of long-term debt		250	393	398
Retirement of long-term debt		0	(100)	0
Contributions from parent		940	400	429
Payment of common stock dividends to parent		(400)	(486)	(390)
Return of Capital to Parent		(745)	0	0
Other financing activities		(2)	(8)	(4)
Net cash provided by (used in) financing activities		43	199	433
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(224)	(5)	218
Cash and Cash Equivalents at Beginning of Period		262
Cash and Cash Equivalents at End of Period		40	262
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		264	269	51
Cash, Cash Equivalents and Restricted Cash at End of Period		40	264	269
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		158	154	144
Income taxes - net		67	32	(20)
Accrued expenditures for property, plant and equipment at December 31,		156	180	158
LG And E And KU Energy LLC [Member]
Cash Flows from Operating Activities
Net income		450	468	445
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		606	547	475
Amortization		19	27	18
Defined benefit plans - expense (income)		15	11	17
Deferred income taxes and investment tax credits		64	82	94
Other		(2)	(3)	(4)
Change in current assets and current liabilities
Accounts receivable		(17)	(16)	1
Accounts payable		(11)	(26)	39
Unbilled Revenues		(12)	5	34
Accounts payable to affiliates		5	2	2
Fuel, materials and supplies		10	0	7
Taxes payable		13	(5)	(3)
Regulatory assets and liabilities, net		(26)	(45)	32
Other		(13)	(8)	(24)
Other operating activities
Defined benefit plans - funding		(54)	(34)	(131)
Other assets		(5)	(3)	(24)
Expenditures for asset retirement obligations		(84)	(89)	(72)
Other liabilities		45	25	9
Net cash provided by operating activities		1,003	938	915
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(966)	(1,094)	(1,117)
Other investing activities		3	0	1
Net cash provided by (used in) investing activities		(963)	(1,094)	(1,116)
Cash Flows from Financing Activities
Issuance of long-term debt		498	705	118
Issuance of long-term note with affiliate		550	0	250
Retirement of long-term debt		(975)	(200)	(27)
Acquisition of outstanding bonds		0	(40)	0
Remarketing of reacquired bonds		0	40	0
Issuance of commercial paper		73	0	0
Contributions from member		0	63	0
Distributions to member		(283)	(308)	(302)
Net increase (decrease) in notes payable to affiliates		101	37	(112)
Net increase (decrease) in short-term debt		4	(126)	270
Other financing activities		(6)	(12)	(2)
Net cash provided by (used in) financing activities		(38)	159	195
Net Increase (Decrease) in Cash and Cash Equivalents		2	3	(6)
Cash and Cash Equivalents at Beginning of Period		27	24	30
Cash and Cash Equivalents at End of Period		29	27	24
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		248	237	218
Income taxes - net		38	29	46
Accrued expenditures for property, plant and equipment at December 31,		100	113	150
Louisville Gas And Electric Co [Member]
Cash Flows from Operating Activities
Net income	[2]	244	232	233
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		259	231	195
Amortization		9	15	14
Defined benefit plans - expense (income)		3	3	3
Deferred income taxes and investment tax credits		3	56	60
Change in current assets and current liabilities
Accounts receivable		(3)	(9)	4
Accounts receivable from affiliates		4	6	0
Accounts payable		(18)	(10)	10
Unbilled Revenues		(3)	1	14
Accounts payable to affiliates		(5)	5	1
Fuel, materials and supplies		4	5	4
Taxes payable		(1)	7	1
Regulatory assets and liabilities, net		0	(19)	5
Other		(3)	(5)	(10)
Other operating activities
Defined benefit plans - funding		(11)	(6)	(61)
Other assets		(2)	(1)	(12)
Expenditures for asset retirement obligations		(20)	(30)	(22)
Other liabilities		23	11	4
Net cash provided by operating activities		483	492	443
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(456)	(482)	(554)
Net cash provided by (used in) investing activities		(456)	(482)	(554)
Cash Flows from Financing Activities
Issuance of long-term debt		0	399	100
Retirement of long-term debt		0	(200)	0
Acquisition of outstanding bonds		0	(40)	0
Remarketing of reacquired bonds		0	40	0
Issuance of commercial paper		41	0	0
Contributions from parent		103	25	83
Payment of common stock dividends to parent		(161)	(182)	(156)
Net increase (decrease) in short-term debt		(17)	(41)	80
Other financing activities		(1)	(6)	(1)
Net cash provided by (used in) financing activities		(35)	(5)	106
Net Increase (Decrease) in Cash and Cash Equivalents		(8)	5	(5)
Cash and Cash Equivalents at Beginning of Period		15	10	15
Cash and Cash Equivalents at End of Period		7	15	10
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		82	77	71
Income taxes - net		63	2	7
Accrued expenditures for property, plant and equipment at December 31,		60	59	61
Kentucky Utilities Co [Member]
Cash Flows from Operating Activities
Net income	[3]	280	293	286
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		346	315	279
Amortization		8	10	3
Defined benefit plans - expense (income)		0	(1)	0
Deferred income taxes and investment tax credits		20	39	48
Other		(1)	(3)	(4)
Change in current assets and current liabilities
Accounts receivable		(13)	(3)	(4)
Accounts receivable from affiliates		(1)	0	0
Accounts payable		9	(15)	29
Unbilled Revenues		(9)	4	20
Accounts payable to affiliates		(16)	(2)	(3)
Fuel, materials and supplies		6	(6)	3
Taxes payable		2	2	5
Regulatory assets and liabilities, net		(26)	(26)	27
Other		(5)	(6)	(3)
Other operating activities
Defined benefit plans - funding		(3)	(3)	(54)
Other assets		(2)	(2)	(12)
Expenditures for asset retirement obligations		(64)	(59)	(50)
Other liabilities		12	16	11
Net cash provided by operating activities		543	553	581
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(510)	(610)	(562)
Other investing activities		3	0	1
Net cash provided by (used in) investing activities		(507)	(610)	(561)
Cash Flows from Financing Activities
Issuance of long-term debt		498	306	18
Retirement of long-term debt		(500)	0	(27)
Issuance of commercial paper		32	0	0
Contributions from parent		128	68	45
Payment of common stock dividends to parent		(200)	(229)	(246)
Net increase (decrease) in short-term debt		21	(85)	190
Other financing activities		(5)	(5)	(1)
Net cash provided by (used in) financing activities		(26)	55	(21)
Net Increase (Decrease) in Cash and Cash Equivalents		10	(2)	(1)
Cash and Cash Equivalents at Beginning of Period		12	14	15
Cash and Cash Equivalents at End of Period		22	12	14
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		109	101	95
Income taxes - net		44	39	25
Accrued expenditures for property, plant and equipment at December 31,		$ 40	$ 54	$ 88
[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, 2020	Dec. 31, 2019
Current Assets
Cash and cash equivalents		$ 708	$ 815
Accounts receivable (less reserve:)
Customer		790	687
Other		91	105
Unbilled revenues		498	504
Fuel, materials and supplies		361	332
Prepayments		96	79
Price risk management assets		94	147
Regulatory assets		99	67
Other current assets		130	98
Total Current Assets		2,768	2,767
Property, Plant and Equipment
Regulated utility plant		45,887	42,709
Less: accumulated depreciation - regulated utility plant		8,894	8,055
Regulated utility plant, net		36,993	34,654
Non-regulated property, plant and equipment		498	357
Less: accumulated depreciation - non-regulated property, plant and equipment		102	109
Non-regulated property, plant and equipment, net		396	248
Construction work in progress		1,503	1,580
Property, Plant and Equipment, net		38,892	36,482
Other Noncurrent Assets
Regulatory assets		1,262	1,492
Goodwill		3,274	3,198
Other intangibles		764	742
Pension benefit asset		706	464
Price risk management assets		52	149
Other noncurrent assets		398	386
Total Other Noncurrent Assets		6,456	6,431
Total Assets		48,116	45,680
Current Liabilities
Short-term debt		1,662	1,151
Long-term debt due within one year		1,574	1,172
Accounts payable		965	956
Taxes		91	99
Interest		303	294
Dividends		319	317
Customer deposits		300	261
Regulatory liabilities		79	115
Other current liabilities		684	535
Total Current Liabilities		5,977	4,900
Long-term Debt [Abstract]
Long-term Debt		21,553	20,721
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		3,568	3,088
Investment tax credits		122	124
Accrued pension obligations		200	587
Asset retirement obligations		200	212
Regulatory liabilities		2,530	2,572
Other deferred credits and noncurrent liabilities		593	485
Total Deferred Credits and Other Noncurrent Liabilities		7,213	7,068
Commitments and Contingent Liabilities
Equity
Common stock	[1]	8	8
Additional paid-in capital		12,270	12,214
Earnings reinvested		5,315	5,127
Accumulated other comprehensive loss		(4,220)	(4,358)
Total Equity		13,373	12,991
Total Liabilities and Equity		$ 48,116	$ 45,680
Common stock par value		$ 0.01	$ 0.01
PPL Electric Utilities Corp [Member]
Current Assets
Cash and cash equivalents		$ 40	$ 262
Accounts receivable (less reserve:)
Customer		311	258
Other		17	22
Accounts receivable from affiliates		10	11
Unbilled revenues		121	134
Fuel, materials and supplies		59	33
Prepayments		9	6
Regulatory assets		40	26
Other current assets		13	9
Total Current Assets		620	761
Property, Plant and Equipment
Regulated utility plant		13,514	12,589
Less: accumulated depreciation - regulated utility plant		3,297	3,078
Regulated utility plant, net		10,217	9,511
Construction work in progress		592	597
Property, Plant and Equipment, net		10,809	10,108
Other Noncurrent Assets
Regulatory assets		541	726
Other intangibles		268	263
Other noncurrent assets		86	43
Total Other Noncurrent Assets		895	1,032
Total Assets		12,324	11,901
Current Liabilities
Short-term debt		400	0
Long-term debt due within one year		400	0
Accounts payable		428	438
Accounts payable to affiliates		39	32
Taxes		17	13
Interest		39	41
Regulatory liabilities		68	96
Other current liabilities		105	93
Total Current Liabilities		1,096	713
Long-term Debt [Abstract]
Long-term Debt		3,836	3,985
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,559	1,447
Accrued pension obligations		8	179
Regulatory liabilities		578	599
Other deferred credits and noncurrent liabilities		123	146
Total Deferred Credits and Other Noncurrent Liabilities		2,268	2,371
Commitments and Contingent Liabilities
Equity
Common stock	[2]	364	364
Additional paid-in capital		3,753	3,558
Earnings reinvested		1,007	910
Total Equity		5,124	4,832
Total Liabilities and Equity		$ 12,324	$ 11,901
Common stock no par value		$ 0	$ 0
LG And E And KU Energy LLC [Member]
Current Assets
Cash and cash equivalents		$ 29	$ 27
Accounts receivable (less reserve:)
Customer		283	260
Other		69	71
Unbilled revenues		176	164
Fuel, materials and supplies		242	250
Prepayments		30	30
Regulatory assets		59	41
Other current assets		4	2
Total Current Assets		892	845
Property, Plant and Equipment
Regulated utility plant		15,557	14,646
Less: accumulated depreciation - regulated utility plant		2,717	2,356
Regulated utility plant, net		12,840	12,290
Construction work in progress		640	794
Property, Plant and Equipment, net		13,480	13,084
Other Noncurrent Assets
Regulatory assets		721	766
Goodwill		996	996
Other intangibles		61	69
Other noncurrent assets		127	171
Total Other Noncurrent Assets		1,905	2,002
Total Assets		16,277	15,931
Current Liabilities
Short-term debt		465	388
Long-term debt due within one year		674	975
Notes payable with affiliates		251	150
Accounts payable		294	316
Accounts payable to affiliates		16	11
Taxes		71	58
Interest		37	40
Asset Retirement Obligations		50	70
Price risk management liabilities		2	4
Customer deposits		64	62
Regulatory liabilities		11	19
Other current liabilities		162	153
Total Current Liabilities		2,097	2,246
Long-term Debt [Abstract]
Long-term debt		4,200	4,377
Long-term debt to affiliate		1,200	650
Long-term Debt		5,400	5,027
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,175	1,069
Investment tax credits		121	124
Price risk management liabilities		21	17
Accrued pension obligations		112	233
Asset retirement obligations		132	145
Regulatory liabilities		1,952	1,973
Other deferred credits and noncurrent liabilities		151	155
Total Deferred Credits and Other Noncurrent Liabilities		3,664	3,716
Commitments and Contingent Liabilities
Equity
Accumulated other comprehensive loss		(86)	(93)
Member's Equity		5,116	4,942
Total Liabilities and Equity		16,277	15,931
Louisville Gas And Electric Co [Member]
Current Assets
Cash and cash equivalents		7	15
Accounts receivable (less reserve:)
Customer		127	121
Other		35	41
Accounts receivable from affiliates		16	18
Unbilled revenues		79	76
Fuel, materials and supplies		119	122
Prepayments		14	14
Regulatory assets		23	25
Other current assets		1	1
Total Current Assets		421	433
Property, Plant and Equipment
Regulated utility plant		6,735	6,372
Less: accumulated depreciation - regulated utility plant		1,020	846
Regulated utility plant, net		5,715	5,526
Construction work in progress		320	297
Property, Plant and Equipment, net		6,035	5,823
Other Noncurrent Assets
Regulatory assets		351	380
Goodwill		389	389
Other intangibles		35	41
Other noncurrent assets		114	67
Total Other Noncurrent Assets		889	877
Total Assets		7,345	7,133
Current Liabilities
Short-term debt		262	238
Long-term debt due within one year		292	0
Accounts payable		153	172
Accounts payable to affiliates		31	31
Taxes		32	33
Interest		15	15
Asset Retirement Obligations		10	24
Price risk management liabilities		2	4
Customer deposits		32	31
Regulatory liabilities		0	2
Other current liabilities		50	47
Total Current Liabilities		879	597
Long-term Debt [Abstract]
Long-term Debt		1,715	2,005
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		716	697
Investment tax credits		33	34
Price risk management liabilities		21	17
Asset retirement obligations		57	49
Regulatory liabilities		882	883
Other deferred credits and noncurrent liabilities		94	89
Total Deferred Credits and Other Noncurrent Liabilities		1,803	1,769
Commitments and Contingent Liabilities
Equity
Common stock	[3]	424	424
Additional paid-in capital		1,923	1,820
Earnings reinvested		601	518
Total Equity		2,948	2,762
Total Liabilities and Equity		$ 7,345	$ 7,133
Common stock no par value		$ 0	$ 0
Kentucky Utilities Co [Member]
Current Assets
Cash and cash equivalents		$ 22	$ 12
Accounts receivable (less reserve:)
Customer		156	139
Other		30	27
Accounts receivable from affiliates		1	0
Unbilled revenues		97	88
Fuel, materials and supplies		123	128
Prepayments		15	14
Regulatory assets		36	16
Other current assets		1	1
Total Current Assets		481	425
Property, Plant and Equipment
Regulated utility plant		8,808	8,262
Less: accumulated depreciation - regulated utility plant		1,690	1,507
Regulated utility plant, net		7,118	6,755
Construction work in progress		321	496
Property, Plant and Equipment, net		7,439	7,251
Other Noncurrent Assets
Regulatory assets		370	386
Goodwill		607	607
Other intangibles		26	28
Other noncurrent assets		149	128
Total Other Noncurrent Assets		1,152	1,149
Total Assets		9,072	8,825
Current Liabilities
Short-term debt		203	150
Long-term debt due within one year		132	500
Accounts payable		121	121
Accounts payable to affiliates		43	52
Taxes		29	26
Interest		19	20
Asset Retirement Obligations		40	46
Customer deposits		32	31
Regulatory liabilities		11	17
Other current liabilities		59	51
Total Current Liabilities		689	1,014
Long-term Debt [Abstract]
Long-term Debt		2,486	2,123
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		835	792
Investment tax credits		88	90
Asset retirement obligations		75	96
Regulatory liabilities		1,070	1,090
Other deferred credits and noncurrent liabilities		47	46
Total Deferred Credits and Other Noncurrent Liabilities		2,115	2,114
Commitments and Contingent Liabilities
Equity
Common stock	[4]	308	308
Additional paid-in capital		2,857	2,729
Earnings reinvested		617	537
Total Equity		3,782	3,574
Total Liabilities and Equity		$ 9,072	$ 8,825
Common stock no par value		$ 0	$ 0
[1]	1,560,000 shares authorized; 768,907 and 767,233 shares issued and outstanding at December 31, 2020 and December 31, 2019.
[2]	170,000 shares authorized; 66,368 shares issued and outstanding at December 31, 2020 and December 31, 2019
[3]	75,000 shares authorized; 21,294 shares issued and outstanding at December 31, 2020 and December 31, 2019.
[4]	80,000 shares authorized; 37,818 shares issued and outstanding at December 31, 2020 and December 31, 2019.

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) shares in Thousands, $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 75	$ 58
Equity
Common stock par value	$ 0.01	$ 0.01
Common stock shares authorized	1,560,000	1,560,000
Common stock shares issued	768,907	767,233
Common stock shares outstanding	768,907	767,233
PPL Electric Utilities Corp [Member]
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 41	$ 28
Unbilled Revenues, Reserve	$ 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
LG And E And KU Energy LLC [Member]
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 30	$ 28
Unbilled Revenues, Reserve	2	0
Louisville Gas And Electric Co [Member]
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	2	1
Unbilled Revenues, Reserve	$ 1	$ 0
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	$ 1	$ 1
Unbilled Revenues, Reserve	$ 1	$ 0
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	Accumulated Other Comprehensive LossCumulative Effect, Period of Adoption, Adjustment	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	LG And E And KU Energy LLC [Member]	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		$ 1.64
Balance at beginning of period - shares at Dec. 31, 2017				693,398	[1]								66,368	[2]						21,294	[3]					37,818	[4]
Balance at beginning of period at Dec. 31, 2017																	$ 4,563
Balance at beginning of period at Dec. 31, 2017		$ 10,761		$ 7		$ 10,305	$ 3,871		$ (3,422)		$ 3,992		$ 364		$ 2,729	$ 899		$ 2,527		$ 424		$ 1,712	$ 391	$ 3,357		$ 308		$ 2,616	$ 433	$ 0
Common stock shares issued	[1]			26,925
Common stock issued		718				718
Stock-based compensation		(2)				(2)
Net income		1,827					1,827				430	[5]				430	445	233	[6]				233	286	[7]				286
Capital contributions from parent											429				429			83				83		45				45
Dividends and dividend equivalents		(1,156)					(1,156)
Cash dividends declared on common stock											(390)					(390)		(156)					(156)	(246)					(246)
Distributions to member																	(302)
Other comprehensive income (loss)		(491)							(491)								17
Balance at end of period - shares at Dec. 31, 2018				720,323	[1]								66,368	[2]						21,294	[3]					37,818	[4]
Balance at end of period at Dec. 31, 2018																	4,723
Balance at end of period at Dec. 31, 2018		$ 11,657		$ 7		11,021	4,593		(3,964)		4,461		$ 364		3,158	939		2,687		$ 424		1,795	468	3,442		$ 308		2,661	473	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest			$ 0					$ 51		$ (51)
Dividends Declared Per Share of Common Stock		$ 1.65
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	468	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)
Contributions from member																	63
Distributions to member																	(308)
Other comprehensive income (loss)		$ (394)							(394)								(4)
Balance at end of period - shares at Dec. 31, 2019		767,233		767,233	[1]						66,368		66,368	[2]				21,294		21,294	[3]			37,818		37,818	[4]
Balance at end of period at Dec. 31, 2019																	4,942
Balance at end of period at Dec. 31, 2019		$ 12,991		$ 8		12,214	5,127		(4,358)		$ 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	450	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)
Distributions to member																	(283)
Other comprehensive income (loss)		$ 138							138								7
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																	$ 5,116
Balance at end of period at Dec. 31, 2020		$ 13,373		$ 8		$ 12,270	$ 5,315		$ (4,220)		$ 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)
[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) - vote	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Vote per share of PPL's common stock	1	1	1

Earnings Per Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2020
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. In 2019 and 2018, these securities also included the PPL common stock forward sale agreements, which were partially settled in 2018 with the remaining shares 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: 2020 2019 2018 Income (Numerator) Net income $ 1,469 $ 1,746 $ 1,827 Less amounts allocated to participating securities 1 1 2 Net income available to PPL common shareowners - Basic and Diluted $ 1,468 $ 1,745 $ 1,825 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 768,590 728,512 704,439 Add incremental non-participating securities: Share-based payment awards (a) 794 1,101 445 Forward sale agreements — 7,141 3,735 Weighted-average shares - Diluted EPS 769,384 736,754 708,619 Basic EPS Net Income available to PPL common shareowners $ 1.91 $ 2.39 $ 2.59 Diluted EPS Net Income available to PPL common shareowners $ 1.91 $ 2.37 $ 2.58 (a) The Treasury Stock Method was applied to non-participating share-based payment awards. For the year ended December 31, PPL issued common stock related to stock-based compensation plans and DRIP as follows (in thousands): 2020 Stock-based compensation plans (a) 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. See Note 8 for additional information on common stock issued under the ATM Program. 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: 2020 2019 2018 Stock-based compensation awards 452 8 183

Earnings Per Share (Tables)

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2020
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: 2020 2019 2018 Income (Numerator) Net income $ 1,469 $ 1,746 $ 1,827 Less amounts allocated to participating securities 1 1 2 Net income available to PPL common shareowners - Basic and Diluted $ 1,468 $ 1,745 $ 1,825 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 768,590 728,512 704,439 Add incremental non-participating securities: Share-based payment awards (a) 794 1,101 445 Forward sale agreements — 7,141 3,735 Weighted-average shares - Diluted EPS 769,384 736,754 708,619 Basic EPS Net Income available to PPL common shareowners $ 1.91 $ 2.39 $ 2.59 Diluted EPS Net Income available to PPL common shareowners $ 1.91 $ 2.37 $ 2.58 (a) The Treasury Stock Method was applied to non-participating share-based payment awards.
Common Stock Issuances	For the year ended December 31, PPL issued common stock related to stock-based compensation plans and DRIP as follows (in thousands): 2020 Stock-based compensation plans (a) 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: 2020 2019 2018 Stock-based compensation awards 452 8 183

Earnings Per Share (Details)

Earnings Per Share (Details) - USD ($) shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Income (Numerator)
Net income	$ 1,469	$ 1,746	$ 1,827
Less amounts allocated to participating securities	1	1	2
Net income available to PPL common shareowners - Basic	1,468	1,745	1,825
Net income available to PPL common shareowners - Diluted	$ 1,468	$ 1,745	$ 1,825
Shares of Common Stock (Denominator)
Weighted-average shares - Basic EPS (in shares)	768,590	728,512	704,439
Add incremental non-participating securities:
Share-based payment awards (in shares)	794	1,101	445
Forward sales agreements	0	7,141	3,735
Weighted-average shares - Diluted EPS (in shares)	769,384	736,754	708,619
Basic EPS - Available to PPL common shareowners:
Net Income (in dollars per share)	$ 1.91	$ 2.39	$ 2.59
Diluted EPS - Available to PPL common shareowners:
Net Income (in dollars per share)	$ 1.91	$ 2.37	$ 2.58
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Common stock issued under DRIP (in shares)	943
Shares Issued (Numeric) [Abstract]
Common stock issued under stock-based compensation plans (in shares)	731
Stock Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS	452	8	183

SCHEDULE I - CONDENSED UNCONSOL

SCHEDULE I - CONDENSED UNCONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Details) - USD ($) shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Operating Revenues [Abstract]
Operating Revenues	$ 7,607	$ 7,769	$ 7,785
Operating Expenses [Abstract]
Other operation and maintenance	1,944	1,985	1,983
Total Operating Expenses	4,804	4,929	4,933
Operating Loss	2,803	2,840	2,852
Other Income (Expense) - net [Abstract]
Other Income (Expense) - net	169	309	396
Interest Expense	1,001	994	963
Income Before Income Taxes	1,971	2,155	2,285
Income Taxes	502	409	458
Net income	1,469	1,746	1,827
Total other comprehensive income (loss)	138	(394)	(491)
Comprehensive Income Attributable to PPL Shareowners	$ 1,607	$ 1,352	$ 1,336
Net Income Available to PPL Corporation Common Shareowners: (in dollars per share)
Basic (in dollars per share)	$ 1.91	$ 2.39	$ 2.59
Diluted (in dollars per share)	$ 1.91	$ 2.37	$ 2.58
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic	768,590	728,512	704,439
Diluted	769,384	736,754	708,619
LG&E and KU Energy LLC Unconsolidated [Member]
Other Income (Expense) - net [Abstract]
Equity in earnings of subsidiaries	$ 490	$ 477	$ 470
Interest Income from Affiliate	12	28	25
Other Income (Expense) - net	502	505	495
Interest Expense	23	30	29
Interest Expense with Affiliates	37	32	28
Income Before Income Taxes	442	443	438
Income Taxes	(8)	(25)	(7)
Net income	450	468	445
Total other comprehensive income (loss)	7	(4)	17
Comprehensive Income Attributable to PPL Shareowners	$ 457	$ 464	$ 462

SCHEDULE I - CONDENSED UNCONS_2

SCHEDULE I - CONDENSED UNCONSOLIDATED STATEMENTS OF CASH FLOWS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Cash Flows from Investing Activities [Abstract]
Net cash provided by (used in) investing activities	$ (3,258)	$ (3,080)	$ (3,361)
Cash Flows from Financing Activities [Abstract]
Issuance of equity, net of issuance costs	34	1,167	698
Net increase (decrease) in short-term debt	127	(278)	363
Retirement of long-term debt	(1,172)	(300)	(277)
Issuance of long-term debt	2,167	1,465	1,059
Payment of common stock dividends	(1,275)	(1,192)	(1,133)
Other	(41)	(26)	(20)
Net cash provided by (used in) financing activities	386	836	690
Cash and Cash Equivalents at Beginning of Period	815
Cash and Cash Equivalents at End of Period	708	815
LG&E and KU Energy LLC Unconsolidated [Member]
Cash Flows from Operating Activities [Abstract]
Net Cash Provided by (Used in) Operating Activities, Continuing Operations	371	368	346
Cash Flows from Investing Activities [Abstract]
Capital contributions to affiliated subsidiaries	(231)	(93)	(128)
Net decrease (increase) in notes receivable from affiliates	5	(44)	(26)
Net cash provided by (used in) investing activities	(226)	(137)	(154)
Cash Flows from Financing Activities [Abstract]
Net increase (decrease) in notes payable to affiliates	613	14	110
Retirement of long-term debt	(475)	0	0
Contributions from member	0	63	0
Distributions to member	(283)	(308)	(302)
Net cash provided by (used in) financing activities	(145)	(231)	(192)
Net Increase (Decrease) in Cash and Cash Equivalents	0	0	0
Cash and Cash Equivalents at Beginning of Period	0	0	0
Cash and Cash Equivalents at End of Period	0	0	0
Supplemental Disclosures of Cash Flow Information: [Abstract]
Cash Dividends Received from Subsidiaries	361	411	402
LG And E And KU Energy LLC [Member]
Cash Flows from Investing Activities [Abstract]
Net cash provided by (used in) investing activities	(963)	(1,094)	(1,116)
Cash Flows from Financing Activities [Abstract]
Net increase (decrease) in notes payable to affiliates	101	37	(112)
Net increase (decrease) in short-term debt	4	(126)	270
Retirement of long-term debt	(975)	(200)	(27)
Issuance of long-term debt	498	705	118
Contributions from member	0	63	0
Other	(6)	(12)	(2)
Net cash provided by (used in) financing activities	(38)	159	195
Cash and Cash Equivalents at Beginning of Period	27	24	30
Cash and Cash Equivalents at End of Period	$ 29	$ 27	$ 24

Quarterly Financial Data (Unaud

Quarterly Financial Data (Unaudited) (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Nov. 30, 2020	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Quarterly Financial Information Disclosure [Line Items]
Operating Revenues		$ 7,607	$ 7,769	$ 7,785
Operating income		$ 2,803	$ 2,840	$ 2,852
Net income (loss) available to PPL common shareowners: [Abstract]
Basic (in dollars per share)		$ 1.91	$ 2.39	$ 2.59
Diluted (in dollars per share)		1.91	2.37	2.58
Dividends declared per share of common stock (in dollars per share)	$ 0.4150	$ 1.66	$ 1.65	$ 1.64
PPL Electric Utilities Corp [Member]
Quarterly Financial Information Disclosure [Line Items]
Operating Revenues		$ 2,331	$ 2,358	$ 2,277
Operating income		$ 817	$ 745	$ 694

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2020
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 distribution of electricity in the U.K.; 2) the generation, transmission, distribution and sale of electricity and the distribution and sale of natural gas, primarily in Kentucky; and 3) the transmission, distribution and sale of electricity in Pennsylvania. Headquartered in Allentown, PA, PPL's principal subsidiaries are PPL Global, LKE (including its principal subsidiaries, LG&E and KU) and PPL Electric. PPL's corporate level financing subsidiary is PPL Capital Funding. WPD, a subsidiary of PPL Global, through wholly owned subsidiaries, operates distribution networks providing electricity service in the U.K. WPD serves end-users in South Wales and southwest and central England. Its principal subsidiaries are WPD (South Wales), WPD (South West), WPD (East Midlands) and WPD (West Midlands). PPL consolidates WPD on a one-month lag. Material events, such as debt issuances that occur in the lag period, are recognized in the current period financial statements. Events that are significant but not material are disclosed. (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, LKE, LG&E and KU) LKE is a utility holding company with cost-based rate-regulated utility operations through its subsidiaries, 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. 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. All significant intercompany transactions have been eliminated. The financial statements of PPL, LKE, 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 (PPL) WPD operates in an incentive-based regulatory structure under distribution licenses granted by Ofgem. Electricity distribution revenues are set by Ofgem for a given time period through price control reviews that are not directly based on cost recovery. The price control formula that governs WPD's allowed revenue is designed to provide economic incentives to minimize operating, capital and financing costs. As a result, WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP and does not record regulatory assets and liabilities. (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, primarily associated with PPL's investments in U.K. subsidiaries. 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 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 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. These transactions generally include foreign currency forwards and options to hedge GBP-denominated earnings translation risk associated with PPL's U.K. subsidiaries that report their financial statements in GBP. As such, these transactions reduce earnings volatility due solely to changes in foreign currency exchange rates. PPL also hedges anticipated transactions, including the previously announced potential 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 LKE, LG&E and KU, unbilled revenues for a month are calculated by multiplying an estimate of unbilled kWh by the estimated average cents per kWh. 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. (PPL) WPD is currently operating under the eight-year price control period of RIIO-ED1, which commenced for electric distribution companies on April 1, 2015. Ofgem has adopted a price control mechanism that establishes the amount of base demand revenue WPD can earn, subject to certain true-ups, and provides for increased or reduced revenues based on incentives or penalties for performance relative to pre-established targets. WPD's allowed revenue primarily includes base demand revenue (adjusted for inflation using RPI), performance incentive revenues/penalties and adjustments for over or under-recovery from prior periods. As the regulatory model is incentive based rather than a cost recovery model, WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP. Therefore, the accounting treatment of adjustments to base demand revenue and/or allowed revenue is evaluated based on revenue recognition accounting guidance. Unlike prior price control reviews, base demand revenue under RIIO-ED1 is adjusted during the price control period. The most significant of those adjustments are: • Inflation True-Up - The base demand revenue for the RIIO-ED1 period was set based on 2012/13 prices. Therefore, an inflation factor as determined by forecasted RPI, provided by HM Treasury, is applied to base demand revenue. Forecasted RPI is trued up to actuals and affects future base demand revenue two • Annual Iteration Process (AIP) - The RIIO-ED1 price control period also includes an AIP. This allows future base demand revenues agreed with Ofgem as part of the price control review, to be updated during the price control period for financial adjustments including tax, pensions, cost of debt, legacy price control adjustments from preceding price control periods and adjustments relating to actual and allowed total expenditure, together with the Totex Incentive Mechanism (TIM). Under the TIM, WPD's DNOs are able to retain 70% of any amounts not spent against the RIIO-ED1 plan and bear 70% of any over-spends. The AIP calculates an incremental change to base demand revenue, known as the "MOD" adjustment. As both MOD and TRU are changes to future base demand revenues as determined by Ofgem, these adjustments are recognized as a component of revenues in future years in which service is provided and revenues are collected or returned to customers. In addition to base demand revenue, certain other items are added or subtracted to arrive at allowed revenue. The most significant of these are: • Incentives - Ofgem has established incentives to provide opportunities for DNO's to enhance overall returns by improving network efficiency, reliability and customer service. These incentives can result in an increase or reduction in revenues based on incentives or penalties for actual performance against pre-established targets based on past performance. The annual incentives and penalties are reflected in customers' rates on a two • Correction Factor - During the current price control period, WPD sets its tariffs to recover allowed revenue. However, in any fiscal period, WPD's revenue could be negatively affected if its tariffs and the volume delivered do not fully recover the revenue allowed for a particular period. Conversely, WPD could also over-recover revenue. Over and under-recoveries are subtracted from or added to allowed revenue in future years when billed to customers, known as the "Correction Factor" or "K-factor." Over and under-recovered amounts arising for the period are refunded/recovered on a two Financing 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. Current Expected Credit Losses Financing receivable collectibility is evaluated using 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, LKE, LG&E and KU) LKE, 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 “accounts receivable-customer” except as noted. Additions Balance at Charged to Income Charged to Other Accounts Deductions (b) Balance at PPL 2020 (a) $ 60 (a) $ 31 $ — $ 16 $ 75 (c) (d) 2019 56 37 3 38 58 2018 51 41 3 39 56 PPL Electric 2020 $ 30 (a) $ 19 $ — $ 8 $ 41 (c) 2019 27 26 — 25 28 2018 24 29 — 26 27 LKE 2020 $ 28 $ 9 $ — $ 5 $ 32 (d) 2019 27 8 3 10 28 2018 25 10 3 11 27 LG&E 2020 $ 1 $ 4 $ — $ 2 $ 3 2019 1 2 2 4 1 2018 1 4 1 5 1 KU 2020 $ 1 $ 4 $ — $ 3 $ 2 2019 2 4 1 6 1 2018 1 5 2 6 2 (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 receivables. (d) Includes $27 million related to other receivables. Cash (All Registrants) Cash Equivalents All highly liquid investments with original maturities of three months or less are considered to be cash equivalents. (PPL and PPL Electric) 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: PPL PPL Electric December 31, December 31, December 31, December 31, Cash and cash equivalents $ 708 $ 815 $ 40 $ 262 Restricted cash - current 1 3 — 2 Restricted cash - noncurrent (a) 18 18 — — Total Cash, Cash Equivalents and Restricted Cash $ 727 $ 836 $ 40 $ 264 (a) 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. On the Balance Sheets, the current portion of restricted cash is included in "Other current assets," while the noncurrent portion is included in "Other noncurrent assets." (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 (All Registrants) 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. Short-term Investments 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) PPL capitalizes interest costs as part of construction costs. Capitalized interest, including the debt component of AFUDC for PPL, was $9 million in 2020, $10 million in 2019 and $15 million 2018. (PPL Electric) PPL Electric capitalizes interest costs as part of construction costs. Capitalized interest, including the debt component of AFUDC for PPL Electric was $7 million in 2020, $8 million in 2019 and $7 million in 2018. 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 LKE, LG&E and KU, all ARO depreciation expenses are reclassified to a regulatory asset. 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: 2020 2019 2018 PPL 2.81 % 2.84 % 2.77 % PPL Electric 2.99 % 3.05 % 3.01 % LKE 4.00 % 3.96 % 3.69 % LG&E 4.00 % 3.87 % 3.63 % KU 4.00 % 4.02 % 3.74 % (All Registrants) Goodwill and Other Intangible Assets 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) 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, LKE, 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, LKE's, LG&E's and KU's reporting units are primarily at the operating segment level. PPL, LKE, 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 first quarter of 2020, PPL, LKE, LG&E and KU considered whether the economic events associated with COVID-19, which resulted in PPL's shares experiencing volatility and a decrease in market value, would more likely than not reduce the fair value of the Registrants’ reporting units below their carrying amounts. Based on the assessment, a quantitative impairment test was not required for the LKE, LG&E and KU reporting units, but was required for the U.K. Regulated segment reporting unit, the allocated goodwill of which was $2.5 billion at March 31, 2020. The test did not indicate impairment of the reporting unit. In the fourth quarter of 2020, PPL (for its U.K. Regulated and Kentucky Regulated segments), and individually, LKE, LG&E and KU elected to perform qualitative step zero evaluations for their annual goodwill impairment tests, as of October 1, 2020. 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, LKE, 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 incr

Segment and Related Information

Segment and Related Information	12 Months Ended
	Dec. 31, 2020
Segment Reporting [Abstract]
Segment and Related Information	(PPL) PPL is organized into three segments: U.K. Regulated, Kentucky Regulated and Pennsylvania Regulated. PPL's segments are segmented by geographic location. The U.K. Regulated segment consists of PPL Global, which primarily includes WPD's regulated electricity distribution operations, the results of hedging the translation of WPD's earnings from GBP into U.S. dollars, and certain costs, such as U.S. income taxes, administrative costs, and certain acquisition-related financing costs. The Kentucky Regulated segment consists primarily of LKE's regulated electricity generation, transmission and distribution operations conducted by LG&E and KU, as well as LG&E's regulated distribution and sale of natural gas. In addition, certain acquisition-related financing costs are allocated to the Kentucky Regulated segment. The Pennsylvania Regulated segment includes the regulated electricity transmission and distribution operations of PPL Electric. In addition, certain costs are allocated to the Pennsylvania Regulated segment. "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. Income Statement data for the segments and reconciliation to PPL's consolidated results for the years ended December 31 are as follows: 2020 2019 2018 Operating Revenues from external customers (a) U.K. Regulated $ 2,133 $ 2,167 $ 2,268 Kentucky Regulated 3,106 3,206 3,214 Pennsylvania Regulated 2,330 2,358 2,277 Corporate and Other 38 38 26 Total $ 7,607 $ 7,769 $ 7,785 Depreciation U.K. Regulated $ 265 $ 250 $ 247 Kentucky Regulated 606 547 475 Pennsylvania Regulated 403 386 352 Corporate and Other 13 16 20 Total $ 1,287 $ 1,199 $ 1,094 Amortization (b) U.K. Regulated $ 16 $ 25 $ 34 Kentucky Regulated 19 27 18 Pennsylvania Regulated 26 24 22 Corporate and Other 11 5 4 Total $ 72 $ 81 $ 78 Unrealized (gains) losses on derivatives and other hedging activities (c) U.K. Regulated $ 271 $ 62 $ (190) Kentucky Regulated 5 6 6 Corporate and Other 4 5 (2) Total $ 280 $ 73 $ (186) Interest Expense U.K. Regulated $ 400 $ 405 $ 413 Kentucky Regulated 300 298 274 Pennsylvania Regulated 172 169 159 Corporate and Other 129 122 117 Total $ 1,001 $ 994 $ 963 Income Before Income Taxes U.K. Regulated $ 958 $ 1,169 $ 1,339 Kentucky Regulated 516 530 531 Pennsylvania Regulated 664 607 567 Corporate and Other (167) (151) (152) Total $ 1,971 $ 2,155 $ 2,285 2020 2019 2018 Income Taxes (d) U.K. Regulated $ 272 $ 192 $ 225 Kentucky Regulated 98 94 120 Pennsylvania Regulated 167 149 136 Corporate and Other (35) (26) (23) Total $ 502 $ 409 $ 458 Deferred income taxes and investment tax credits (e) U.K. Regulated $ 233 $ 140 $ 118 Kentucky Regulated 64 82 94 Pennsylvania Regulated 82 90 125 Corporate and Other 23 (3) 18 Total $ 402 $ 309 $ 355 Net Income U.K. Regulated $ 686 $ 977 $ 1,114 Kentucky Regulated 418 436 411 Pennsylvania Regulated 497 458 431 Corporate and Other (132) (125) (129) Total $ 1,469 $ 1,746 $ 1,827 (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, debt discounts and premiums and debt issuance costs. (c) Includes unrealized gains and losses from economic activity. See Note 18 for additional information. (d) Represents both current and deferred income taxes, including investment tax credits. See Note 6 for additional information on the impact of the TCJA in 2018. (e) 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: 2020 2019 2018 Expenditures for long-lived assets U.K. Regulated $ 995 $ 857 $ 954 Kentucky Regulated 966 1,097 1,117 Pennsylvania Regulated 1,154 1,121 1,196 Corporate and Other 158 32 1 Total $ 3,273 $ 3,107 $ 3,268 The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated results as of: As of December 31, 2020 2019 Total Assets U.K. Regulated (a) $ 19,094 $ 17,622 Kentucky Regulated 15,943 15,597 Pennsylvania Regulated 12,347 11,918 Corporate and Other (b) 732 543 Total $ 48,116 $ 45,680 (a) Includes $14.4 billion and $13.2 billion of net PP&E as of December 31, 2020 and December 31, 2019. WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP. (b) Primarily consists of unallocated items, including cash, PP&E, goodwill, the elimination of inter-segment transactions as well as the assets of Safari Energy. Geographic data for the years ended December 31 are as follows: 2020 2019 2018 Revenues from external customers U.K. $ 2,133 $ 2,167 $ 2,268 U.S. 5,474 5,602 5,517 Total $ 7,607 $ 7,769 $ 7,785 As of December 31, 2020 2019 Long-Lived Assets U.K. $ 14,805 $ 13,618 U.S. 24,851 23,607 Total $ 39,656 $ 37,225 (PPL Electric, LKE, LG&E and KU) PPL Electric has two operating segments that are aggregated into a single reportable segment. LKE, 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, 2020
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) U.K. Regulated Segment Revenue The U.K. Regulated Segment generates revenues from contracts with customers primarily from WPD’s DUoS operations. DUoS revenues result from WPD charging licensed third-party energy suppliers for their use of WPD’s distribution systems to deliver energy to their customers. WPD satisfies its performance obligation and DUoS revenue is recognized over-time as electricity is delivered. The amount of revenue recognized is based on actual and forecasted volumes of electricity delivered during the period multiplied by a per-unit energy tariff, plus fixed charges. This method of recognition fairly presents WPD's transfer of electric service to the customer as the calculation is based on volumes, and the tariff rate is set by WPD using a methodology prescribed by Ofgem. Customers are billed monthly and outstanding amounts are typically due within 14 days of the invoice date. DUoS customers are “at will” customers of WPD 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 WPD’s DUoS contracts. (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, LKE, 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: 2020 PPL PPL Electric LKE LG&E KU Operating Revenues (a) $ 7,607 $ 2,331 $ 3,106 $ 1,456 $ 1,690 Revenues derived from: Alternative revenue programs (b) (24) (12) (12) (8) (4) Other (c) (27) (3) (17) (7) (10) Revenues from Contracts with Customers $ 7,556 $ 2,316 $ 3,077 $ 1,441 $ 1,676 2019 PPL PPL Electric LKE LG&E KU Operating Revenues (a) $ 7,769 $ 2,358 $ 3,206 $ 1,500 $ 1,740 Revenues derived from: Alternative revenue programs (b) (30) (6) (24) (10) (14) Other (c) (38) (10) (21) (9) (12) Revenues from Contracts with Customers $ 7,701 $ 2,342 $ 3,161 $ 1,481 $ 1,714 2018 PPL PPL Electric LKE LG&E KU Operating Revenues (a) $ 7,785 $ 2,277 $ 3,214 $ 1,496 $ 1,760 Revenues derived from: Alternative revenue programs (b) 32 (6) 38 12 26 Other (c) (38) (12) (17) (5) (12) Revenues from Contracts with Customers $ 7,779 $ 2,259 $ 3,235 $ 1,503 $ 1,774 (a) For the years ended December 31, 2020 and 2019, PPL includes $2.1 billion and $2.2 billion of revenues from external customers reported by the U.K. Regulated segment. PPL Electric and LKE represent revenues from external customers reported by the Pennsylvania Regulated and Kentucky Regulated segments. 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 program for LG&E, and the generation formula rate for KU. 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: 2020 PPL (d) PPL Electric (d) LKE LG&E KU Licensed energy suppliers (a) $ 1,990 $ — $ — $ — $ — Residential 2,585 1,238 1,347 676 671 Commercial 1,185 314 871 444 427 Industrial 582 44 538 173 365 Other (b) 484 50 261 114 147 Wholesale - municipal 20 — 20 — 20 Wholesale - other (c) 40 — 40 34 46 Transmission 670 670 — — — Revenues from Contracts with Customers $ 7,556 $ 2,316 $ 3,077 $ 1,441 $ 1,676 2019 PPL (d) PPL Electric (d) LKE LG&E KU Licensed energy suppliers (a) $ 2,032 $ — $ — $ — $ — Residential 2,610 1,288 1,322 668 654 Commercial 1,257 349 908 466 442 Industrial 621 59 562 180 382 Other (b) 495 52 277 121 156 Wholesale - municipal 43 — 43 — 43 Wholesale - other (c) 49 — 49 46 37 Transmission 594 594 — — — Revenues from Contracts with Customers $ 7,701 $ 2,342 $ 3,161 $ 1,481 $ 1,714 2018 PPL PPL Electric LKE LG&E KU Licensed energy suppliers (a) $ 2,127 $ — $ — $ — $ — Residential 2,704 1,379 1,325 666 659 Commercial 1,233 368 865 455 410 Industrial 624 54 570 180 390 Other (b) 489 53 278 129 149 Wholesale - municipal 118 — 118 — 118 Wholesale - other (c) 79 — 79 73 48 Transmission 405 405 — — — Revenues from Contracts with Customers $ 7,779 $ 2,259 $ 3,235 $ 1,503 $ 1,774 (a) Represents customers of WPD. (b) Primarily includes revenues from pole attachments, street lighting, other public authorities and other non-core businesses. (c) Includes wholesale power and transmission revenues. LG&E and KU amounts include intercompany power sales and transmission revenues, which are eliminated upon consolidation at LKE. (d) In 2020 and 2019, management deemed it appropriate to present the revenue offset associated with network integration transmission service (NITS) as distribution revenue rather than transmission revenue. 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: 2020 2019 2018 PPL $ 29 $ 27 $ 34 PPL Electric 17 21 24 LKE 8 6 9 LG&E 4 2 4 KU 4 4 5 The following table shows the balances and certain activity of contract liabilities resulting from contracts with customers: PPL PPL Electric LKE LG&E KU Contract liabilities as of December 31, 2020 $ 48 $ 23 $ 11 $ 5 $ 6 Contract liabilities as of December 31, 2019 44 21 9 5 4 Revenue recognized during the year ended December 31, 2020 that was included in the contract liability balance at December 31, 2019 29 9 9 5 4 Contract liabilities as of December 31, 2019 $ 44 $ 21 $ 9 $ 5 $ 4 Contract liabilities as of December 31, 2018 42 23 9 5 4 Revenue recognized during the year ended December 31, 2019 that was included in the contract liability balance at December 31, 2018 32 11 9 5 4 Contract liabilities as of December 31, 2018 $ 42 $ 23 $ 9 $ 5 $ 4 Contract liabilities as of December 31, 2017 29 19 8 4 4 Revenue recognized during the year ended December 31, 2018 that was included in the contract liability balance at December 31, 2017 21 8 8 4 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, 2020, 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 $46 million within the next 12 months.

Preferred Securities

Preferred Securities	12 Months Ended
	Dec. 31, 2020
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 2020, 2019 or 2018. (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 2020, 2019 or 2018. (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 2020, 2019 or 2018. (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 2020, 2019 or 2018.
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 2020, 2019 or 2018. (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 2020, 2019 or 2018. (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 2020, 2019 or 2018. (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 2020, 2019 or 2018.
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 2020, 2019 or 2018. (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 2020, 2019 or 2018. (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 2020, 2019 or 2018. (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 2020, 2019 or 2018.
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 2020, 2019 or 2018. (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 2020, 2019 or 2018. (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 2020, 2019 or 2018. (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 2020, 2019 or 2018.

Income and Other Taxes

Income and Other Taxes	12 Months Ended
	Dec. 31, 2020
Income Tax Disclosure [Abstract]
Income and Other Taxes	6. Income and Other Taxes (PPL) "Income Before Income Taxes" included the following: 2020 2019 2018 Domestic income $ 902 $ 964 $ 1,127 Foreign income 1,069 1,191 1,158 Total $ 1,971 $ 2,155 $ 2,285 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 for the U.S. and the U.K. Significant components of PPL's deferred income tax assets and liabilities were as follows: 2020 2019 Deferred Tax Assets Deferred investment tax credits $ 30 $ 31 Regulatory liabilities 68 75 Income taxes due to customers 444 462 Accrued pension and postretirement costs 106 211 Federal loss carryforwards 234 324 State loss carryforwards 448 432 Federal and state tax credit carryforwards 401 402 Foreign capital loss carryforwards 370 320 Foreign - other 6 8 Contributions in aid of construction 115 112 Domestic - other 136 99 Valuation allowances (906) (834) Total deferred tax assets 1,452 1,642 Deferred Tax Liabilities Domestic plant - net 3,700 3,546 Regulatory assets 195 262 Foreign plant - net 911 765 Foreign - pensions 127 72 Domestic - other 70 61 Total deferred tax liabilities 5,003 4,706 Net deferred tax liability $ 3,551 $ 3,064 State deferred taxes are determined by entity and by jurisdiction. As a result, $17 million and $24 million of net deferred tax assets are shown as "Other noncurrent assets" on the Balance Sheets for 2020 and 2019. At December 31, 2020, 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 Federal net operating losses $ 1,111 $ 234 $ — 2035-2037 State net operating losses 6,032 448 (419) 2021-2040 Foreign capital losses (a) 1,945 370 (370) Indefinite Federal - Other 13 2 — Indefinite State - Other 2 — — Indefinite Credit carryforwards Federal investment tax credit 134 — 2025-2040 Federal foreign tax credits (b) 218 (113) 2024-2027 Federal - other 32 (4) 2021-2040 State Recycling Credit 16 — 2028 State - other 1 — Indefinite (a) 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. (b) Includes $62 million of foreign tax credits carried forward from 2016 and $156 million of additional foreign tax credits from 2017 related to the taxable deemed dividend associated with the TCJA. 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 2020 $ 834 $ 69 (a) $ 7 $ 4 $ 906 2019 808 31 — 5 834 2018 838 26 — 56 (b) 808 (a) The cancellation of the reduction of the U.K. statutory income tax rate in 2020 resulted in a $38 million increase in deferred tax assets and corresponding valuation allowances. See "Reconciliation of Income Tax Expense" below for additional information on the impact of the U.K. Finance Act 2020. In addition, deferred tax assets and corresponding valuation allowances were increased in 2020 by approximately $11 million due to the effect of foreign currency exchange rates. (b) Decrease in the valuation allowance of approximately $35 million due to the change in the total foreign tax credits available after finalization of the deemed dividend calculation required by the TCJA in 2017. In addition, the deferred tax assets and corresponding valuation allowances were reduced in 2018 by approximately $19 million due to the effect of foreign currency exchange rates. A U.S. based company with foreign subsidiaries may be required to record deferred taxes associated with the reversal of differences in the outside book-tax basis of those subsidiaries. The primary component of such outside basis differences is ordinarily accumulated unremitted earnings. PPL Global does not record deferred U.S. income taxes associated with the accumulated unremitted earnings of WPD, as management has determined that such earnings are indefinitely reinvested. Current year distributions from WPD to the U.S. are sourced from a portion of the current year’s earnings of the WPD group. There have been no material changes to the facts underlying PPL’s assertion that historically reinvested earnings of WPD as well as some portion of current year earnings will continue to be indefinitely reinvested. WPD's long-term working capital forecasts and capital expenditure projections for the foreseeable future require reinvestment of WPD's undistributed earnings. Additionally, U.S. long-term working capital forecasts and capital expenditure projections for the foreseeable future do not require or contemplate annual distributions from WPD in excess of some portion of WPD's future annual earnings. The cumulative undistributed earnings are included in "Earnings reinvested" on the Balance Sheets. The amount considered indefinitely reinvested at December 31, 2020 was $8.0 billion. It is not practicable to estimate the amount of additional taxes that could be payable on these foreign earnings in the event of repatriation to the U.S., but it could be material. PPL will reassess the indefinite reinvestment of these earnings if and when the U.K. utility business meets the criteria to be classified as held for sale. 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: 2020 2019 2018 Income Tax Expense (Benefit) Current - Federal $ (9) $ (10) $ (19) Current - State 24 19 17 Current - Foreign 85 91 104 Total Current Expense (Benefit) 100 100 102 Deferred - Federal 123 139 203 Deferred - State 94 76 100 Deferred - Foreign (a) 215 123 107 Total Deferred Expense (Benefit), excluding operating loss carryforwards 432 338 410 Amortization of investment tax credit (3) (3) (3) Tax expense (benefit) of operating loss carryforwards Deferred - Federal 6 7 (20) Deferred - State (33) (33) (31) Total Tax Expense (Benefit) of Operating Loss Carryforwards (27) (26) (51) Total income tax expense (benefit) $ 502 $ 409 $ 458 Total income tax expense (benefit) - Federal $ 117 $ 133 $ 161 Total income tax expense (benefit) - State 85 62 86 Total income tax expense (benefit) - Foreign 300 214 211 Total income tax expense (benefit) $ 502 $ 409 $ 458 (a) 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: 2020 2019 2018 Other comprehensive income $ (19) $ (93) $ (6) Total $ (19) $ (93) $ (6) 2020 2019 2018 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 414 $ 453 $ 480 Increase (decrease) due to: State income taxes, net of federal income tax benefit 48 45 40 Valuation allowance adjustments (a) 26 22 21 Impact of lower U.K. income tax rates (26) (25) (25) U.S. income tax on foreign earnings - net of foreign tax credit 11 2 3 Federal and state income tax return adjustments (9) 1 — Impact of the U.K. Finance Acts on deferred tax balances (b) 101 (14) (13) Depreciation and other items not normalized (5) (10) (11) Amortization of excess deferred federal and state income taxes (43) (40) (37) Interest benefit on U.K. financing activities (12) (12) (17) Deferred tax impact of Kentucky tax reform (c) — — 9 Kentucky recycling credit, net of federal income tax expense (d) — (18) — Other (3) 5 8 Total increase (decrease) 88 (44) (22) Total income tax expense (benefit) $ 502 $ 409 $ 458 Effective income tax rate 25.5% 19.0% 20.0% (a) In 2020, 2019 and 2018, PPL recorded deferred income tax expense of $24 million, $25 million and $24 million for valuation allowances primarily related to increased Pennsylvania net operating loss carryforwards expected to be unutilized. (b) In 2018 and 2019, PPL reduced its net deferred tax liabilities as a result of the U.K. Finance Act 2016 that was enacted in September 2016 and reduced the U.K. statutory income tax rate effective April, 2020 to 17%. In 2020, the U.K. Finance Act 2020 cancelled the tax rate reduction 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. (c) In 2018, PPL recorded deferred income tax expense, primarily associated with LKE’s non-regulated entities, due to the Kentucky corporate income tax rate reduction from 6% to 5%, as enacted by HB 487, effective January 1, 2018. (d) In 2019, LKE 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. 2020 2019 2018 Taxes, other than income State gross receipts $ 100 $ 107 $ 103 Foreign property 127 127 134 Domestic - other 80 79 75 Total $ 307 $ 313 $ 312 (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: 2020 2019 Deferred Tax Assets Accrued pension and postretirement costs $ 25 $ 81 Contributions in aid of construction 91 88 Regulatory liabilities 24 31 Income taxes due to customers 162 170 State loss carryforwards — 6 Federal loss carryforwards 52 78 Other 29 23 Total deferred tax assets 383 477 Deferred Tax Liabilities Electric utility plant - net 1,826 1,761 Regulatory assets 86 139 Other 30 24 Total deferred tax liabilities 1,942 1,924 Net deferred tax liability $ 1,559 $ 1,447 PPL Electric expects to have adequate levels of taxable income to realize its recorded deferred income tax assets. At December 31, 2020, PPL Electric had the following loss and tax credit carryforwards and related deferred tax assets: Gross Deferred Tax Asset Expiration Loss carryforwards Federal net operating losses $ 248 $ 52 2035-2037 Credit carryforwards Federal - other 5 2031-2040 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: 2020 2019 2018 Income Tax Expense (Benefit) Current - Federal $ 61 $ 44 $ 2 Current - State 23 15 9 Total Current Expense (Benefit) 84 59 11 Deferred - Federal 45 51 96 Deferred - State 38 39 37 Total Deferred Expense (Benefit), excluding operating loss carryforwards 83 90 133 Tax expense (benefit) of operating loss carryforwards Deferred - Federal — — (8) Total Tax Expense (Benefit) of Operating Loss Carryforwards — — (8) Total income tax expense (benefit) $ 167 $ 149 $ 136 Total income tax expense (benefit) - Federal $ 106 $ 95 $ 90 Total income tax expense (benefit) - State 61 54 46 Total income tax expense (benefit) $ 167 $ 149 $ 136 2020 2019 2018 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 139 $ 127 $ 119 Increase (decrease) due to: State income taxes, net of federal income tax benefit 52 47 43 Federal and state income tax return adjustments (4) 1 — Depreciation and other items not normalized (5) (10) (11) Amortization of excess deferred federal income taxes (a) (16) (18) (17) Other 1 2 2 Total increase (decrease) 28 22 17 Total income tax expense (benefit) $ 167 $ 149 $ 136 Effective income tax rate 25.2% 24.6% 24.0% (a) In 2020, 2019 and 2018, 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. 2020 2019 2018 Taxes, other than income State gross receipts $ 100 $ 107 $ 103 Property and other 7 5 6 Total $ 107 $ 112 $ 109 (LKE) The provision for LKE'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 LKE's deferred income tax assets and liabilities were as follows: 2020 2019 Deferred Tax Assets Federal loss carryforwards $ 107 $ 140 State loss carryforwards 28 31 Federal tax credit carryforwards 159 162 Contributions in aid of construction 23 23 Regulatory liabilities 43 44 Accrued pension and postretirement costs 57 71 State tax credit carryforwards 17 19 Income taxes due to customers 282 292 Deferred investment tax credits 30 31 Lease liabilities 13 14 Valuation allowances (4) (6) Other 29 28 Total deferred tax assets 784 849 Deferred Tax Liabilities Plant - net 1,831 1,778 Regulatory assets 109 122 Lease right-of-use assets 11 12 Other 8 6 Total deferred tax liabilities 1,959 1,918 Net deferred tax liability $ 1,175 $ 1,069 At December 31, 2020, LKE 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 carryforwards Federal net operating losses $ 511 $ 107 $ — 2035 - 2037 Federal charitable contributions 1 — — 2024 State net operating losses 710 28 — 2029 - 2038 Gross Deferred Tax Asset Valuation Allowance Expiration Credit carryforwards Federal investment tax credit 134 — 2025 - 2028, 2036 - 2040 Federal - other 25 (4) 2021-2040 State - recycling credit 16 — 2028 State - other 1 — Indefinite Changes in deferred tax valuation allowances were: Balance at Additions Deductions Balance 2020 $ 6 $ — $ 2 (a) $ 4 2019 8 3 5 (a) 6 2018 8 — — 8 (a) Tax credits expiring. 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: 2020 2019 2018 Income Tax Expense (Benefit) Current - Federal $ 41 $ 20 $ 31 Current - State 1 — 4 Total Current Expense (Benefit) 42 20 35 Deferred - Federal 43 81 65 Deferred - State (a) 24 5 34 Total Deferred Expense (Benefit), excluding benefits of operating loss carryforwards 67 86 99 Amortization of investment tax credit - Federal (3) (3) (3) Tax expense (benefit) of operating loss carryforwards Deferred - Federal — — (2) Total Tax Expense (Benefit) of Operating Loss Carryforwards — — (2) Total income tax expense (benefit) (b) $ 106 $ 103 $ 129 Total income tax expense (benefit) - Federal $ 81 $ 98 $ 91 Total income tax expense (benefit) - State 25 5 38 Total income tax expense (benefit) (b) $ 106 $ 103 $ 129 (a) In 2019, LKE 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. (b) Excludes deferred federal and state tax expense (benefit) recorded to OCI of $2 million in 2020, $(1) million in 2019 and $5 million in 2018. 2020 2019 2018 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 117 $ 120 $ 121 Increase (decrease) due to: State income taxes, net of federal income tax benefit 22 23 22 Amortization of investment tax credit (3) (3) (3) Amortization of excess deferred federal and state income taxes (28) (23) (20) Deferred tax impact of state tax reform (a) — — 9 Kentucky Recycling Credit, net of federal income tax expense (b) — (18) — Other (2) 4 — Total increase (decrease) (11) (17) 8 Total income tax expense (benefit) $ 106 $ 103 $ 129 Effective income tax rate 19.1% 18.0% 22.5% (a) In 2018, LKE recorded deferred income tax expense, primarily associated with LKE's non-regulated entities, due to the Kentucky corporate income tax rate reduction from 6% to 5%, as enacted by HB 487, effective January 1, 2018. (b) In 2019, LKE 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. 2020 2019 2018 Taxes, other than income Property and other $ 77 $ 74 $ 70 Total $ 77 $ 74 $ 70 (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: 2020 2019 Deferred Tax Assets Contributions in aid of construction $ 15 $ 15 Regulatory liabilities 20 19 Accrued pension and postretirement costs — 6 Deferred investment tax credits 8 8 Income taxes due to customers 132 136 State tax credit carryforwards 12 14 Lease liabilities 5 5 Valuation allowances (12) (14) Other 11 10 Total deferred tax assets 191 199 Deferred Tax Liabilities Plant - net 833 811 Regulatory assets 66 77 Lease right-of-use assets 4 4 Other 4 4 Total deferred tax liabilities 907 896 Net deferred tax liability $ 716 $ 697 At December 31, 2020 LG&E had $12 million of state credit carryforwards that expire in 2028 and a $12 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: 2020 2019 2018 Income Tax Expense (Benefit) Current - Federal $ 53 $ 4 $ — Current - State 7 4 4 Total Current Expense (Benefit) 60 8 4 Deferred - Federal (4) 46 51 Deferred - State 7 10 10 Total Deferred Expense (Benefit) 3 56 61 Amortization of investment tax credit - Federal (1) (1) (1) Total income tax expense (benefit) $ 62 $ 63 $ 64 Total income tax expense (benefit) - Federal $ 48 $ 49 $ 50 Total income tax expense (benefit) - State 14 14 14 Total income tax expense (benefit) $ 62 $ 63 $ 64 2020 2019 2018 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 64 $ 62 $ 62 Increase (decrease) due to: State income taxes, net of federal income tax benefit 12 12 11 Amortization of excess deferred federal and state income taxes (11) (10) (8) Kentucky recycling credit, net of federal income tax expense (a) — (14) — Valuation allowance adjustments (a) — 14 — Other (3) (1) (1) Total increase (decrease) (2) 1 2 Total income tax expense (benefit) $ 62 $ 63 $ 64 Effective income tax rate 20.3% 21.4% 21.5% (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. 2020 2019 2018 Taxes, other than income Property and other $ 40 $ 39 $ 36 Total $ 40 $ 39 $ 36 (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: 2020 2019 Deferred Tax Assets Contributions in aid of construction $ 8 $ 8 Regulatory liabilities 23 25 Deferred investment tax credits 22 23 Income taxes due to customers 150 156 State tax credit carryforwards 5 5 Lease liabilities 8 8 Valuation allowances (4) (4) Other 4 3 Total deferred tax assets 216 224 Deferred Tax Liabilities Plant - net 992 959 Regulatory assets 43 45 Accrued pension and postretirement costs 8 2 Lease right-of-use assets 7 7 Other 1 3 Total deferred tax liabilities 1,051 1,016 Net deferred tax liability $ 835 $ 792 At December 31, 2020 KU had $5 million of state credit carryforwards of which $4 million will expire in 2028 and $1 million that has an indefinite carryforward period. At December 31, 2020 KU had a $4 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: 2020 2019 2018 Income Tax Expense (Benefit) Current - Federal $ 40 $ 35 $ 22 Current - State 3 5 6 Total Current Expense (Benefit) 43 40 28 Deferred - Federal 11 28 40 Deferred - State 11 13 10 Total Deferred Expense (Benefit) 22 41 50 Amortization of investment tax credit - Federal (2) (2) (2) Total income tax expense (benefit) $ 63 $ 79 $ 76 Total income tax expense (benefit) - Federal $ 49 $ 61 $ 60 Total income tax expense (benefit) - State 14 18 16 Total income tax expense (benefit) $ 63 $ 79 $ 76 2020 2019 2018 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 72 $ 78 $ 76 Increase (decrease) due to: State income taxes, net of federal income tax benefit 14 15 13 Amortization of investment tax credit (2) (2) (2) Amortization of excess deferred federal and state income taxes (17) (13) (12) Kentucky recycling credit, net of federal income tax expense (a) — (4) — Valuation allowance adjustments (a) — 4 — Other (4) 1 1 Total increase (decrease) (9) 1 — Total income tax expense (benefit) $ 63 $ 79 $ 76 Effective income tax rate 18.4% 21.2% 21.0% (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. 2020 2019 2018 Taxes, other than income Property and other $ 37 $ 35 $ 34 Total $ 37 $ 35 $ 34 (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 LKE, LG&E and KU or their subsidiaries indirectly or directly file tax returns in two major tax jurisdictions. With few exceptions, at December 31, 2020, these jurisdictions, as well as the tax years that are no longer subject to examination, were as follows. PPL PPL Electric LKE LG&E KU U.S. (federal) 2016 and prior 2016 and prior 2016 and prior 2016 and prior 2016 and prior Pennsylvania (state) 2016 and prior 2016 and prior Kentucky (state) 2014 and prior 2014 and prior 2014 and prior 2014 and prior U.K. (foreign) 2016 and prior Tax Cuts and Jobs Act (TCJA) On December 22, 2017, the TCJA was signed into law. Substantially all of the provisions of the TCJA were effective for taxable years beginning after December 31, 2017. The TCJA included significant changes to the taxation of corporations, including provisions specifically applicable to regulated public utilities. The more significant changes that impact the Registrants were: • The reduction in the U.S. federal corporate income tax rate from a top marginal rate of 35% to a flat rate of 21%, effective January 1, 2018; • The exclusion from U.S. federal taxable income of dividends from foreign subsidiaries and the associated "transition tax;" • Limitations on the tax deductibility of interest expense, with an exception to these limitations for regulated public utilities; • Full current year expensing of capital expenditures with an exception for regulated public utilities for capital projects commencing after December 31, 2017 that qualify for the exception to the interest expense limitation; and • The continuation of certain rate normalization requirements for accelerated depreciation benefits. For non-regulated businesses, the TCJA generally provides for full expensing of property acquired after September 27, 2017. 2018 Impacts of TCJA The Registrants recognized certain provisional amounts relating to the impact of the enactment of the TCJA in their December 31, 2017 financial statements, in accordance with SEC guidance. Included in those provisional amounts were estimates of tax depreciation, deductible executive compensation, accumulated foreign earnings, foreign tax credits, and deemed dividends from foreign subsidiaries, all of which were based on the interpretation and application of various provisions of the TCJA. In the third quarter of 2018, PPL filed its consolidated federal income tax return, which was prepared using guidance issued by the U.S. Treasury Department and the IRS since the filing of each Registrant's 2017 Form 10-K. Accordingly, the Registrants updated the following provisional amounts and now consider them to be complete: (1) the amount of the deemed dividend and associated foreign tax credits relating to the transition tax imposed on accumulated foreign earnings as of December 31, 2017; (2) the amount of accelerated 100% "bonus" depreciation PPL was eligible to claim in its 2017 federal income tax return; and (3) the related impacts on PPL's 2017 consolidated federal net operating loss to be carried forward to future periods. In addition, the Registrants recorded the tax impact of the U.S. federal corporate income tax rate reduction from 35% to 21% on the changes to deferred tax assets and liabilities resulting from the completed provisional amounts. The completed provisional amounts related to the tax rate reduction had an insignificant impact on the net regulatory liabilities of PPL's U.S. regulated operations. In the fourth quarter of 2018, PPL completed its analysis of the deductibility of executive compensation awarded as of November 2, 2017 and concluded that no material change to the provisional amounts was required. The final amounts reported in PPL's 2017 federal income tax return, provisional amounts for the year ended December 31, 2017, the related measurement period adjustments, and the resulting tax impact for the year ended December 31, 2018 were as follows. Taxable Income (Loss) (a) Adjustments per 2017 Tax Return Adjustments per 2017 Tax Provision 2018 Adjustments PPL Deemed Dividend $ 397 $ 462 $ (65) Bonus Depreciation (b) (67) — (67) Consolidated Federal Net Operating Loss due to the TCJA (c) (330) (462) 132 Total $ — $ — $ — PPL Electric Bonus Depreciation (b) $ (39) $ — $ (39) Consolidated Federal Net Operating Loss reallocated due to the TCJA (c) (68) (105) 37 Total $ (107) $ (105) $ (2) LKE Bonus Depreciation (b) $ (28) $ — $ (28) Consolidated Federal Net Operating Loss reallocated due to the TCJA (c) (32) (45) 13 Total $ (60) $ (45) $ (15) LG&E Bonus Depreciation (b) $ (17) $ — $ (17) Consolidated Federal Net Operating Loss reallocated due to the TCJA (c) 17 — 17 Total $ — $ — $ — KU Bonus Depreciation (b) $ (11) $ — $ (11) Consolidated Federal Net Operating Loss reallocated due to the TCJA (c) 11 — 11 Total $ — $ — $ — (a) The above table reflects, for each item, the amount subject to change as a result of the TCJA and does not reflect the total amount of each item included in the return and the provision. (b) The TCJA increased the bonus depreciation percentage from 50% to 100% for qualified property acquired and placed in service after September 27, 2017 and before January 1, 2018. Increases in tax depreciation reduce the Registrants' taxes payable and increase net deferred tax liabilities with no impact to “Income Taxes” on the Statements of Income. (c) An increase in the consolidated federal net operating loss reduces net deferred tax liabilities with the opposite effect if there is a decrease in the consolidated federal net operating loss. These increases or decreases have no impact to “Income Taxes” on the Statements of Income. Income Tax Expense (Benefit) Adjustments per 2017 Tax Return Adjustments per 2017 Tax Provision 2018 Adjustments PPL Deemed Dividend $ 139 $ 161 $ (22) Foreign Tax Credits (157) (205) 48 Valuation of Foreign Tax Credit Carryforward 110 145 (35) Reduction in U.S. federal income tax rate 229 220 9 Total $ 321 $ 321 $ — PPL Electric Reduction in U.S. federal income tax rate $ (13) $ (13) $ — LKE Reduction in U.S. federal income tax rate $ 110 $ 112 $ (2) The Registrants' accounting related to the effects of the TCJA on financial results for the period ended December 31, 2017 was complete as of December 31, 2018 with respect to all provisional amounts. TCJA Regulatory Update The IRS issued proposed regulations for certain provisions of the TCJA in 2018, including interest deductibility and Global Intangible Low-Taxed Income (GILTI). In 2019, final and new proposed regulations were issued relating to the GILTI provisions. PPL has determined that neither the final or new proposed regulations materially change PPL's conclusion that currently no incremental tax arises under these rules. Proposed regulations relating to the limitation on the deductibility of interest expense were issued in November 2018 and such regulations provide detailed rules implementing the broader statutory provisions. These proposed regulations did not apply to the Registrants in 2019.

Utility Rate Regulation

Utility Rate Regulation	12 Months Ended
	Dec. 31, 2020
Utility Rate Regulation [Line Items]
Utility Rate Regulation	7. Utility Rate Regulation Regulatory Assets and Liabilities (All Registrants) PPL, PPL Electric, LKE, 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) WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP and does not record regulatory assets and liabilities. See Note 1 for additional information. (PPL, LKE, 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 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, LKE and KU) KU's Virginia base rates are calculated based on 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, 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 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 2020 2019 2020 2019 Current Regulatory Assets: Plant outage costs $ 46 $ 32 $ — $ — Gas supply clause 4 8 — — Smart meter rider 17 13 17 13 Storm costs 7 — 7 — Transmission formula rate 15 3 15 3 Transmission service charge — 10 — 10 Other 10 1 1 — Total current regulatory assets (a) $ 99 $ 67 $ 40 $ 26 Noncurrent Regulatory Assets: Defined benefit plans $ 570 $ 800 $ 290 $ 467 Storm costs 17 39 — 15 Unamortized loss on debt 30 41 8 18 Interest rate swaps 23 22 — — Terminated interest rate swaps 75 81 — — Accumulated cost of removal of utility plant 240 220 240 220 AROs 300 279 — — Act 129 compliance rider — 6 — 6 Other 7 4 3 — Total noncurrent regulatory assets $ 1,262 $ 1,492 $ 541 $ 726 PPL PPL Electric 2020 2019 2020 2019 Current Regulatory Liabilities: Generation supply charge $ 21 $ 23 $ 21 $ 23 Environmental cost recovery 4 5 — — Universal service rider 22 9 22 9 Fuel adjustment clause 5 8 — — TCJA customer refund 11 61 11 59 Storm damage expense rider 6 5 6 5 Act 129 compliance rider 7 — 7 — Other 3 4 1 — Total current regulatory liabilities $ 79 $ 115 $ 68 $ 96 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 653 $ 640 $ — $ — Power purchase agreement - OVEC 43 51 — — Net deferred taxes 1,690 1,756 560 588 Defined benefit plans 60 51 18 11 Terminated interest rate swaps 66 68 — — Other 18 6 — — Total noncurrent regulatory liabilities $ 2,530 $ 2,572 $ 578 $ 599 LKE LG&E KU 2020 2019 2020 2019 2020 2019 Current Regulatory Assets: Plant outage costs $ 46 $ 32 $ 12 $ 16 $ 34 $ 16 Gas supply clause 4 8 4 8 — — Other 9 1 7 1 2 — Total current regulatory assets $ 59 $ 41 $ 23 $ 25 $ 36 $ 16 Noncurrent Regulatory Assets: Defined benefit plans $ 280 $ 333 $ 174 $ 206 $ 106 $ 127 Storm costs 17 24 11 14 6 10 Unamortized loss on debt 22 23 13 14 9 9 Interest rate swaps 23 22 23 22 — — Terminated interest rate swaps 75 81 44 47 31 34 AROs 300 279 85 76 215 203 Other 4 4 1 1 3 3 Total noncurrent regulatory assets $ 721 $ 766 $ 351 $ 380 $ 370 $ 386 LKE LG&E KU 2020 2019 2020 2019 2020 2019 Current Regulatory Liabilities: Environmental cost recovery $ 4 $ 5 $ — $ 1 $ 4 $ 4 Fuel adjustment clauses 5 8 — — 5 8 Other 2 6 — 1 2 5 Total current regulatory liabilities $ 11 $ 19 $ — $ 2 $ 11 $ 17 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 653 $ 640 $ 274 $ 266 $ 379 $ 374 Power purchase agreement - OVEC 43 51 30 35 13 16 Net deferred taxes 1,130 1,168 528 544 602 624 Defined benefit plans 42 40 — — 42 40 Terminated interest rate swaps 66 68 33 34 33 34 Other 18 6 17 4 1 2 Total noncurrent regulatory liabilities $ 1,952 $ 1,973 $ 882 $ 883 $ 1,070 $ 1,090 (a) For PPL, these amounts are included in "Other current assets" on the Balance Sheets. 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, LKE, LG&E and KU) As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, 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 is recorded as a regulatory asset. As of December 31, 2020, the balances were $79 million for PPL and LKE, $44 million for LG&E and $35 million for KU. As of December 31, 2019, the balances were $51 million for PPL and LKE, $29 million for LG&E and $22 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. PPL Electric's regulatory assets for storm costs are being amortized through 2021. LG&E's and KU's regulatory assets for storm costs are being amortized through various dates ending in 2029. Unamortized Loss on Debt Unamortized loss on reacquired debt represents losses on long-term debt 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, as appropriate, only applicable expenses from reportable storms that are greater than or less than $20 million recovered annually through base rates. Storm costs incurred in PPL Electric's territory from a March 2018 storm are being amortized through 2021. Act 129 Compliance Rider In compliance with Pennsylvania's Act 129 of 2008 and implementing regulations, PPL Electric is currently in Phase III of the energy efficiency and conservation plan which was approved in June 2016. Phase III 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 related to the period of July 1, 2018 through December 31, 2020 is being credited back to distribution customers through a negative surcharge. The liability related to the period of January 1, 2018 through June 30, 2018 was $43 million and was credited back to customers over the period of January 1, 2020 through December 31, 2020 utilizing the same negative surcharge mechanism referred to above, as approved by the PUC in November 2019. (PPL, LKE, 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 returns on equity of 9.2% and 9.725% 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 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. AROs As discussed in Note 1, for LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, at the time of retirement, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability. Power Purchase Agreement - OVEC As a result of purchase accounting associated with PPL's acquisition of LKE, the fair values of the OVEC power purchase agreement were recorded on the balance sheets of LKE, 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 through 2033. Terminated Interest Rate Swaps Net realized gains and losses on all interest rate swaps are probable of recovery 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 Since July 1, 2017, plant outage costs in Kentucky have been normalized for ratemaking purposes based on an average level of expenses. Plant outage expenses that are greater or less than the average are collected from or returned to customers, through future base rates. Effective May 1, 2019 plant outage costs are normalized based on a five-year average of historical expenses with over or under recoveries collected or returned over an eight-year period. Gas Supply Clause (PPL, LKE 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 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). LG&E currently has a proceeding pending with the KPSC in which LG&E proposed renewal of and modification to its natural gas procurement incentive mechanism, which is currently approved through September 1, 2021. LG&E cannot predict the outcome of this proceeding. 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. Generation Formula Rate (PPL, LKE and KU) KU provides wholesale requirements service to its municipal customers and bills for this service pursuant to a FERC approved generation formula rate. Under this formula, rates are put into effect each July utilizing a return on rate base calculation and actual expenses from the preceding year. The regulatory asset or liability represents the difference between the revenue requirement in effect for the current year and actual expenditures incurred for the current year. Amounts are included in other current regulatory assets for 2020 and other current regulatory liabilities for 2019 in the table above. Regulatory Matters Kentucky Activities (PPL, LKE, 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 would be 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. LG&E and KU are also requesting 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 include a request for a CPCN to deploy Advanced Metering Infrastructure across LG&E’s and KU’s service territories in Kentucky. The applications are based on a forecasted test year of July 1, 2021 through June 30, 2022 and request an authorized return on equity of 10.0%. Subject to KPSC approval, the requested rates, decreased by the amount of the billing credit, are expected to become effective July 1, 2021. Certain counterparties have intervened in the proceedings. Data discovery and the filing of written testimony will continue through April 2021 and a hearing is expected to occur during the second quarter of 2021. PPL, LKE, LG&E and KU cannot predict the outcome of these proceedings. ECR Filings On March 31, 2020, LG&E and KU submitted applications to the KPSC for ECR rate treatment regarding upcoming environmental construction projects relating to the EPA's regulations addressing ELGs. The construction projects are expected to begin in 2021 and continue through 2024 and are estimated to cost approximately $405 million ($153 million at LG&E and $252 million at KU). The applications requested an authorized 9.725% return on equity with respect to these projects consistent with the authorized return on equity approved for the 2018 Kentucky rate cases in April 2019. On September 29, 2020, the KPSC issued orders approving the ECR applications, permitting an authorized return on equity of 9.2% for the applicable projects. 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. Hearings were held February 8, 2021. This proceeding remains pending before the PUC. PPL Electric cannot predict the outcome of this proceeding. 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. In March 2020, PPL Electric filed a Petition for Approval of a new default service program and procurement plan with the PUC for the period June 1, 2021 through May 31, 2025. Hearings were held in August 2020. PPL Electric received a Recommended Decision from the Administrative Law Judge on October 13, 2020. Several parties filed Exceptions and Reply Exceptions on October 26, 2020 and November 2, 2020, respectively. On December 17, 2020, the PUC issued a final Order approving the partial settlement reached by parties, including the PPL Electric default service plan for the period of June 2021 through May 2025, and ruling on the issues reserved for litigation. This matter is not expected to have a significant impact on the financial condition of PPL Electric. Federal Matters Challenge to 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 is unjust and unreasonable, and proposing an alternative ROE of 8.00% based on its interpretation of FERC Opinion No. 569. However, also on May 21, 2020, the FERC issued Opinion No. 569-A in response to numerous requests for rehearing of Opinion No. 569, which revised the method for analyzing base ROE. On June 10, 2020, PPLICA filed a Motion to Supplement the May 21, 2020 complaint in which PPLICA continued to allege that PPL Electric’s base ROE is unjust and unreasonable, but revised its analysis of PPL Electric's base ROE to reflect the guidance provided in Opinion No. 569-A. The amended complaint proposed an updated alternative ROE of 8.50% and also requested that the FERC preserve the original refund effective date as established by the filing of the original complaint on May 21, 2020. Several parties have filed motions to intervene, including one party who filed Comments in Support of the original complaint. On July 10, 2020, PPL Electric filed its Answer and supporting Testimony to the PPLICA filings arguing that the FERC should deny the original and amended complaints as they are without merit and fail to demonstrate the existing base ROE is unjust and unreasonable. In addition, PPL Electric contended any refund effective date should be set for no earlier than June 10, 2020 and PPLICA's proposed replacement ROE should be rejected. On October 15, 2020, the FERC issued an order on the PPLICA complaints which established hearing and settlement procedures, set a refund effective date of May 21, 2020 and granted the motions to intervene. On November 16, 2020, PPL Electric filed a request for rehearing of the portion of the October 15, 2020 Order that set the May 21, 2020 refund effective date. On December 17, 2020, the FERC issued a Notice of Denial of Rehearing by Operation of Law and Providing for Further Consideration. On February 16, 2021, PPL Electric filed a Petition for Review with the United States Court of Appeals for the District of Columbia Circuit of the portion of the October 15, 2020 Order that set the May 21, 2020 refund effective date. PPL Electric continues to believe its ROE is just and reasonable and that it has meritorious defenses against the original and amended complaints. At this time, PPL Electric cannot predict the outcome of this matter or the range of possible losses, if any, that may be incurred. However, revenue earned from May 21, 2020 through the settlement of this matter may be subject to refund. A change of 50 basis points to the base ROE would impact PPL Electric's net income by approximately $12 million on an annual basis. (PPL, LKE, 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. Due to the development of robust, accessible energy markets over time, LG&E and KU believe the mitigation commitments are no longer relevant or appropriate. In March 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, subject to FERC review and approval. In July 2019, LG&E and KU proposed their transition mechanism to the FERC and in September 2019, the FERC rejected the proposed transition mechanism and issued a separate order providing clarifications of certain aspects of the March order. In October 2019, LG&E and KU filed requests for rehearing and clarification on the two September orders. In September 2020, the FERC issued its orders in the rehearing process that modified the discussion in, and set aside portions of, the September 2019 orders including adjusting factors impacting the proposed transition mechanism. In October 2020, both LG&E and KU and other parties filed separate motions for rehearing and clarification regarding FERC’s September 2020 orders. In November 2020, the FERC denied the parties’ rehearing requests. In November 2020 and January 2021, LG&E and KU and other parties filed for appeal of the September 2020 and November 2020 orders with the D.C. Circuit Court of Appeals, where certain additional prior petitions for review relating to the proceedings are also pending. On January 15, 2021, LG&E and KU made a filing seeking FERC acceptance of a new proposal for a transition mechanism. LG&E and KU cannot predict the outcome of these proceedings. LG&E and KU currently receive recovery of the waivers and credits provided through other rate mechanisms. (All Registrants) TCJA Impact on FERC Rates In November 2019, the FERC published Final Rules providing that public utility transmission providers include mechanisms in their formula rates to deduct excess ADIT from, or add deficient ADIT to, rate base and adjust their income tax allowances by amortized excess or deficient ADIT, and to make a related compliance filing. In February 2019, PPL Electric filed with the FERC proposed revisions to its transmission formula rate template pursuant to Section 205 of the Federal Power Act and Section 35.13 of the FERC Rules and Regulations. Specifically, PPL Electric proposed to modify its formula rate to permit the return or recovery of excess or deficient ADIT resulting from the TCJA and permit PPL Electric to prospectively account for the income tax expense associated with the depreciation of the equity component of the AFUDC. In April 2019, the FERC accepted the proposed revisions to the formula rate template, which were effective June 1, 2019, as well as the proposed adjustments to ADIT, effective January 1, 2018. In February 2019, in connection with the requirements of the TCJA and Kentucky HB 487, LG&E and KU filed a request with the FERC to amend their transmission formula rates resulting from the laws’ reductions to corporate income tax rates. The FERC approved this request effective June 1, 2019. In 2020, LG&E and KU submitted a compliance filing addressing excess and deficient ADIT. LG&E and KU do not anticipate the impact of the TCJA and Kentucky HB 487 related to their FERC-jurisdictional rates to be significant. 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 2020, 2019 and 2018, PPL Electric purchased $1.1 billion, $1.2 billion and $1.3 billion of accounts receivable from alternative suppliers.

Financing Activities

Financing Activities	12 Months Ended
	Dec. 31, 2020
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, LKE, LG&E and KU also apply to PPL and the credit facilities and commercial paper programs of LG&E and KU also apply to LKE. 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" on the Balance Sheets. The following credit facilities were in place at: December 31, 2020 December 31, 2019 Expiration Capacity Borrowed Letters of Unused Capacity Borrowed Letters of PPL U.K. WPD plc Syndicated Credit Facility (a) (b) (c) Jan. 2023 £ 210 £ 187 £ — £ 23 £ 155 £ — WPD (South West) Syndicated Credit Facility (a) (b) (c) May 2023 220 50 — 170 40 — WPD (South Wales) Syndicated Credit Facility (a) (b) (c) May 2023 125 — — 125 — — WPD (East Midlands) Syndicated Credit Facility (a) (b) (c) May 2023 250 — — 250 — — WPD (West Midlands) Syndicated Credit Facility (a) (b) (c) May 2023 250 74 — 176 48 — Uncommitted Credit Facilities 100 60 4 36 — 4 Total U.K. Credit Facilities (b) £ 1,155 £ 371 £ 4 £ 780 £ 243 £ 4 U.S. PPL Capital Funding Syndicated Credit Facility (c) (d) Jan 2024 1,450 — 402 1,048 — 450 Term Loan Credit Facility (c) (d) Mar 2021 200 200 — — — — Bilateral Credit Facility (c) (d) Mar 2021 50 — — 50 — — Bilateral Credit Facility (c) (d) Mar 2021 50 — 15 35 — 15 Term Loan Credit Facility (c) (d) Mar 2021 100 100 — — — — Term Loan Credit Facility (c) (d) Mar 2022 100 100 — — — — Total PPL Capital Funding Credit Facilities $ 1,950 $ 400 $ 417 $ 1,133 $ — $ 465 PPL Electric Syndicated Credit Facility (c) (d) Jan 2024 $ 650 $ — $ 1 $ 649 $ — $ 1 LG&E Syndicated Credit Facility (c) (d) Jan 2024 $ 500 $ — $ 262 $ 238 $ — $ 238 Total LG&E Credit Facilities $ 500 $ — $ 262 $ 238 $ — $ 238 KU Syndicated Credit Facility (c) (d) Jan 2024 $ 400 $ — $ 203 $ 197 $ — $ 150 Total KU Credit Facilities $ 400 $ — $ 203 $ 197 $ — $ 150 (a) The facilities contain financial covenants to maintain an interest coverage ratio of not less than 3.0 times consolidated earnings before income taxes, depreciation and amortization and total net debt not in excess of 85% of its RAV, calculated in accordance with the credit facility. (b) The WPD plc amounts borrowed at December 31, 2020 and 2019 included USD-denominated borrowings of $249 million and $200 million, which bore interest at weighted average rate of 0.95% and 2.52%. The WPD (South West) amounts borrowed at December 31, 2020 and 2019 were GBP-denominated borrowings, which equated to $67 million and $51 million and bore interest at 0.54% and 1.09%. The WPD (West Midlands) amounts borrowed at December 31, 2020 and 2019 were GBP-denominated borrowings, which equated to $99 million and $62 million and bore interest at 0.54% and 1.11%. The interest rates on the borrowings are equal to one-month USD LIBOR plus a margin. At December 31, 2020, the unused capacity under the U.K. credit facilities was approximately $1.0 billion. (c) Each company pays customary fees under its respective facility and borrowings generally bear interest at LIBOR-based rates plus an applicable margin. (d) 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 its bilateral credit facility expiring in March 2021 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. (PPL) In March 2020, PPL Capital Funding entered into a $200 million term loan credit facility expiring in March 2021 and borrowed the full principal amount under the facility at an initial interest rate of 1.96%. The applicable interest rate on borrowings fluctuates periodically and is based on LIBOR plus a spread. The proceeds were used to repay short-term debt and for general corporate purposes. In April 2020, PPL Capital Funding entered into a $100 million term loan credit facility expiring in March 2021 and borrowed the full principal amount under the facility at an initial interest rate of 1.73%. The applicable interest rate on borrowings fluctuates periodically and is based on LIBOR plus a spread. The proceeds were used to repay short-term debt and for general corporate purposes. PPL has guaranteed PPL Capital Funding's obligations under these credit agreements. (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, 2020 December 31, 2019 Weighted - Capacity Commercial Unused Weighted - Commercial PPL Capital Funding 0.25% $ 1,500 $ 402 $ 1,098 2.13% $ 450 PPL Electric 650 — 650 — LG&E 0.28% 350 262 88 2.07% 238 KU 0.28% 350 203 147 2.02% 150 Total $ 2,850 $ 867 $ 1,983 $ 838 (PPL Electric, LKE, LG&E and KU) See Note 15 for a discussion of intercompany borrowings. Long-term Debt (All Registrants) December 31, Weighted-Average Maturities (g) 2020 2019 PPL U.S. Senior Unsecured Notes 3.95 % 2021 - 2047 $ 4,850 $ 4,325 Senior Secured Notes/First Mortgage Bonds (a) (b) (c) 3.81 % 2021 - 2050 8,955 8,705 Junior Subordinated Notes 4.35 % 2067 - 2073 930 930 Term Loan Credit Facility 0.85 % 2022 100 — Total U.S. Long-term Debt 14,835 13,960 U.K. Senior Unsecured Notes (d) 4.69 % 2021 - 2040 7,197 6,874 Index-linked Senior Unsecured Notes (e) 1.42 % 2028 - 2056 1,150 1,104 Term Loan Credit Facility 1.46 % 2024 67 64 Total U.K. Long-term Debt (f) 8,414 8,042 Total Long-term Debt Before Adjustments 23,249 22,002 Fair market value adjustments 8 12 Unamortized premium and (discount), net 2 5 Unamortized debt issuance costs (132) (126) Total Long-term Debt 23,127 21,893 Less current portion of Long-term Debt 1,574 1,172 Total Long-term Debt, noncurrent $ 21,553 $ 20,721 PPL Electric Senior Secured Notes/First Mortgage Bonds (a) (b) 3.79 % 2021 - 2049 $ 4,289 $ 4,039 Total Long-term Debt Before Adjustments 4,289 4,039 Unamortized discount (23) (24) Unamortized debt issuance costs (30) (30) Total Long-term Debt 4,236 3,985 Less current portion of Long-term Debt 400 — Total Long-term Debt, noncurrent $ 3,836 $ 3,985 LKE Senior Unsecured Notes 4.38 % 2021 $ 250 $ 725 First Mortgage Bonds (a) (c) 3.82 % 2023 - 2050 4,666 4,666 Long-term debt to affiliate 3.89 % 2026 - 2030 1,200 650 Total Long-term Debt Before Adjustments 6,116 6,041 Unamortized premium 5 5 Unamortized discount (13) (12) Unamortized debt issuance costs (34) (32) Total Long-term Debt 6,074 6,002 Less current portion of Long-term Debt 674 975 Total Long-term Debt, noncurrent $ 5,400 $ 5,027 December 31, Weighted-Average Maturities (g) 2020 2019 LG&E First Mortgage Bonds (a) (c) 3.69 % 2025 - 2049 $ 2,024 $ 2,024 Total Long-term Debt Before Adjustments 2,024 2,024 Unamortized discount (4) (4) Unamortized debt issuance costs (13) (15) Total Long-term Debt 2,007 2,005 Less current portion of Long-term Debt 292 — Total Long-term Debt, noncurrent $ 1,715 $ 2,005 KU First Mortgage Bonds (a) (c) 3.92 % 2023 - 2050 $ 2,642 $ 2,642 Total Long-term Debt Before Adjustments 2,642 2,642 Unamortized premium 5 5 Unamortized discount (9) (8) Unamortized debt issuance costs (20) (16) Total Long-term Debt 2,618 2,623 Less current portion of Long-term Debt 132 500 Total Long-term Debt, noncurrent $ 2,486 $ 2,123 (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 $10.8 billion and $10.1 billion at December 31, 2020 and 2019. 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 $5.5 billion and $5.3 billion at December 31, 2020 and 2019. 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 $6.7 billion and $6.6 billion at December 31, 2020 and 2019. (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, 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, 2020, the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a term rate mode totaled $848 million for LKE, comprised of $539 million and $309 million for LG&E and KU respectively. At December 31, 2020, the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a variable rate mode totaled $33 million for LKE and KU respectively. 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) Includes £225 million ($300 million at December 31, 2020) of notes that may be redeemed, in total but not in part, on December 21, 2026, at the greater of the principal value or a value determined by reference to the gross redemption yield on a nominated U.K. Government bond. (e) The principal amount of the notes issued by WPD (South West), WPD (East Midlands) and WPD (South Wales) is adjusted based on changes in a specified index, as detailed in the terms of the related indentures. The adjustment to the principal amounts from 2019 to 2020 was an increase of approximately £10 million ($13 million) resulting from inflation. In addition, this amount includes £331 million ($441 million at December 31, 2020) of notes issued by WPD (South West) that may be redeemed, in total by series, on December 1, 2026, at the greater of the adjusted principal value and a make-whole value determined by reference to the gross real yield on a nominated U.K. government bond. (f) Includes £5.8 billion ($7.7 billion at December 31, 2020) of notes that may be put by the holders to the issuer for redemption if the long-term credit ratings assigned to the notes are withdrawn by any of the rating agencies (Moody's or S&P) or reduced to a non-investment grade rating of Ba1 or BB+ or lower in connection with a restructuring event, which includes the loss of, or a material adverse change to, the distribution licenses under which the issuer operates. (g) The table reflects principal maturities only, based on stated maturities or earlier put dates, and the weighted-average rates as of December 31, 2020. 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 2021 through 2025 and thereafter are as follows: PPL PPL LKE LG&E KU 2021 $ 1,574 $ 400 $ 674 $ 292 $ 132 2022 1,374 474 — — — 2023 2,552 340 13 — 13 2024 950 — — — — 2025 883 — 550 300 250 Thereafter 15,916 3,075 4,879 1,432 2,247 Total $ 23,249 $ 4,289 $ 6,116 $ 2,024 $ 2,642 (PPL) In April 2020, PPL Capital Funding entered into a $100 million term loan credit facility expiring in March 2022 and borrowed the full principal amount under the facility at an initial interest rate of 1.72%. The applicable interest rate on borrowings fluctuates periodically and is based on LIBOR plus a spread. The proceeds were used to repay short-term debt and for general corporate purposes. In April 2020, PPL Capital Funding issued $1 billion of 4.125% Senior Notes due 2030. PPL Capital Funding received proceeds of $993 million, net of a discount and underwriting fees, which were used to repay short-term debt and for general corporate purposes. PPL has guaranteed PPL Capital Funding's obligations under the credit agreement and notes. In October 2020, WPD (South Wales) issued £250 million of 1.625% Senior Notes due 2035. WPD (South Wales) received proceeds of £247 million which equated to $319 million at the time of issuance, net of fees and a discount. The proceeds were used to repay the £150 million of 9.25% Notes due in November 2020 and for general corporate purposes. In January 2021, WPD issued a notice to redeem its $500 million of 5.375% Notes due May 2021 on March 1, 2021. (PPL and PPL Electric) In October 2020, PPL Electric issued $250 million of First Mortgage Bonds, Floating Rate Series due 2023. PPL Electric received proceeds of $249 million, net of discounts and underwriting fees, which were used to repay short-term debt and for general corporate purposes. In October 2020, the Pennsylvania Economic Development Financing Authority (PEDFA) remarketed $90 million of Pollution Control Revenue Refunding Bonds, Series 2008 (PPL Electric Utilities Corporation Project) due 2023, previously issued on behalf of PPL Electric. The bonds were remarketed at a long-term rate and will bear interest at 0.40% through their maturity date of October 1, 2023. (PPL and LKE) In August 2020, LKE redeemed $475 million of 3.75% senior notes due November 2020. (PPL, LKE and LG&E) In September 2020, the County of Trimble, Kentucky remarketed $125 million of Pollution Control Revenue Refunding Bonds, 2016 Series A due 2044 previously issued on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at 1.30% through their mandatory purchase date of September 1, 2027. In September 2020, the Louisville/Jefferson County Metro Government of Kentucky remarketed $23 million of Pollution Control Revenue Bonds, 2001 Series A due 2026 on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at 0.90% through their maturity date of September 1, 2026. (PPL, LKE and KU) In June 2020, KU issued $500 million of 3.30% First Mortgage Bonds due 2050. KU received proceeds of $493 million, net of discounts and underwriting fees, which were initially used to repay short-term debt and for other general corporate purpose, pending application to the redemption of KU's 3.25% First Mortgage Bonds in August 2020. In August 2020, KU redeemed $500 million of 3.25% First Mortgage Bonds due November 2020. 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 and LKE are each separate legal entities. These subsidiaries are not liable for the debts of PPL Electric and LKE. Accordingly, creditors of PPL Electric and LKE may not satisfy their debts from the assets of their subsidiaries absent a specific contractual undertaking by a subsidiary to pay the creditors or as required by applicable law or regulation. Similarly, PPL Electric and LKE are not liable for the debts of their subsidiaries, nor are their subsidiaries liable for the debts of one another. Accordingly, creditors of these subsidiaries may not satisfy their debts from the assets of PPL Electric and LKE (or their other subsidiaries) absent a specific contractual undertaking by that parent or other subsidiary to pay such creditors or as required by applicable law or regulation. (PPL) Equity Securities 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, 2020 and 2019. The ATM program expires in February 2021. Distributions and Related Restrictions In November 2020, PPL declared its quarterly common stock dividend, payable January 4, 2021, at 41.50 cents per share (equivalent to $1.66 per annum). Future dividends, declared at the discretion of the Board of Directors, 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 or 2013 Series B Junior Subordinated Notes due 2073. At December 31, 2020, no interest payments were deferred. WPD subsidiaries have financing arrangements that limit their ability to pay dividends. However, PPL does not, at this time, expect that any of such limitations would significantly impact PPL's ability to meet its cash obligations. (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. LKE primarily relies on dividends from its subsidiaries to fund its distributions to PPL. 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 LKE. 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, 2020, net assets of $3 billion ($1.3 billion for LG&E and $1.7 billion for KU) were restricted for purposes of paying dividends to LKE, and net assets of $3.7 billion ($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, 2020
Contractors [Abstract]
Acquisitions, Development and Divestitures	(PPL) On August 10, 2020, PPL announced that it initiated a formal process to sell its U.K. utility business. PPL noted that there can be no assurance of any specific outcome, including whether the sale process will result in the completion of any potential transaction, the timing or terms thereof, the value or benefits that may be realized or the effect that any potential transaction will have on future financial results. As a result of the potential sale, PPL assessed the recoverability of the assets of its U.K. utility business. PPL prepared probability-weighted undiscounted cash flow estimates as of December 31, 2020 and September 30, 2020 that considered the likelihood of the possible outcomes of the sale process, including the possibility of not selling the U.K. utility business. The resulting cash flow analyses exceeded the carrying value of the assets of the U.K. utility business. A change in the possible outcomes of the sale process could result in the carrying value of the assets of the U.K. utility business not being recoverable, which could result in an impairment in future periods. The U.K. utility business will continue to be classified as held and used until it meets the criteria to be classified as held for sale, which includes management obtaining a commitment to a plan to sell from its Board of Directors. Should the U.K. utility business meet the criteria to be classified as held for sale in a future period, PPL will be required at that time to compare the estimated fair value of its investment in the U.K. utility business, less costs to sell, to its carrying value, including accumulated other comprehensive losses related to the U.K. utility business, for impairment purposes. The resulting measurement may result in a loss. In addition, PPL will reassess its assertion of the indefinite reinvestment of the unremitted earnings of the U.K. utility business. See Note 21 for additional information on accumulated other comprehensive income and losses. See Note 6 for additional information on income taxes.

Leases

Leases	12 Months Ended
	Dec. 31, 2020
Leases [Line Items]
Lessor, Operating Leases [Text Block]	Lessor Transactions Third parties lease land from LKE, LG&E and KU at certain generation plants to produce refined coal used to generate electricity. The leases are operating leases and expire in 2021. Payments are allocated among lease and non-lease components as stated in the agreements. Lease payments are fixed or are determined based on the amount of refined coal used in electricity generation at the facility. Payments received are primarily recorded as a regulatory liability and are amortized in accordance with regulatory approvals. WPD leases property and telecom assets to third parties, which generally expire through 2029. These leases are operating leases. Generally, lease payments are fixed and include only a lease component. The following table shows the fixed lease payments that PPL, LKE, LG&E and KU expect to receive over the remaining term of their operating lease agreements for the years ended December 31: 2020 PPL LKE LG&E KU 2021 $ 11 $ 5 $ — $ 5 2022 6 — — — 2023 6 1 — — 2024 5 — — — 2025 4 — — — Thereafter 12 — — — Total $ 44 $ 6 $ — $ 5 Lease income recognized for the twelve months ended December 31, 2020 $ 21 $ 15 $ 6 $ 9 Lease income recognized for the twelve months ended December 31, 2019 21 13 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. LKE, 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 2021 to 2025, some of which have options to extend the leases from one year to ten years and some have options to terminate at LKE's, LG&E's and KU's discretion. PPL has also entered into various operating leases primarily for office space, land easements, telecom assets and warehouse space. These leases generally have fixed payments with expiration dates ranging from 2020 through 2029, except for the land agreements which extend through 2116. 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 ROU 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, LKE, 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: 2020 PPL LKE LG&E KU Lease cost: Operating lease cost $ 30 $ 22 $ 8 $ 13 Short-term lease cost 9 2 1 1 Total lease cost $ 39 $ 24 $ 9 $ 14 2019 PPL LKE LG&E KU Lease cost: Operating lease cost $ 33 $ 25 $ 12 $ 13 Short-term lease cost 7 2 1 1 Total lease cost $ 40 $ 27 $ 13 $ 14 The following table provides other key information related to the Registrants' operating leases at December 31: 2020 PPL LKE LG&E KU Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 26 $ 18 $ 7 $ 11 Right-of-use asset obtained in exchange for new operating lease liabilities 17 16 6 9 2019 PPL LKE LG&E KU Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 29 $ 21 $ 9 $ 11 Right-of-use asset obtained in exchange for new operating lease liabilities 46 16 5 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, 2020. PPL LKE LG&E KU 2021 $ 27 $ 17 $ 6 $ 10 2022 22 13 5 8 2023 18 10 4 6 2024 15 8 3 4 2025 8 6 3 3 Thereafter 20 3 1 2 Total $ 110 $ 57 $ 22 $ 33 Weighted-average discount rate 3.35% 3.66% 3.53% 3.68% Weighted-average remaining lease term (in years) 8 4 4 4 Current lease liabilities (a) $ 24 $ 16 $ 6 $ 9 Non-current lease liabilities (a) 70 37 15 21 Right-of-use assets (b) 87 46 17 27 (a) Current lease liabilities are included in "Other Current Liabilities" on the Balance Sheets. Non-current lease liabilities are included in "Other deferred credits and noncurrent liabilities" on the Balance Sheets. The difference between the total future minimum lease payments and the recorded lease liabilities is due to the impact of discounting. (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, 2020
Stock-Based Compensation [Line Items]
Stock-Based Compensation	(PPL, PPL Electric and LKE) 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, LKE 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: 2020 2019 2018 PPL $ 35.30 $ 31.95 $ 30.58 PPL Electric 35.37 32.33 30.00 LKE 35.31 30.65 30.98 Restricted stock unit activity for 2020 was: Restricted Weighted- PPL Nonvested, beginning of period 1,137,685 $ 32.76 Granted 331,160 35.30 Vested (562,848) 34.57 Forfeited (9,661) 32.97 Nonvested, end of period 896,336 32.56 PPL Electric Nonvested, beginning of period 229,860 $ 32.61 Transfer between registrants (1,197) 32.23 Granted 65,356 35.37 Vested (79,313) 34.55 Forfeited (3,986) 32.65 Nonvested, end of period 210,720 32.73 LKE Nonvested, beginning of period 166,445 $ 32.09 Transfer between registrants (1,598) 30.57 Granted 50,402 35.31 Vested (60,571) 34.88 Forfeited (1,550) 30.36 Nonvested, end of period 153,128 32.08 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: 2020 2019 2018 PPL $ 19 $ 13 $ 16 PPL Electric 3 2 2 LKE 2 1 5 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: 2020 2019 2018 Expected stock volatility 15.64% 17.57% 17.60% Expected life 3 years 3 years 3 years The weighted-average grant date fair value of TSR performance units granted was: 2020 2019 2018 PPL $ 37.63 $ 35.83 $ 38.26 PPL Electric 38.64 35.68 38.37 LKE 37.73 35.93 38.32 TSR performance unit activity for 2020 was: TSR Performance Units Weighted- PPL Nonvested, beginning of period 739,392 $ 37.50 Granted 261,891 37.63 Forfeited (a) (375,029) 38.46 Nonvested, end of period 626,254 36.98 PPL Electric Nonvested, beginning of period 66,799 $ 37.43 Granted 21,416 38.64 Forfeited (a) (26,408) 38.37 Nonvested, end of period 61,807 37.44 LKE Nonvested, beginning of period 130,533 $ 37.60 Granted 35,538 37.73 Forfeited (a) (66,459) 38.23 Nonvested, end of period 99,612 37.23 (a) Primarily related to the forfeiture of 2017 performance units as performance during the period was below the minimum established performance threshold, which resulted in no payout. There were no TSR performance units vesting for the years ended December 31, 2020 and 2019. The total fair value of TSR performance units vesting for the year ended December 31, 2018 was $3 million for PPL. Amounts for PPL Electric and LKE 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: 2020 2019 2018 PPL $ 34.95 $ 30.89 $ 32.21 PPL Electric 35.59 30.76 32.32 LKE 34.81 30.99 32.28 ROE performance unit activity for 2020 was: ROE Performance Unit Weighted- PPL Nonvested, beginning of period 570,765 $ 32.02 Granted 374,878 34.95 Vested (216,979) 34.42 Nonvested, end of period 728,664 32.81 PPL Electric Nonvested, beginning of period 49,194 $ 31.92 Granted 30,426 35.59 Vested (17,813) 34.41 Nonvested, end of period 61,807 33.01 LKE Nonvested, beginning of period 107,805 $ 32.20 Granted 60,286 34.81 Vested (46,384) 34.29 Nonvested, end of period 121,707 32.70 The total fair value of ROE performance units vesting for the years ended December 31 was: 2020 PPL $ 8 PPL Electric 1 LKE 2 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, 2020, 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 2020 was: Number Weighted Weighted- Aggregate PPL Outstanding at beginning of period 1,330,943 $ 26.20 Exercised (227,927) 26.10 Outstanding and exercisable at end of period 1,103,016 26.22 1.7 $ 2 For 2020, 2019 and 2018, PPL received $8 million, $53 million and $5 million in cash from stock options exercised. The total intrinsic value of stock options exercised was insignificant in 2020 and 2018 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 and LKE includes an allocation of PPL Services' expense, was: 2020 2019 2018 PPL $ 28 $ 35 $ 25 PPL Electric 10 12 10 LKE 11 9 8 The income tax benefit related to above compensation expense was as follows: 2020 2019 2018 PPL $ 8 $ 10 $ 10 PPL Electric 3 3 3 LKE 3 2 2 At December 31, 2020, unrecognized compensation expense related to nonvested stock awards was: Unrecognized Weighted- PPL $ 16 1.7 PPL Electric 3 1.8 LKE 1 1.4

Retirement and Postemployment B

Retirement and Postemployment Benefits	12 Months Ended
	Dec. 31, 2020
Retirement Benefits [Abstract]
Retirement and Postemployment Benefits	(All Registrants) Defined Benefits Certain employees of PPL's domestic 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. Effective April 1, 2010, the principal defined benefit pension plan applicable to WPD (South West) and WPD (South Wales) was closed to most new employees, except for those meeting specific grandfathered participation rights. WPD Midlands' defined benefit plan had been closed to new members, except for those meeting specific grandfathered participation rights, prior to acquisition. New employees not eligible to participate in the plans are offered benefits under a defined contribution 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 domestic 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. WPD does not sponsor any postretirement benefit plans other than pensions. (PPL) The following table provides the components of net periodic defined benefit costs (credits) for PPL's domestic (U.S.) and WPD's (U.K.) pension and other postretirement benefit plans for the years ended December 31. Pension Benefits U.S. U.K. Other Postretirement Benefits 2020 2019 2018 2020 2019 2018 2020 2019 2018 Net periodic defined benefit costs (credits): Service cost $ 56 $ 50 $ 62 $ 89 $ 68 $ 82 $ 6 $ 6 $ 7 Interest cost 146 164 156 143 187 185 19 22 21 Expected return on plan assets (246) (245) (249) (622) (588) (587) (21) (18) (23) Amortization of: Prior service cost (credit) 9 8 10 1 1 — 1 (1) (1) Actuarial (gain) loss 89 56 84 213 92 151 — 1 — Net periodic defined benefit costs 54 33 63 (176) (240) (169) 5 10 4 Settlements (a) 23 1 — — — — — — — Net periodic defined benefit costs $ 77 $ 34 $ 63 $ (176) $ (240) $ (169) $ 5 $ 10 $ 4 Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: Settlement (23) (1) — — — — — — — Net (gain) loss (221) (121) 157 459 723 201 (6) (18) 8 Prior service cost 1 2 1 — — 13 5 — — Amortization of: Prior service (cost) credit (9) (8) (10) (1) (1) — (1) 1 1 Actuarial gain (loss) (89) (56) (84) (213) (92) (151) — (1) — Total recognized in OCI and (341) (184) 64 245 630 63 (2) (18) 9 Total recognized in net periodic $ (264) $ (150) $ 127 $ 69 $ 390 $ (106) $ 3 $ (8) $ 13 (a) Includes 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. (b) WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP. As a result, WPD does not record regulatory assets/liabilities. For PPL's U.S. pension benefits and for other postretirement benefits, the amounts recognized in OCI and regulatory assets/liabilities for the years ended December 31 were as follows: U.S. Pension Benefits Other Postretirement Benefits 2020 2019 2018 2020 2019 2018 OCI $ (428) $ (194) $ 90 $ (12) $ (13) $ 20 Regulatory assets/liabilities 87 10 (26) 10 (5) (11) Total recognized in OCI and $ (341) $ (184) $ 64 $ (2) $ (18) $ 9 (LKE) The following table provides the components of net periodic defined benefit costs for LKE's pension and other postretirement benefit plans for the years ended December 31. Pension Benefits Other Postretirement Benefits 2020 2019 2018 2020 2019 2018 Net periodic defined benefit costs (credits): Service cost $ 24 $ 22 $ 25 $ 4 $ 4 $ 4 Interest cost 57 66 63 7 8 8 Expected return on plan assets (101) (101) (102) (9) (8) (9) Amortization of: Prior service cost 8 8 9 1 1 1 Actuarial (gain) loss (a) 41 22 35 (1) (1) — Net periodic defined benefit costs (credits) before settlements $ 29 $ 17 $ 30 $ 2 $ 4 $ 4 Settlements (b) 15 — — — — — Net periodic defined benefit costs (credits) (c) $ 44 $ 17 $ 30 $ 2 $ 4 $ 4 Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Settlements $ (15) $ — $ — $ — $ — $ — Net (gain) loss (29) (37) 40 (1) (14) 1 Prior service cost 2 2 — 5 — — Amortization of: Prior service credit (8) (8) (9) (1) (1) (1) Actuarial gain (loss) (41) (22) (35) 1 1 — Total recognized in OCI and (91) (65) (4) 4 (14) — Total recognized in net periodic $ (47) $ (48) $ 26 $ 6 $ (10) $ 4 (a) 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 LKE's pension accounting policy and actuarial (gain)/loss calculated using a 15 year amortization period was $11 million in 2020, $5 million in 2019 and $11 million in 2018. (b) Due to the amount of lump sum payment distributions from the LKE qualified pension plan, a settlement charge of $15 million for the year ended December 31, 2020 was incurred. 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 attributable to LKE’s operations outside of the jurisdiction of the KPSC has been charged to expense. (c) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, settlement charges of $5 million in 2019 and $6 million in 2018 were 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. For LKE's pension and other 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 2020 2019 2018 2020 2019 2018 OCI $ (5) $ 13 $ (25) $ (2) $ (7) $ 4 Regulatory assets/liabilities (86) (78) 21 6 (7) (4) Total recognized in OCI and $ (91) $ (65) $ (4) $ 4 $ (14) $ — (LG&E) The following table provides the components of net periodic defined benefit costs for LG&E's pension benefit plan for the years ended December 31. Pension Benefits 2019 (a) 2018 Net periodic defined benefit costs (credits): Service cost $ 1 $ 1 Interest cost 11 12 Expected return on plan assets (21) (22) Amortization of: Prior service cost (credit) 5 5 Actuarial loss (b) 9 7 Net periodic defined benefit costs (credits) (c) $ 5 $ 3 Other Changes in Plan Assets and Benefit Obligations Net (gain) loss $ (19) $ 22 Prior service cost — — Amortization of: Prior service credit (5) (5) Actuarial gain (9) (7) Total recognized in regulatory assets/liabilities (33) 10 Total recognized in net periodic defined benefit costs and regulatory assets $ (28) $ 13 (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 and $2 million in 2018. (c) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, settlement charges of $5 million in 2019 and $6 million in 2018 were 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. The U.K. pension benefits apply to PPL only. Pension Benefits U.S. U.K. Other Postretirement Benefits 2020 2019 2018 2020 2019 2018 2020 2019 2018 PPL $ 40 $ 18 $ 40 $ (237) $ (287) $ (226) $ 4 $ 8 $ 2 PPL Electric (a) (2) (4) 4 2 4 (1) LKE (b) 20 12 21 1 2 3 LG&E (a) (b) 4 3 4 2 2 2 KU (a) (b) 1 (1) 2 — — 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 and KU do 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 LKE's, 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, $3 million for LG&E and $1 million for KU were recorded as regulatory assets in 2020, $2 million for LG&E and $1 million for KU were recorded as regulatory assets in 2019 and $3 million for LG&E and $2 million for KU were recorded as regulatory assets in 2018. In the table above, LG&E amounts include costs for the specific plans it sponsors and the following allocated costs of defined benefit plans sponsored by LKE. LG&E 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 LG&E from LKS. These allocations are based on LG&E's participation in those plans, which management believes are reasonable: Pension Benefits Other Postretirement Benefits 2019 (a) 2018 2019 (a) 2018 LG&E Non-Union Only $ — $ 2 $ 2 $ 2 (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. (PPL, LKE and LG&E) PPL, LKE, and LG&E use base mortality tables issued by the Society of Actuaries for all U.S. defined benefit pension and other postretirement benefit plans. In 2019, PPL, LKE and LGE 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 and LKE 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. The U.K. pension benefits apply to PPL only. Pension Benefits U.S. U.K. Other Postretirement Benefits 2020 2019 2020 2019 2020 2019 PPL Discount rate 2.92 % 3.64 % 1.53 % 1.94 % 2.84 % 3.60 % Rate of compensation increase 3.76 % 3.79 % 3.25 % 3.25 % 3.75 % 3.76 % LKE Discount rate 2.91 % 3.62 % 2.85 % 3.59 % Rate of compensation increase 3.50 % 3.50 % 3.50 % 3.50 % LG&E Discount rate — % 3.60 % The following weighted-average assumptions were used to determine the net periodic defined benefit costs for the years ended December 31. The U.K. pension benefits apply to PPL only. Pension Benefits U.S. U.K. Other Postretirement Benefits 2020 2019 2018 2020 2019 2018 2020 2019 2018 PPL Discount rate service cost 3.64 % 4.35 % 3.70 % 2.03 % 3.12 % 2.73 % 3.60 % 4.31 % 3.64 % Discount rate interest cost 3.64 % 4.35 % 3.70 % 1.73 % 2.62 % 2.31 % 3.60 % 4.31 % 3.64 % Rate of compensation increase 3.79 % 3.79 % 3.78 % 3.25 % 3.50 % 3.50 % 3.76 % 3.76 % 3.75 % Expected return on plan assets 7.25 % 7.25 % 7.25 % 7.13 % 7.21 % 7.23 % 6.44 % 6.46 % 6.40 % LKE Discount rate 3.62 % 4.35 % 3.69 % 3.59 % 4.32 % 3.65 % Rate of compensation increase 3.50 % 3.50 % 3.50 % 3.50 % 3.50 % 3.50 % Expected return on plan assets (a) 7.25 % 7.25 % 7.25 % 7.02 % 7.00 % 7.15 % LG&E Discount rate — % 4.33 % 3.65 % Expected return on plan assets (a) — % 7.25 % 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 and LKE) The following table provides the assumed health care cost trend rates for the years ended December 31: 2020 2019 2018 PPL and LKE Health care cost trend rate assumed for next year – obligations 6.5 % 6.6 % 6.6 % – cost 6.6 % 6.6 % 6.6 % Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) – obligations 5.0 % 5.0 % 5.0 % – cost 5.0 % 5.0 % 5.0 % Year that the rate reaches the ultimate trend rate – obligations 2027 2024 2023 – cost 2024 2023 2022 (PPL) The funded status of PPL's plans at December 31 was as follows: Pension Benefits U.S. U.K. Other Postretirement Benefits 2020 2019 2020 2019 2020 2019 Change in Benefit Obligation Benefit Obligation, beginning of period $ 4,146 $ 3,883 $ 8,515 $ 7,275 $ 557 $ 538 Service cost 56 50 89 68 6 6 Interest cost 146 164 143 187 19 22 Participant contributions — — 12 12 15 14 Plan amendments 2 2 — — 5 — Actuarial (gain) loss 256 368 624 1,220 29 34 Settlements (114) (21) — — — — Gross benefits paid (241) (300) (366) (363) (58) (58) Federal subsidy — — — — — 1 Currency conversion — — 281 116 — — Benefit Obligation, end of period 4,251 4,146 9,298 8,515 573 557 Change in Plan Assets Plan assets at fair value, beginning of period 3,585 3,109 8,945 7,801 340 301 Actual return on plan assets 723 735 805 1,095 56 71 Employer contributions 115 63 272 278 18 10 Participant contributions — — 12 12 11 10 Settlements (114) (22) — — — — Gross benefits paid (241) (300) (366) (363) (58) (52) Currency conversion — — 302 122 — — Plan assets at fair value, end of period 4,068 3,585 9,970 8,945 367 340 Funded Status, end of period $ (183) $ (561) $ 672 $ 430 $ (206) $ (217) Amounts recognized in the Balance Sheets consist of: Noncurrent asset $ 24 $ 24 $ 682 $ 440 $ — $ 11 Current liability (18) (8) — (1) (22) (2) Noncurrent liability (189) (577) (10) (9) (184) (226) Net amount recognized, end of period $ (183) $ (561) $ 672 $ 430 $ (206) $ (217) Pension Benefits U.S. U.K. Other Postretirement Benefits 2020 2019 2020 2019 2020 2019 Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: Prior service cost (credit) $ 27 $ 34 $ 11 $ 11 $ 14 $ 10 Net actuarial (gain) loss 695 1,029 3,682 3,435 — 6 Total (a) $ 722 $ 1,063 $ 3,693 $ 3,446 $ 14 $ 16 Total accumulated benefit obligation $ 4,024 $ 3,910 $ 8,516 $ 7,821 (a) WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP and as a result, does not record regulatory assets/liabilities. For PPL's U.S. pension and other postretirement benefit plans, the amounts recognized in AOCI and regulatory assets/liabilities at December 31 were as follows: U.S. Pension Benefits Other Postretirement Benefits 2020 2019 2020 2019 AOCI $ 270 $ 352 $ 10 $ 13 Regulatory assets/liabilities 452 711 4 3 Total $ 722 $ 1,063 $ 14 $ 16 The actuarial loss for U.S. 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 actuarial loss for U.S. pension plans in 2019 was primarily related to a change in the discount rate used to measure the benefit obligations of those plans. The actuarial loss for U.K. pension plans in 2020 and 2019 was primarily related to a change in the discount rate used to measure the benefit obligations of those plans. 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: U.S. U.K. PBO in excess of plan assets PBO in excess of plan assets 2020 2019 2020 2019 Projected benefit obligation $ 1,875 $ 3,861 $ 11 $ 10 Fair value of plan assets 1,668 3,275 — — U.S. U.K. ABO in excess of plan assets ABO in excess of plan assets 2020 2019 2020 2019 Accumulated benefit obligation $ 184 $ 3,624 $ 11 $ 10 Fair value of plan assets — 3,275 — — (LKE) The funded status of LKE's plans at December 31 was as follows: Pension Benefits Other Postretirement Benefits 2020 2019 2020 2019 Change in Benefit Obligation Benefit Obligation, beginning of period $ 1,684 $ 1,580 $ 208 $ 205 Service cost 24 22 4 4 Interest cost 57 66 7 8 Participant contributions — — 9 7 Plan amendments 2 2 5 — Actuarial (gain) loss (a) 164 166 18 5 Settlements (83) (16) — — Gross benefits paid (63) (136) (22) (21) Benefit Obligation, end of period 1,785 1,684 229 208 Change in Plan Assets Plan assets at fair value, beginning of period 1,470 1,294 141 117 Actual return on plan assets 294 304 28 27 Employer contributions 50 24 4 11 Participant contributions — — 9 7 Settlements (83) (16) — — Gross benefits paid (63) (136) (22) (21) Plan assets at fair value, end of period 1,668 1,470 160 141 Funded Status, end of period $ (117) $ (214) $ (69) $ (67) Amounts recognized in the Balance Sheets consist of: Noncurrent asset $ — $ 24 $ — $ 11 Current liability (5) (5) (2) (2) Noncurrent liability (112) (233) (67) (76) Net amount recognized, end of period $ (117) $ (214) $ (69) $ (67) Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: Prior service cost $ 23 $ 30 $ 14 $ 10 Net actuarial (gain) loss 296 380 (37) (37) Total $ 319 $ 410 $ (23) $ (27) Total accumulated benefit obligation $ 1,657 $ 1,561 (a) The actuarial (gain) loss for all pension plans in 2020 and 2019 was primarily related to changes in the discount rate used to measure the benefit obligations of those plans. The amounts recognized in AOCI and regulatory assets/liabilities at December 31 were as follows: Pension Benefits Other Postretirement Benefits 2020 2019 2020 2019 AOCI $ 127 $ 132 $ 2 $ 4 Regulatory assets/liabilities 192 278 (25) (31) Total $ 319 $ 410 $ (23) $ (27) The following tables provide information on pension plans where the projected benefit obligation (PBO) or accumulated benefit obligations (ABO) exceed the fair value of plan assets: PBO in excess of plan assets 2020 2019 Projected benefit obligation $ 1,785 $ 1,398 Fair value of plan assets 1,668 1,160 ABO in excess of plan assets 2020 2019 Accumulated benefit obligation $ 104 $ 1,276 Fair value of plan assets — 1,160 (LG&E) The funded status of LG&E's plan at December 31, was as follows: Pension Benefits 2019 (a) Change in Benefit Obligation Benefit Obligation, beginning of period $ 285 Service cost 1 Interest cost 11 Actuarial (gain) loss 25 Gross benefits paid (36) Benefit Obligation, end of period 286 Change in Plan Assets Plan assets at fair value, beginning of period 281 Actual return on plan assets 64 Employer contributions 1 Gross benefits paid (36) Plan assets at fair value, end of period 310 Funded Status, end of period $ 24 Amounts recognized in the Balance Sheets consist of: Noncurrent asset (liability) $ 24 Net amount recognized, end of period $ 24 Amounts recognized in regulatory assets (pre-tax) consist of: Prior service cost $ 17 Net actuarial loss 79 Total $ 96 Total accumulated benefit obligation for defined benefit pension plan $ 286 (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. LG&E's pension plan had plan assets in excess of projected and accumulated benefit obligations December 31, 2019. In addition to the plan it sponsored, LG&E is allocated a portion of the funded status and costs of certain defined benefit plans sponsored by LKE. LG&E 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 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 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: 2020 2019 Pension $ (78) $ (7) Other postretirement benefits 68 63 (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: 2020 2019 Pension $ (4) $ 179 Other postretirement benefits 99 122 (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. 2020 2019 Pension $ (62) $ (31) Other postretirement benefits 16 16 Plan Assets - U.S. Pension Plans (PPL, LKE and LG&E) 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 2020 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 2020 2020 2019 (a) Target Asset Growth Portfolio 56 % 57 % 55 % Equity securities 34 % 34 % Debt securities (b) 13 % 14 % Alternative investments 9 % 9 % Immunizing Portfolio 43 % 42 % 43 % Debt securities (b) 33 % 35 % Derivatives 10 % 7 % Liquidity Portfolio 1 % 1 % 2 % Total 100 % 100 % 100 % (a) Allocations exclude consideration of a group annuity contract held by the LG&E and KU Retirement Plan. (b) Includes commingled debt funds, which PPL treats as debt securities for asset allocation purposes. (LKE) LKE has pension plans whose assets are invested solely in the Master Trust, which is fully disclosed below. The fair value of these plans' assets of $1.7 billion and $1.5 billion at December 31, 2020 and 2019 represents an interest of approximately 41% in the Master Trust. (LG&E) LG&E had a pension plan whose assets were invested solely in the Master Trust, which is fully disclosed below. The fair value of this plan's assets of $310 million at December 31, 2019 represented an interest of approximately 9% in the Master Trust. 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. The fair value of LKE's plan assets allocated to LG&E was $618 million and $251 million at December 31, 2020 and 2019. (KU) The fair value of LKE's plan assets allocated to KU was $505 million and $445 million at December 31, 2020 and 2019 . (PPL, LKE and LG&E) The fair value of net assets in the Master Trust by asset class and level within the fair value hierarchy was: December 31, 2020 December 31, 2019 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 $ 300 $ 300 $ — $ — $ 182 $ 182 $ — $ — Equity securities: U.S. Equity 60 60 — — 194 194 — — U.S. Equity fund measured at NAV (a) 742 — — — 451 — — — International equity fund at NAV (a) 566 — — — 554 — — — Commingled debt measured at NAV (a) 712 — — — 621 — — — Debt securities: U.S. Treasury and U.S. government sponsored 336 335 1 — 310 309 1 — Corporate 1,045 — 1,030 15 951 — 931 20 Other 13 — 13 — 14 — 14 — December 31, 2020 December 31, 2019 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Alternative investments: Real estate measured at NAV (a) 76 — — — 88 — — — Private equity measured at NAV (a) 68 — — — 62 — — — Hedge funds measured at NAV (a) 223 — — — 194 — — — Limited Partnerships at NAV (a) 6 — — — — — — — Derivatives (37) — (37) — 3 — 3 — Insurance contracts — — — — 4 — — 4 PPL Services Corporation Master Trust assets, at 4,110 $ 695 $ 1,007 $ 15 3,628 $ 685 $ 949 $ 24 Receivables and payables, net (b) 116 99 401(h) accounts restricted for other (158) (142) Total PPL Services Corporation Master Trust $ 4,068 $ 3,585 (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, 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 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2019 is as follows: Corporate Insurance Total Balance at beginning of period $ 25 $ 21 $ 46 Actual return on plan assets: Relating to assets still held at the reporting date (1) 4 3 Relating to assets sold during the period 3 — 3 Purchases, sales and settlements (7) (21) (28) Balance at end of period $ 20 $ 4 $ 24 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; invest

Jointly Owned Facilities

Jointly Owned Facilities	12 Months Ended
	Dec. 31, 2020
Jointly Owned Facilities [Line Items]
Jointly Owned Facilities	(PPL, LKE, LG&E and KU) At December 31, 2020 and 2019, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL and LKE December 31, 2020 Trimble County Unit 1 75.00 % $ 440 $ 64 $ 2 Trimble County Unit 2 75.00 % 1,340 227 106 December 31, 2019 Trimble County Unit 1 75.00 % $ 440 $ 54 $ 2 Trimble County Unit 2 75.00 % 1,278 203 134 LG&E 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 — — December 31, 2019 E.W. Brown Units 6-7 38.00 % $ 45 $ 20 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 20 — Trimble County Unit 1 75.00 % 440 54 2 Trimble County Unit 2 14.25 % 340 43 69 Trimble County Units 5-6 29.00 % 32 12 — Trimble County Units 7-10 37.00 % 78 27 — Cane Run Unit 7 22.00 % 119 13 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 1 — — KU 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 — — December 31, 2019 E.W. Brown Units 6-7 62.00 % $ 75 $ 32 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 14 — Trimble County Unit 2 60.75 % 938 160 65 Trimble County Units 5-6 71.00 % 76 29 — Trimble County Units 7-10 63.00 % 128 46 — Cane Run Unit 7 78.00 % 429 49 1 E.W. Brown Solar Unit 61.00 % 16 2 — 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.
LG And E And KU Energy LLC [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Facilities	(PPL, LKE, LG&E and KU) At December 31, 2020 and 2019, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL and LKE December 31, 2020 Trimble County Unit 1 75.00 % $ 440 $ 64 $ 2 Trimble County Unit 2 75.00 % 1,340 227 106 December 31, 2019 Trimble County Unit 1 75.00 % $ 440 $ 54 $ 2 Trimble County Unit 2 75.00 % 1,278 203 134 LG&E 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 — — December 31, 2019 E.W. Brown Units 6-7 38.00 % $ 45 $ 20 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 20 — Trimble County Unit 1 75.00 % 440 54 2 Trimble County Unit 2 14.25 % 340 43 69 Trimble County Units 5-6 29.00 % 32 12 — Trimble County Units 7-10 37.00 % 78 27 — Cane Run Unit 7 22.00 % 119 13 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 1 — — KU 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 — — December 31, 2019 E.W. Brown Units 6-7 62.00 % $ 75 $ 32 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 14 — Trimble County Unit 2 60.75 % 938 160 65 Trimble County Units 5-6 71.00 % 76 29 — Trimble County Units 7-10 63.00 % 128 46 — Cane Run Unit 7 78.00 % 429 49 1 E.W. Brown Solar Unit 61.00 % 16 2 — 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, LKE, LG&E and KU) At December 31, 2020 and 2019, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL and LKE December 31, 2020 Trimble County Unit 1 75.00 % $ 440 $ 64 $ 2 Trimble County Unit 2 75.00 % 1,340 227 106 December 31, 2019 Trimble County Unit 1 75.00 % $ 440 $ 54 $ 2 Trimble County Unit 2 75.00 % 1,278 203 134 LG&E 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 — — December 31, 2019 E.W. Brown Units 6-7 38.00 % $ 45 $ 20 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 20 — Trimble County Unit 1 75.00 % 440 54 2 Trimble County Unit 2 14.25 % 340 43 69 Trimble County Units 5-6 29.00 % 32 12 — Trimble County Units 7-10 37.00 % 78 27 — Cane Run Unit 7 22.00 % 119 13 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 1 — — KU 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 — — December 31, 2019 E.W. Brown Units 6-7 62.00 % $ 75 $ 32 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 14 — Trimble County Unit 2 60.75 % 938 160 65 Trimble County Units 5-6 71.00 % 76 29 — Trimble County Units 7-10 63.00 % 128 46 — Cane Run Unit 7 78.00 % 429 49 1 E.W. Brown Solar Unit 61.00 % 16 2 — 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, LKE, LG&E and KU) At December 31, 2020 and 2019, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL and LKE December 31, 2020 Trimble County Unit 1 75.00 % $ 440 $ 64 $ 2 Trimble County Unit 2 75.00 % 1,340 227 106 December 31, 2019 Trimble County Unit 1 75.00 % $ 440 $ 54 $ 2 Trimble County Unit 2 75.00 % 1,278 203 134 LG&E 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 — — December 31, 2019 E.W. Brown Units 6-7 38.00 % $ 45 $ 20 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 20 — Trimble County Unit 1 75.00 % 440 54 2 Trimble County Unit 2 14.25 % 340 43 69 Trimble County Units 5-6 29.00 % 32 12 — Trimble County Units 7-10 37.00 % 78 27 — Cane Run Unit 7 22.00 % 119 13 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 1 — — KU 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 — — December 31, 2019 E.W. Brown Units 6-7 62.00 % $ 75 $ 32 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 14 — Trimble County Unit 2 60.75 % 938 160 65 Trimble County Units 5-6 71.00 % 76 29 — Trimble County Units 7-10 63.00 % 128 46 — Cane Run Unit 7 78.00 % 429 49 1 E.W. Brown Solar Unit 61.00 % 16 2 — 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, 2020
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Energy Purchase Commitments (PPL, LKE, 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 2023 Natural Gas Retail Supply 2022 Coal 2024 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 (f) 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 2021 $ 23 $ 11 $ 34 2022 23 11 34 2023 24 10 34 2024 22 10 32 2025 22 10 32 Thereafter 250 109 359 Total $ 364 $ 161 $ 525 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2020 2019 2018 LG&E $ 12 $ 15 $ 14 KU 6 7 6 Total $ 18 $ 22 $ 20 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 motion to dismiss. 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 a trial has been scheduled for February 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 and the Delaware Action are both in early stages of litigation; at this time, PPL cannot predict the outcome 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. (PPL, LKE and LG&E) Cane Run Environmental Claims 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 seek 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. PPL, LKE and LG&E cannot predict the outcome of this matter and an estimate or range of possible losses cannot be determined. (PPL, LKE and KU) E.W. Brown Environmental Claims 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 October 2018, KU filed a petition for rehearing to the U.S. Court of Appeals for the Sixth Circuit regarding the RCRA claims. In November 2018, the U.S. Court of Appeals for the Sixth Circuit denied KU's petition for rehearing regarding the RCRA claims. In January 2019, KU filed an answer to plaintiffs’ complaint in the U.S. District Court. Discovery is complete and the parties' motions for partial summary judgment are pending. In December 2020, the U.S. District Court delayed the trial scheduled for February 2, 2021 indefinitely due to pandemic considerations. PPL, LKE and KU cannot predict the outcome of these matters and an estimate or range of possible losses cannot be determined. KU is undertaking extensive remedial measures at the E.W. Brown plant including work preparing for 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. However, until the KEEC assesses the study and issues any regulatory determinations, PPL, LKE and KU are unable to determine whether additional remedial measures will be required at the E.W. Brown plant. Air Sulfuric Acid Mist Emissions (PPL, LKE and LG&E) 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. PPL, LKE and LG&E are unable to predict the outcome of this matter or the potential impact on operations of the Mill Creek plant, including increased capital or operating costs, and potential civil penalties or remedial measures, if any. An estimate or range of possible losses cannot be determined. Water/Waste (PPL, LKE, 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 rule will be implemented by the states or applicable permitting authorities in the course of their normal permitting activities. LG&E and KU have developed 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. See Note 7 for additional information regarding LG&E's and KU's applications for ECR rate treatment of construction costs relating to regulations addressing ELGs. 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 to adopt various other amendments to the rule. PPL, LKE, LG&E and KU are unable to predict the outcome of the ongoing litigation and rulemaking 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. The Kentucky Energy and Environmental Cabinet has announced it intends to propose new state rules aimed at addressing procedural deficiencies identified by the court and providing the regulatory framework necessary for operation of the state program in lieu of the federal CCR Rule. 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. Since 2017, LG&E and KU have commenced closure of many of the subject impoundments and have completed closure of some of their smaller impoundments. LG&E and KU expect to commence closure of the remaining impoundments no later than April 2021. 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 19 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 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 all of these sites, the costs of which have not been and are not expected to be significant to PPL Electric. At December 31, 2020 and December 31, 2019, 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. PPL, PPL Electric, LKE, LG&E and KU cannot 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. Other Labor Union Agreements (LKE and KU) In August 2020, KU and the United Steelworkers of America ratified a three-year labor agreement through August 2023. The agreement covers approximately 48 employees. The terms of the new labor agreement are not expected to have a significant impact on the financial results of LKE or KU. (LKE and LG&E) In November 2020, LG&E and the IBEW ratified a three-year collective bargaining agreement through November 2023. The agreement covers approximately 640 employees. The terms of the labor agreement are not expected to have a significant impact on the financial results of LKE or LG&E. 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, 2020. "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 except for "WPD guarantee of pension and other obligations of unconsolidated entities," for which PPL has a total recorded liability of $5 million at December 31, 2020 and December 31, 2019. For reporting purposes, on a consolidated basis, all guarantees of PPL Electric, LKE, LG&E and KU also apply to PPL, and all guarantees of LG&E and KU also apply to LKE. Exposure at December 31, 2020 Expiration PPL WPD indemnifications for entities in liquidation and sales of assets $ 11 (a) 2022 WPD guarantee of pension and other obligations of unconsolidated entities 95 (b) LKE Indemnification of lease termination and other divestitures 200 (c) 2021 LG&E and KU LG&E and KU obligation of shortfall related to OVEC (d) (a) Indemnification to the liquidators and certain others for existing liabilities or expenses or liabilities arising during the liquidation process. The indemnifications are limited to distributions made from the subsidiary to its parent either prior or subsequent to liquidation or are not explicitly stated in the agreements. The indemnifications generally expire two to seven years subsequent to the date of dissolution of the entities. The exposure noted only includes those cases where the agreements provide for specific limits. In connection with their sales of various businesses, WPD and its affiliates have provided the purchasers with indemnifications that are standard for such transactions, including indemnifications for certain pre-existing liabilities and environmental and tax matters or have agreed to continue their obligations under existing third-party guarantees, either for a set period of time following the transactions or upon the condition that the purchasers make reasonable efforts to terminate the guarantees. Additionally, WPD and its affiliates remain secondarily responsible for lease payments under certain leases that they have assigned to third parties. (b) Relates to certain obligations of discontinued or modified electric associations that were guaranteed at the time of privatization by the participating members. Costs are allocated to the members and can be reallocated if an existing member becomes insolvent. At December 31, 2020, WPD has recorded an estimated discounted liability for which the expected payment/performance is probable. Neither the expiration date nor the maximum amount of potential payments for certain obligations is explicitly stated in the related agreements, and as a result, the exposure has been estimated. (c) LKE provides certain indemnifications covering the due and punctual payment, performance and discharge by each party of its respective obligations. The most comprehensive of these guarantees is the LKE guarantee covering operational, regulatory and environmental commitments and indemnifications made by WKE under a 2009 Transaction Termination Agreement. This guarantee has a term of 12 years ending July 2021, and a maximum exposure of $200 million, exclusive of certain items such as government fines and penalties that may exceed the maximum. Additionally, LKE has indemnified various third parties related to historical obligations for other divested subsidiaries and affiliates. The indemnifications vary by entity and the maximum exposures range from being capped at the sale price to no specified maximum. LKE could be required to perform on these indemnifications in the event of covered losses or liabilities being claimed by an indemnified party. LKE cannot predict the ultimate outcomes of the various indemnification scenarios, but does not expect such outcomes to result in significant losses above the amounts recorded. (d) 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. LKE's proportionate share of OVEC's outstanding debt was $104 million at December 31, 2020, consisting of LG&E's share of $72 million and KU's share of $32 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. Periodically, OVEC and certain of its sponsors, including LG&E and KU, may consider certain potential additional credit support actions to preserve OVEC's access to credit markets, including establishing or continuing debt reserve accounts or other changes involving OVEC's existing short and long-term debt. 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 extraordinary challenges to businesses, communities, workforces and markets. I

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2020
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, LKE, LG&E and KU) PPL Services, PPL EU Services and LKS provide PPL, PPL Electric and LKE, their respective subsidiaries, including LG&E and KU, 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. 2020 2019 2018 PPL Electric from PPL Services $ 50 $ 59 $ 59 LKE from PPL Services 27 28 26 PPL Electric from PPL EU Services 176 152 148 LG&E from LKS 170 160 151 KU from LKS 180 178 169 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 LKE and LG&E and KU are reimbursed through LKS. Intercompany Borrowings (PPL Electric) PPL Energy Funding maintains a $650 million revolving line of credit with a PPL Electric subsidiary. No balance was outstanding at December 31, 2020 and 2019. 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. (LKE) LKE maintains a $375 million revolving line of credit with a PPL Energy Funding subsidiary whereby LKE can borrow funds on a short-term basis at market-based rates. The interest rates on borrowings are equal to one-month LIBOR plus a spread. At December 31, 2020 and 2019, $251 million and $150 million were outstanding and reflected in "Notes payable with affiliates" on the Balance Sheets. The interest rate on the outstanding borrowings at December 31, 2020 and 2019 were 1.65% and 3.20%. Interest expense on the revolving line of credit was not significant for 2020, 2019 or 2018. LKE maintains an agreement with a PPL affiliate that has a $300 million borrowing limit whereby LKE can loan funds on a short-term basis at market-based rates. No balance was outstanding at December 31, 2020 and 2019. The interest rate on the loan based on the PPL affiliates credit rating is currently equal to one-month LIBOR plus a spread. LKE maintains 10-year notes with a combined value of $1.2 billion with a PPL affiliate with a weighted-average interest rate of 3.9% and maturities ranging from 2026 to 2030. This is inclusive of a 10-year note of $550 million that was entered into in August 2020. At December 31, 2020 and 2019, the notes were reflected in "Long-term debt to affiliate" on the Balance Sheets. Interest expense on the notes was $33 million for 2020, $24 million for 2019, and $21 million for 2018. In May 2020, LKE entered into a $450 million term loan credit agreement with a PPL affiliate whereby LKE could borrow funds on a short-term basis at market-based rates. Interest on borrowings was determined as the lower of the daily rate for 30-day non-financial commercial paper programs plus a spread or one-month LIBOR plus a spread. The agreement expired on August 31, 2020. Interest expense on borrowings was not significant for 2020. (LG&E) LG&E participates in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E funds up to $750 million at an interest rate based on a market index of commercial paper issues. No balances were outstanding at December 31, 2020 and 2019. (KU) KU participates in an intercompany money pool agreement whereby LKE and/or LG&E make available to KU funds up to $650 million at an interest rate based on a market index of commercial paper issues. No balances were outstanding at December 31, 2020 and 2019. 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 $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. The intercompany receivable balance associated with these funds was $32 million as of December 31, 2019, of which $10 million was reflected in "Accounts receivable from affiliates" and $22 million was reflected in "Other noncurrent assets" on the Balance Sheets. Other (PPL Electric, LKE, LG&E and KU) See Note 1 for discussions regarding the intercompany tax sharing agreement (for PPL Electric, LKE, LG&E and KU) and intercompany allocations of stock-based compensation expense (for PPL Electric and LKE). For PPL Electric, LG&E and KU, see Note 12 for discussions regarding intercompany allocations associated with defined benefits.
LG And E And KU Energy LLC [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, LKE, LG&E and KU) PPL Services, PPL EU Services and LKS provide PPL, PPL Electric and LKE, their respective subsidiaries, including LG&E and KU, 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. 2020 2019 2018 PPL Electric from PPL Services $ 50 $ 59 $ 59 LKE from PPL Services 27 28 26 PPL Electric from PPL EU Services 176 152 148 LG&E from LKS 170 160 151 KU from LKS 180 178 169 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 LKE and LG&E and KU are reimbursed through LKS. Intercompany Borrowings (PPL Electric) PPL Energy Funding maintains a $650 million revolving line of credit with a PPL Electric subsidiary. No balance was outstanding at December 31, 2020 and 2019. 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. (LKE) LKE maintains a $375 million revolving line of credit with a PPL Energy Funding subsidiary whereby LKE can borrow funds on a short-term basis at market-based rates. The interest rates on borrowings are equal to one-month LIBOR plus a spread. At December 31, 2020 and 2019, $251 million and $150 million were outstanding and reflected in "Notes payable with affiliates" on the Balance Sheets. The interest rate on the outstanding borrowings at December 31, 2020 and 2019 were 1.65% and 3.20%. Interest expense on the revolving line of credit was not significant for 2020, 2019 or 2018. LKE maintains an agreement with a PPL affiliate that has a $300 million borrowing limit whereby LKE can loan funds on a short-term basis at market-based rates. No balance was outstanding at December 31, 2020 and 2019. The interest rate on the loan based on the PPL affiliates credit rating is currently equal to one-month LIBOR plus a spread. LKE maintains 10-year notes with a combined value of $1.2 billion with a PPL affiliate with a weighted-average interest rate of 3.9% and maturities ranging from 2026 to 2030. This is inclusive of a 10-year note of $550 million that was entered into in August 2020. At December 31, 2020 and 2019, the notes were reflected in "Long-term debt to affiliate" on the Balance Sheets. Interest expense on the notes was $33 million for 2020, $24 million for 2019, and $21 million for 2018. In May 2020, LKE entered into a $450 million term loan credit agreement with a PPL affiliate whereby LKE could borrow funds on a short-term basis at market-based rates. Interest on borrowings was determined as the lower of the daily rate for 30-day non-financial commercial paper programs plus a spread or one-month LIBOR plus a spread. The agreement expired on August 31, 2020. Interest expense on borrowings was not significant for 2020. (LG&E) LG&E participates in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E funds up to $750 million at an interest rate based on a market index of commercial paper issues. No balances were outstanding at December 31, 2020 and 2019. (KU) KU participates in an intercompany money pool agreement whereby LKE and/or LG&E make available to KU funds up to $650 million at an interest rate based on a market index of commercial paper issues. No balances were outstanding at December 31, 2020 and 2019. 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 $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. The intercompany receivable balance associated with these funds was $32 million as of December 31, 2019, of which $10 million was reflected in "Accounts receivable from affiliates" and $22 million was reflected in "Other noncurrent assets" on the Balance Sheets. Other (PPL Electric, LKE, LG&E and KU) See Note 1 for discussions regarding the intercompany tax sharing agreement (for PPL Electric, LKE, LG&E and KU) and intercompany allocations of stock-based compensation expense (for PPL Electric and LKE). 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, LKE, LG&E and KU) PPL Services, PPL EU Services and LKS provide PPL, PPL Electric and LKE, their respective subsidiaries, including LG&E and KU, 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. 2020 2019 2018 PPL Electric from PPL Services $ 50 $ 59 $ 59 LKE from PPL Services 27 28 26 PPL Electric from PPL EU Services 176 152 148 LG&E from LKS 170 160 151 KU from LKS 180 178 169 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 LKE and LG&E and KU are reimbursed through LKS. Intercompany Borrowings (PPL Electric) PPL Energy Funding maintains a $650 million revolving line of credit with a PPL Electric subsidiary. No balance was outstanding at December 31, 2020 and 2019. 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. (LKE) LKE maintains a $375 million revolving line of credit with a PPL Energy Funding subsidiary whereby LKE can borrow funds on a short-term basis at market-based rates. The interest rates on borrowings are equal to one-month LIBOR plus a spread. At December 31, 2020 and 2019, $251 million and $150 million were outstanding and reflected in "Notes payable with affiliates" on the Balance Sheets. The interest rate on the outstanding borrowings at December 31, 2020 and 2019 were 1.65% and 3.20%. Interest expense on the revolving line of credit was not significant for 2020, 2019 or 2018. LKE maintains an agreement with a PPL affiliate that has a $300 million borrowing limit whereby LKE can loan funds on a short-term basis at market-based rates. No balance was outstanding at December 31, 2020 and 2019. The interest rate on the loan based on the PPL affiliates credit rating is currently equal to one-month LIBOR plus a spread. LKE maintains 10-year notes with a combined value of $1.2 billion with a PPL affiliate with a weighted-average interest rate of 3.9% and maturities ranging from 2026 to 2030. This is inclusive of a 10-year note of $550 million that was entered into in August 2020. At December 31, 2020 and 2019, the notes were reflected in "Long-term debt to affiliate" on the Balance Sheets. Interest expense on the notes was $33 million for 2020, $24 million for 2019, and $21 million for 2018. In May 2020, LKE entered into a $450 million term loan credit agreement with a PPL affiliate whereby LKE could borrow funds on a short-term basis at market-based rates. Interest on borrowings was determined as the lower of the daily rate for 30-day non-financial commercial paper programs plus a spread or one-month LIBOR plus a spread. The agreement expired on August 31, 2020. Interest expense on borrowings was not significant for 2020. (LG&E) LG&E participates in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E funds up to $750 million at an interest rate based on a market index of commercial paper issues. No balances were outstanding at December 31, 2020 and 2019. (KU) KU participates in an intercompany money pool agreement whereby LKE and/or LG&E make available to KU funds up to $650 million at an interest rate based on a market index of commercial paper issues. No balances were outstanding at December 31, 2020 and 2019. 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 $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. The intercompany receivable balance associated with these funds was $32 million as of December 31, 2019, of which $10 million was reflected in "Accounts receivable from affiliates" and $22 million was reflected in "Other noncurrent assets" on the Balance Sheets. Other (PPL Electric, LKE, LG&E and KU) See Note 1 for discussions regarding the intercompany tax sharing agreement (for PPL Electric, LKE, LG&E and KU) and intercompany allocations of stock-based compensation expense (for PPL Electric and LKE). 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, LKE, LG&E and KU) PPL Services, PPL EU Services and LKS provide PPL, PPL Electric and LKE, their respective subsidiaries, including LG&E and KU, 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. 2020 2019 2018 PPL Electric from PPL Services $ 50 $ 59 $ 59 LKE from PPL Services 27 28 26 PPL Electric from PPL EU Services 176 152 148 LG&E from LKS 170 160 151 KU from LKS 180 178 169 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 LKE and LG&E and KU are reimbursed through LKS. Intercompany Borrowings (PPL Electric) PPL Energy Funding maintains a $650 million revolving line of credit with a PPL Electric subsidiary. No balance was outstanding at December 31, 2020 and 2019. 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. (LKE) LKE maintains a $375 million revolving line of credit with a PPL Energy Funding subsidiary whereby LKE can borrow funds on a short-term basis at market-based rates. The interest rates on borrowings are equal to one-month LIBOR plus a spread. At December 31, 2020 and 2019, $251 million and $150 million were outstanding and reflected in "Notes payable with affiliates" on the Balance Sheets. The interest rate on the outstanding borrowings at December 31, 2020 and 2019 were 1.65% and 3.20%. Interest expense on the revolving line of credit was not significant for 2020, 2019 or 2018. LKE maintains an agreement with a PPL affiliate that has a $300 million borrowing limit whereby LKE can loan funds on a short-term basis at market-based rates. No balance was outstanding at December 31, 2020 and 2019. The interest rate on the loan based on the PPL affiliates credit rating is currently equal to one-month LIBOR plus a spread. LKE maintains 10-year notes with a combined value of $1.2 billion with a PPL affiliate with a weighted-average interest rate of 3.9% and maturities ranging from 2026 to 2030. This is inclusive of a 10-year note of $550 million that was entered into in August 2020. At December 31, 2020 and 2019, the notes were reflected in "Long-term debt to affiliate" on the Balance Sheets. Interest expense on the notes was $33 million for 2020, $24 million for 2019, and $21 million for 2018. In May 2020, LKE entered into a $450 million term loan credit agreement with a PPL affiliate whereby LKE could borrow funds on a short-term basis at market-based rates. Interest on borrowings was determined as the lower of the daily rate for 30-day non-financial commercial paper programs plus a spread or one-month LIBOR plus a spread. The agreement expired on August 31, 2020. Interest expense on borrowings was not significant for 2020. (LG&E) LG&E participates in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E funds up to $750 million at an interest rate based on a market index of commercial paper issues. No balances were outstanding at December 31, 2020 and 2019. (KU) KU participates in an intercompany money pool agreement whereby LKE and/or LG&E make available to KU funds up to $650 million at an interest rate based on a market index of commercial paper issues. No balances were outstanding at December 31, 2020 and 2019. 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 $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. The intercompany receivable balance associated with these funds was $32 million as of December 31, 2019, of which $10 million was reflected in "Accounts receivable from affiliates" and $22 million was reflected in "Other noncurrent assets" on the Balance Sheets. Other (PPL Electric, LKE, LG&E and KU) See Note 1 for discussions regarding the intercompany tax sharing agreement (for PPL Electric, LKE, LG&E and KU) and intercompany allocations of stock-based compensation expense (for PPL Electric and LKE). 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, 2020
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: 2020 2019 2018 Other Income Economic foreign currency exchange contracts (Note 18) $ (98) $ (14) $ 150 Defined benefit plans - non-service credits (Note 12) 262 316 257 Interest income 10 16 6 AFUDC - equity component 20 23 21 Miscellaneous 7 7 6 Total Other Income 201 348 440 Other Expense Charitable contributions 3 17 24 Miscellaneous 29 22 20 Total Other Expense 32 39 44 Other Income (Expense) - net $ 169 $ 309 $ 396 (PPL Electric) The components of "Other Income (Expense) - net" for the years ended December 31, were: 2020 2019 2018 Other Income Defined benefit plans - non-service credits (Note 12) $ 4 $ 4 $ 5 Interest income 2 2 2 AFUDC - equity component 19 23 20 Total Other Income 25 29 27 Other Expense Charitable contributions 3 3 3 Miscellaneous 4 1 1 Total Other Expense 7 4 4 Other Income (Expense) - net $ 18 $ 25 $ 23
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: 2020 2019 2018 Other Income Defined benefit plans - non-service credits (Note 12) $ 4 $ 4 $ 5 Interest income 2 2 2 AFUDC - equity component 19 23 20 Total Other Income 25 29 27 Other Expense Charitable contributions 3 3 3 Miscellaneous 4 1 1 Total Other Expense 7 4 4 Other Income (Expense) - net $ 18 $ 25 $ 23

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2020
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, 2020 December 31, 2019 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 708 $ 708 $ — $ — $ 815 $ 815 $ — $ — Restricted cash and cash equivalents (a) 19 19 — — 21 21 — — Special use funds (a): Commingled debt fund measured at NAV (b) 26 — — — 29 — — — Commingled equity fund measured at NAV (b) 25 — — — 27 — — — Total special use funds 51 — — — 56 — — — Price risk management assets (c): Foreign currency contracts — — — — 142 — 142 — Cross-currency swaps 146 — 146 — 154 — 154 — Total price risk management assets 146 — 146 — 296 — 296 — Total assets $ 924 $ 727 $ 146 $ — $ 1,188 $ 836 $ 296 $ — Liabilities Price risk management liabilities (c): Interest rate swaps $ 23 $ — $ 23 $ — $ 21 $ — $ 21 $ — Foreign currency contracts 137 — 137 — 5 — 5 — Total price risk management liabilities $ 160 $ — $ 160 $ — $ 26 $ — $ 26 $ — December 31, 2020 December 31, 2019 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Electric Assets Cash and cash equivalents $ 40 $ 40 $ — $ — $ 262 $ 262 $ — $ — Restricted cash and cash equivalents (a) — — — — 2 2 — — Total assets $ 40 $ 40 $ — $ — $ 264 $ 264 $ — $ — LKE Assets Cash and cash equivalents $ 29 $ 29 $ — $ — $ 27 $ 27 $ — $ — Total assets $ 29 $ 29 $ — $ — $ 27 $ 27 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 23 $ — $ 23 $ — $ 21 $ — $ 21 $ — Total price risk management liabilities $ 23 $ — $ 23 $ — $ 21 $ — $ 21 $ — LG&E Assets Cash and cash equivalents $ 7 $ 7 $ — $ — $ 15 $ 15 $ — $ — Total assets $ 7 $ 7 $ — $ — $ 15 $ 15 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 23 $ — $ 23 $ — $ 21 $ — $ 21 $ — Total price risk management liabilities $ 23 $ — $ 23 $ — $ 21 $ — $ 21 $ — KU Assets Cash and cash equivalents $ 22 $ 22 $ — $ — $ 12 $ 12 $ — $ — Total assets $ 22 $ 22 $ — $ — $ 12 $ 12 $ — $ — (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 "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. 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, LKE, LG&E and KU) To manage interest rate risk, PPL, LKE, 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, 2020 December 31, 2019 Carrying Fair Value Carrying Fair Value PPL $ 23,127 $ 28,765 $ 21,893 $ 25,481 PPL Electric 4,236 5,338 3,985 4,589 LKE 6,074 7,589 6,002 6,766 LG&E 2,007 2,499 2,005 2,278 KU 2,618 3,334 2,623 3,003 (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, 2020
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. PPL and WPD hold 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, LKE and LG&E utilize over-the-counter interest rate swaps to limit exposure to market fluctuations on floating-rate debt. PPL, LKE, 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 for certain plans at WPD due to the recovery methods in place. Foreign Currency Risk (PPL) • PPL is 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 is exposed to volumetric risk which is significantly mitigated as a result of the method of regulation in the U.K. Under the RIIO-ED1 price control regulations, recovery of such exposure occurs on a two year lag. See Note 1 for additional information on revenue recognition under RIIO-ED1. • 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 at the regulated domestic utilities and for certain plans at WPD 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, LKE, 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 an immaterial amount and $14 million obligation to return cash collateral under master netting arrangements at December 31, 2020 and 2019. PPL had no obligation to post cash collateral under master netting arrangements at December 31, 2020 and 2019. LKE, LG&E and KU had no obligation to return cash collateral under master netting arrangements at December 31, 2020 and 2019. LKE, LG&E and KU had no cash collateral posted under master netting arrangements at December 31, 2020 and 2019. 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, 2020. At December 31, 2020, PPL held an aggregate notional value in cross-currency interest rate swap contracts of $702 million that range in maturity from 2021 through 2028 to hedge the interest payments and principal of WPD's U.S. dollar-denominated senior notes. 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 2020, 2019 and 2018, PPL had no cash flow hedges reclassified into earnings associated with discontinued cash flow hedges. At December 31, 2020, 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, LKE 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, 2020, LG&E held contracts with a notional amount of $64 million that mature in 2033. Foreign Currency Risk (PPL) PPL is 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 previously announced potential sale of its U.K utility business and net investments. In addition, PPL enters into financial instruments to protect against foreign currency translation risk of expected GBP earnings. Net Investment Hedges PPL enters 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, 2020. At December 31, 2020 and 2019, PPL had $33 million and $32 million of accumulated net investment hedge after tax gains (losses) that were included in the foreign currency translation adjustment component of AOCI. Economic Activity PPL enters into foreign currency contracts on behalf of a subsidiary to economically hedge GBP-denominated anticipated earnings and anticipated transactions, including the previously announced potential sale of its U.K. utility business. At December 31, 2020, the total exposure hedged by PPL was approximately £4 billion. Accounting and Reporting (All Registrants) All derivative instruments are recorded at fair value on the Balance Sheet as an asset or liability unless 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, 2020 and 2019. 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, 2020 December 31, 2019 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) $ — $ — $ — $ 2 $ — $ — $ — $ 4 Cross-currency swaps (b) 94 — — — 5 — — — Foreign currency contracts — — — 137 — — 142 5 Total current 94 — — 139 5 — 142 9 Noncurrent: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) — — — 21 — — — 17 Cross-currency swaps (b) 52 — — — 149 — — — Total noncurrent 52 — — 21 149 — — 17 Total derivatives $ 146 $ — $ — $ 160 $ 154 $ — $ 142 $ 26 (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. 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 2020 Cash Flow Hedges: Interest rate swaps $ (9) Interest Expense $ (10) Cross-currency swaps (15) Other Income (Expense) - net (22) Total $ (24) $ (32) Net Investment Hedges: Foreign currency contracts $ 1 2019 Cash Flow Hedges: Interest rate swaps $ (30) Interest Expense $ (9) Cross-currency swaps 17 Other Income (Expense) - net (9) Total $ (13) $ (18) Net Investment Hedges: Foreign currency contracts $ 2 2018 Cash Flow Hedges: Interest rate swaps $ 4 Interest Expense $ (8) Cross-currency swaps 41 Other Income (Expense) - net 42 Interest Expense 1 Total $ 45 $ 35 Net Investment Hedges: Foreign currency contracts $ 11 Derivatives Not Designated as Location of Gain (Loss) Recognized in 2020 2019 2018 Foreign currency contracts Other Income (Expense) - net $ (98) $ (14) $ 150 Interest rate swaps Interest Expense (5) (5) (5) Total $ (103) $ (19) $ 145 Derivatives Not Designated as Location of Gain (Loss) Recognized as 2020 2019 2018 Interest rate swaps Regulatory assets - noncurrent $ (2) $ (1) $ 6 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 Other Income (Expense) - net Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 1,001 $ 169 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 (10) — 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 Other Income (Expense) - net Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 994 $ 309 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) (LKE and 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, 2020 December 31, 2019 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ 2 $ — $ 4 Total current — 2 — 4 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 21 — 17 Total noncurrent — 21 — 17 Total derivatives $ — $ 23 $ — $ 21 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) 2020 2019 2018 Interest rate swaps Interest Expense $ (5) $ (5) $ (5) Derivative Instruments Location of Gain (Loss) 2020 2019 2018 Interest rate swaps Regulatory assets - noncurrent $ (2) $ (1) $ 6 (PPL, LKE, LG&E and KU) Offsetting Derivative Instruments PPL, LKE, 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, LKE, 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, 2020 Treasury Derivatives PPL $ 146 $ 34 $ — $ 112 $ 160 $ 34 $ — $ 126 LKE — — — — 23 — — 23 LG&E — — — — 23 — — 23 December 31, 2019 Treasury Derivatives PPL $ 296 $ 5 $ 14 $ 277 $ 26 $ 5 $ — $ 21 LKE — — — — 21 — — 21 LG&E — — — — 21 — — 21 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, LKE, 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, LKE'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, 2020, 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 are summarized as follows: PPL Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features $ 102 Aggregate fair value of collateral posted on these derivative instruments — Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a) 102 (a) Includes the effect of net receivables and payables already recorded on the Balance Sheet.

Goodwill and Other Intangible A

Goodwill and Other Intangible Assets	12 Months Ended
	Dec. 31, 2020
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Other Intangible Assets	Goodwill (PPL) The changes in the carrying amount of goodwill by segment were: U.K. Kentucky Corporate and Total 2020 2019 2020 2019 2020 2019 2020 2019 Balance at beginning of period (a) $ 2,483 $ 2,447 $ 662 $ 662 $ 53 $ 53 $ 3,198 $ 3,162 Effect of foreign currency exchange rates 76 34 — — — — 76 34 Other — 2 — — — — — 2 Balance at end of period (a) $ 2,559 $ 2,483 $ 662 $ 662 $ 53 $ 53 $ 3,274 $ 3,198 (a) 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, 2020 December 31, 2019 Gross Accumulated Gross Accumulated Subject to amortization: Contracts (a) $ 136 $ 93 $ 136 $ 84 Land rights and easements 460 142 440 135 Licenses and other 21 4 22 3 Total subject to amortization 617 239 598 222 Not subject to amortization due to indefinite life: Land rights and easements 380 — 361 — Other 6 — 6 — Total not subject to amortization due to indefinite life 386 — 367 — Total $ 1,003 $ 239 $ 965 $ 222 (a) Gross carrying amount in 2020 and 2019 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: 2020 2019 2018 Intangible assets with no regulatory offset $ 11 $ 9 $ 7 Intangible assets with regulatory offset 8 9 8 Total $ 19 $ 18 $ 15 Amortization expense for each of the next five years is estimated to be: 2021 2022 2023 2024 2025 Intangible assets with no regulatory offset $ 11 $ 11 $ 11 $ 11 $ 11 Intangible assets with regulatory offset 8 8 8 8 8 Total $ 19 $ 19 $ 19 $ 19 $ 19 (PPL Electric) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2020 December 31, 2019 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 379 $ 129 $ 370 $ 125 Licenses and other 2 1 3 1 Total subject to amortization 381 130 373 126 Not subject to amortization due to indefinite life: Land rights and easements 17 — 17 — Total $ 398 $ 130 $ 390 $ 126 Intangible assets are shown as "Intangibles" on the Balance Sheets. Amortization expense was as follows: 2020 2019 2018 Intangible assets with no regulatory offset $ 4 $ 4 $ 4 Amortization expense for each of the next five years is estimated to be: 2021 2022 2023 2024 2025 Intangible assets with no regulatory offset $ 4 $ 4 $ 4 $ 4 $ 4 (LKE) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2020 December 31, 2019 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 22 $ 4 $ 22 $ 4 OVEC power purchase agreement (a) 125 82 125 74 Total subject to amortization $ 147 $ 86 $ 147 $ 78 (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: 2020 2019 2018 Intangible assets with regulatory offset $ 8 $ 9 $ 8 Amortization expense for each of the next five years is estimated to be: 2021 2022 2023 2024 2025 Intangible assets with regulatory offset $ 8 $ 8 $ 8 $ 8 $ 8 (LG&E) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2020 December 31, 2019 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 7 $ 1 $ 7 $ 1 OVEC power purchase agreement (a) 86 57 86 51 Total subject to amortization $ 93 $ 58 $ 93 $ 52 (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: 2020 2019 2018 Intangible assets with regulatory offset $ 6 $ 6 $ 6 Amortization expense for each of the next five years is estimated to be: 2021 2022 2023 2024 2025 Intangible assets with regulatory offset $ 6 $ 6 $ 6 $ 6 $ 6 (KU) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2020 December 31, 2019 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 15 $ 3 $ 15 $ 3 OVEC power purchase agreement (a) 39 25 39 23 Total subject to amortization $ 54 $ 28 $ 54 $ 26 (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: 2020 2019 2018 Intangible assets with regulatory offset $ 2 $ 3 $ 2 Amortization expense for each of the next five years is estimated to be: 2021 2022 2023 2024 2025 Intangible assets with regulatory offset $ 2 $ 2 $ 2 $ 2 $ 2

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2020
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	(PPL) WPD has recorded conditional AROs required by U.K. law related to treated wood poles, gas-filled switchgear and fluid-filled cables. (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, LKE, LG&E and KU) PPL's LKE'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 LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, at the time of retirement, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability. The changes in the carrying amounts of AROs were as follows: PPL LKE LG&E KU 2020 2019 2020 2019 2020 2019 2020 2019 ARO at beginning of period $ 282 $ 347 $ 215 $ 296 $ 73 $ 103 $ 142 $ 193 Accretion 17 19 15 17 5 6 10 11 Obligations incurred — — — — — — — — Changes in estimated timing or cost 38 12 40 (2) 13 (2) 27 — Effect of foreign currency exchange rates 1 — — — — — — — Obligations settled (88) (96) (88) (96) (24) (34) (64) (62) ARO at end of period $ 250 $ 282 $ 182 $ 215 $ 67 $ 73 $ 115 $ 142

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income	12 Months Ended
	Dec. 31, 2020
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss)	(PPL and LKE) The after-tax changes in AOCI by component for the years ended December 31 were as follows: Defined benefit plans (b) Foreign Unrealized gains (losses) on Prior Actuarial Total PPL December 31, 2017 $ (1,089) $ (13) $ (7) $ (2,313) $ (3,422) Amounts arising during the year (444) 36 (11) (187) (606) Reclassifications from AOCI — (29) 2 142 115 Net OCI during the year (444) 7 (9) (45) (491) Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment $ — $ (1) $ (3) $ (47) (51) Defined benefit plans (b) Foreign Unrealized gains (losses) on Prior Actuarial Total 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) LKE December 31, 2017 $ (9) $ (79) $ (88) Amounts arising during the year — 7 7 Reclassifications from AOCI 2 8 10 Net OCI during the year 2 15 17 Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment (Note 1) (2) (16) (18) December 31, 2018 $ (9) $ (80) $ (89) Amounts arising during the year (1) (6) (7) Reclassifications from AOCI 1 2 3 Net OCI during the year — (4) (4) December 31, 2019 $ (9) $ (84) $ (93) Amounts arising during the year (1) (7) (8) Reclassifications from AOCI 2 13 15 Net OCI during the year 1 6 7 December 31, 2020 $ (8) $ (78) $ (86) (a) Amounts relate to the operations of WPD. (b) For PPL, substantially all of the amounts relate to WPD's pension plans. At December 31, 2020, the combined accumulated other comprehensive loss related to these plans was $2.9 billion. The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the years ended December 31, 2020, 2019 and 2018. LKE amounts are insignificant for the years ended December 31, 2020, 2019 and 2018. 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 2020 2019 2018 Affected Line Item on the Qualifying derivatives Interest rate swaps $ (10) $ (9) $ (8) Interest Expense Cross-currency swaps (22) (9) 42 Other Income (Expense) - net — — 1 Interest Expense Total Pre-tax (32) (18) 35 Income Taxes 8 5 (6) Total After-tax (24) (13) 29 Defined benefit plans Prior service costs (4) (3) (2) Net actuarial loss (256) (109) (178) Total Pre-tax (260) (112) (180) Income Taxes 52 23 36 Total After-tax (208) (89) (144) Total reclassifications during the year $ (232) $ (102) $ (115)
LG And E And KU Energy LLC [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss)	(PPL and LKE) The after-tax changes in AOCI by component for the years ended December 31 were as follows: Defined benefit plans (b) Foreign Unrealized gains (losses) on Prior Actuarial Total PPL December 31, 2017 $ (1,089) $ (13) $ (7) $ (2,313) $ (3,422) Amounts arising during the year (444) 36 (11) (187) (606) Reclassifications from AOCI — (29) 2 142 115 Net OCI during the year (444) 7 (9) (45) (491) Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment $ — $ (1) $ (3) $ (47) (51) Defined benefit plans (b) Foreign Unrealized gains (losses) on Prior Actuarial Total 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) LKE December 31, 2017 $ (9) $ (79) $ (88) Amounts arising during the year — 7 7 Reclassifications from AOCI 2 8 10 Net OCI during the year 2 15 17 Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment (Note 1) (2) (16) (18) December 31, 2018 $ (9) $ (80) $ (89) Amounts arising during the year (1) (6) (7) Reclassifications from AOCI 1 2 3 Net OCI during the year — (4) (4) December 31, 2019 $ (9) $ (84) $ (93) Amounts arising during the year (1) (7) (8) Reclassifications from AOCI 2 13 15 Net OCI during the year 1 6 7 December 31, 2020 $ (8) $ (78) $ (86) (a) Amounts relate to the operations of WPD. (b) For PPL, substantially all of the amounts relate to WPD's pension plans. At December 31, 2020, the combined accumulated other comprehensive loss related to these plans was $2.9 billion. The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the years ended December 31, 2020, 2019 and 2018. LKE amounts are insignificant for the years ended December 31, 2020, 2019 and 2018. 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 2020 2019 2018 Affected Line Item on the Qualifying derivatives Interest rate swaps $ (10) $ (9) $ (8) Interest Expense Cross-currency swaps (22) (9) 42 Other Income (Expense) - net — — 1 Interest Expense Total Pre-tax (32) (18) 35 Income Taxes 8 5 (6) Total After-tax (24) (13) 29 Defined benefit plans Prior service costs (4) (3) (2) Net actuarial loss (256) (109) (178) Total Pre-tax (260) (112) (180) Income Taxes 52 23 36 Total After-tax (208) (89) (144) Total reclassifications during the year $ (232) $ (102) $ (115)

New Accounting Guidance Pending

New Accounting Guidance Pending Adoption	12 Months Ended
	Dec. 31, 2020
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.

SCHEDULE I - CONDENSED UNCONS_3

SCHEDULE I - CONDENSED UNCONSOLICATED FINANCIAL STATEMENTS AND NOTES TO CONDENSED UNCONSOLIDATED FINANCIAL STATEMENTS	12 Months Ended
	Dec. 31, 2020
LG&E and KU Energy LLC Unconsolidated [Member]
Condensed Unconsolidated Financial Information [Line Items]
Schedule I - Condensed Unconsolidated Financial Information	SCHEDULE I - LG&E and KU Energy LLC CONDENSED UNCONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME FOR THE YEARS ENDED DECEMBER 31, (Millions of Dollars) 2020 2019 2018 Other Income (Expense) - net Equity in Earnings of Subsidiaries $ 490 $ 477 $ 470 Interest Income with Affiliate 12 28 25 Total 502 505 495 Interest Expense 23 30 29 Interest Expense with Affiliate 37 32 28 Income Before Income Taxes 442 443 438 Income Tax Expense (Benefit) (8) (25) (7) Net Income $ 450 $ 468 $ 445 Total other comprehensive income (loss) 7 (4) 17 Comprehensive Income Attributable to Member $ 457 $ 464 $ 462 The accompanying Notes to Condensed Unconsolidated Financial Statements are an integral part of the financial statements. SCHEDULE I - LG&E and KU Energy LLC CONDENSED UNCONSOLIDATED STATEMENTS OF CASH FLOWS FOR THE YEARS ENDED DECEMBER 31, (Millions of Dollars) 2020 2019 2018 Cash Flows from Operating Activities Net cash provided by (used in) operating activities $ 371 $ 368 $ 346 Cash Flows from Investing Activities Capital contributions to affiliated subsidiaries (231) (93) (128) Net decrease (increase) in notes receivable from affiliates 5 (44) (26) Net cash provided by (used in) investing activities (226) (137) (154) Cash Flows from Financing Activities Net increase (decrease) in notes payable with affiliates 613 14 110 Retirement of long-term debt (475) — — Contribution from member — 63 — Distribution to member (283) (308) (302) Net cash provided by (used in) financing activities (145) (231) (192) Net Increase (Decrease) in Cash and Cash Equivalents — — — Cash and Cash Equivalents at Beginning of Period — — — Cash and Cash Equivalents at End of Period $ — $ — $ — Supplemental disclosures of cash flow information: Cash Dividends Received from Subsidiaries $ 361 $ 411 $ 402 The accompanying Notes to Condensed Unconsolidated Financial Statements are an integral part of the financial statements. SCHEDULE I - LG&E and KU Energy LLC CONDENSED UNCONSOLIDATED BALANCE SHEETS AT DECEMBER 31, (Millions of Dollars) 2020 2019 Assets Current Assets Accounts receivable from affiliates $ 4 $ 3 Income taxes receivable 2 3 Notes receivable from affiliates 1,100 1,105 Total Current Assets 1,106 1,111 Investments Affiliated companies at equity 5,944 5,577 Other Noncurrent Assets Deferred income taxes 276 314 Total Assets $ 7,326 $ 7,002 Liabilities and Equity Current Liabilities Notes payable to affiliates $ 251 $ 150 Long-term debt due within one year 250 475 Accounts payable to affiliates 499 489 Taxes 5 — Other current liabilities 2 6 Total Current Liabilities 1,007 1,120 Long-term Debt Long-term debt — 249 Notes payable to affiliates 1,203 691 Total Long-term Debt 1,203 940 Deferred Credits and Other Noncurrent Liabilities — — Equity 5,116 4,942 Total Liabilities and Equity $ 7,326 $ 7,002 The accompanying Notes to Condensed Unconsolidated Financial Statements are an integral part of the financial statements. Schedule I - LG&E and KU Energy LLC Notes to Condensed Unconsolidated Financial Statements 1. Basis of Presentation LG&E and KU Energy LLC (LKE) is a holding company and conducts substantially all of its business operations through its subsidiaries. Substantially all of its consolidated assets are held by such subsidiaries. LKE uses the equity method to account for its investments in entities in which it has a controlling financial interest. LKE's cash flow and its ability to meet its obligations are largely dependent upon the earnings of these subsidiaries and the distribution or other payment of such earnings to it in the form of dividends or repayment of loans and advances from the subsidiaries. These condensed financial statements and related footnotes have been prepared in accordance with Reg. §210.12-04 of Regulation S-X. These statements should be read in conjunction with the consolidated financial statements and notes thereto of LKE. LKE indirectly or directly owns all of the ownership interests of its significant subsidiaries. LKE relies primarily on dividends from its subsidiaries to fund LKE's distributions to its member and to meet its other cash requirements. See Note 8 to LKE's consolidated financial statements for discussions related to restricted net assets of its subsidiaries for the purposes of transferring funds to LKE in the form of distributions, loans or advances. 2. Commitments and Contingencies See Note 14 to LKE's consolidated financial statements for commitments and contingencies of its subsidiaries. Guarantees LKE provides certain indemnifications covering the due and punctual payment, performance and discharge by each party of its respective obligations. The most comprehensive of these guarantees is the LKE guarantee covering operational, regulatory and environmental commitments and indemnifications made by WKE under a 2009 Transaction Termination Agreement. This guarantee has a term of 12 years ending July 2021, and a maximum exposure of $200 million, exclusive of certain items such as government fines and penalties that may exceed the maximum. Additionally, LKE has indemnified various third parties related to historical obligations for other divested subsidiaries and affiliates. The indemnifications vary by entity and the maximum exposures range from being capped at the sale price to no specified maximum. LKE could be required to perform on these indemnifications in the event of covered losses or liabilities being claimed by an indemnified party. LKE cannot predict the ultimate outcomes of the various indemnification scenarios, but does not expect such outcomes to result in significant losses above the amounts recorded. 3. Long-Term Debt

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2020
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 distribution of electricity in the U.K.; 2) the generation, transmission, distribution and sale of electricity and the distribution and sale of natural gas, primarily in Kentucky; and 3) the transmission, distribution and sale of electricity in Pennsylvania. Headquartered in Allentown, PA, PPL's principal subsidiaries are PPL Global, LKE (including its principal subsidiaries, LG&E and KU) and PPL Electric. PPL's corporate level financing subsidiary is PPL Capital Funding. WPD, a subsidiary of PPL Global, through wholly owned subsidiaries, operates distribution networks providing electricity service in the U.K. WPD serves end-users in South Wales and southwest and central England. Its principal subsidiaries are WPD (South Wales), WPD (South West), WPD (East Midlands) and WPD (West Midlands). PPL consolidates WPD on a one-month lag. Material events, such as debt issuances that occur in the lag period, are recognized in the current period financial statements. Events that are significant but not material are disclosed. (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, LKE, LG&E and KU) LKE is a utility holding company with cost-based rate-regulated utility operations through its subsidiaries, 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. 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. All significant intercompany transactions have been eliminated. The financial statements of PPL, LKE, 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 (PPL) WPD operates in an incentive-based regulatory structure under distribution licenses granted by Ofgem. Electricity distribution revenues are set by Ofgem for a given time period through price control reviews that are not directly based on cost recovery. The price control formula that governs WPD's allowed revenue is designed to provide economic incentives to minimize operating, capital and financing costs. As a result, WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP and does not record regulatory assets and liabilities. (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, primarily associated with PPL's investments in U.K. subsidiaries. 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 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 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. These transactions generally include foreign currency forwards and options to hedge GBP-denominated earnings translation risk associated with PPL's U.K. subsidiaries that report their financial statements in GBP. As such, these transactions reduce earnings volatility due solely to changes in foreign currency exchange rates. PPL also hedges anticipated transactions, including the previously announced potential 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 LKE, LG&E and KU, unbilled revenues for a month are calculated by multiplying an estimate of unbilled kWh by the estimated average cents per kWh. 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. (PPL) WPD is currently operating under the eight-year price control period of RIIO-ED1, which commenced for electric distribution companies on April 1, 2015. Ofgem has adopted a price control mechanism that establishes the amount of base demand revenue WPD can earn, subject to certain true-ups, and provides for increased or reduced revenues based on incentives or penalties for performance relative to pre-established targets. WPD's allowed revenue primarily includes base demand revenue (adjusted for inflation using RPI), performance incentive revenues/penalties and adjustments for over or under-recovery from prior periods. As the regulatory model is incentive based rather than a cost recovery model, WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP. Therefore, the accounting treatment of adjustments to base demand revenue and/or allowed revenue is evaluated based on revenue recognition accounting guidance. Unlike prior price control reviews, base demand revenue under RIIO-ED1 is adjusted during the price control period. The most significant of those adjustments are: • Inflation True-Up - The base demand revenue for the RIIO-ED1 period was set based on 2012/13 prices. Therefore, an inflation factor as determined by forecasted RPI, provided by HM Treasury, is applied to base demand revenue. Forecasted RPI is trued up to actuals and affects future base demand revenue two • Annual Iteration Process (AIP) - The RIIO-ED1 price control period also includes an AIP. This allows future base demand revenues agreed with Ofgem as part of the price control review, to be updated during the price control period for financial adjustments including tax, pensions, cost of debt, legacy price control adjustments from preceding price control periods and adjustments relating to actual and allowed total expenditure, together with the Totex Incentive Mechanism (TIM). Under the TIM, WPD's DNOs are able to retain 70% of any amounts not spent against the RIIO-ED1 plan and bear 70% of any over-spends. The AIP calculates an incremental change to base demand revenue, known as the "MOD" adjustment. As both MOD and TRU are changes to future base demand revenues as determined by Ofgem, these adjustments are recognized as a component of revenues in future years in which service is provided and revenues are collected or returned to customers. In addition to base demand revenue, certain other items are added or subtracted to arrive at allowed revenue. The most significant of these are: • Incentives - Ofgem has established incentives to provide opportunities for DNO's to enhance overall returns by improving network efficiency, reliability and customer service. These incentives can result in an increase or reduction in revenues based on incentives or penalties for actual performance against pre-established targets based on past performance. The annual incentives and penalties are reflected in customers' rates on a two • Correction Factor - During the current price control period, WPD sets its tariffs to recover allowed revenue. However, in any fiscal period, WPD's revenue could be negatively affected if its tariffs and the volume delivered do not fully recover the revenue allowed for a particular period. Conversely, WPD could also over-recover revenue. Over and under-recoveries are subtracted from or added to allowed revenue in future years when billed to customers, known as the "Correction Factor" or "K-factor." Over and under-recovered amounts arising for the period are refunded/recovered on a two
Accounts Receivable	Financing 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. Current Expected Credit Losses Financing receivable collectibility is evaluated using 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, LKE, LG&E and KU) LKE, 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.
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 and PPL Electric) 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 (All Registrants) 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. Short-term Investments 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) 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
Goodwill and Other Intangible Assets	(All Registrants) Goodwill and Other Intangible Assets 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) 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, LKE, 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, LKE's, LG&E's and KU's reporting units are primarily at the operating segment level. PPL, LKE, 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 first quarter of 2020, PPL, LKE, LG&E and KU considered whether the economic events associated with COVID-19, which resulted in PPL's shares experiencing volatility and a decrease in market value, would more likely than not reduce the fair value of the Registrants’ reporting units below their carrying amounts. Based on the assessment, a quantitative impairment test was not required for the LKE, LG&E and KU reporting units, but was required for the U.K. Regulated segment reporting unit, the allocated goodwill of which was $2.5 billion at March 31, 2020. The test did not indicate impairment of the reporting unit. In the fourth quarter of 2020, PPL (for its U.K. Regulated and Kentucky Regulated segments), and individually, LKE, LG&E and KU elected to perform qualitative step zero evaluations for their annual goodwill impairment tests, as of October 1, 2020. 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.
Asset Retirement Obligations	( PPL, LKE, 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 LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, at the time of retirement, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability. 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, PPL Electric and LKE) 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-
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, valuation allowances on deferred tax assets and whether the undistributed earnings of WPD are considered indefinitely reinvested. 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, 2020, 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 for additional discussion regarding income taxes, including the impact of the TCJA and management's conclusion that the undistributed earnings of WPD are considered indefinitely reinvested. The provision for PPL's, PPL Electric's, LKE's, LG&E's and KU's 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" and PPL presents value-added taxes in "Taxes" on the Balance Sheets. These taxes are not reflected on the Statements of Income. See Note 6 for details on 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 (All Registrants) 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
Treasury Stock	Treasury Stock (PPL) PPL restores all shares of common stock acquired to authorized but unissued shares of common stock upon acquisition.
Foreign Currency Translation and Transactions	Foreign Currency Translation and Transactions (PPL) WPD's functional currency is the GBP, which is the local currency in the U.K. As such, assets and liabilities are translated to U.S. dollars at the exchange rates on the date of consolidation and related revenues and expenses are generally translated at average exchange rates prevailing during the period included in PPL's results of operations. Adjustments resulting from foreign currency translation are recorded in AOCI. Gains or losses relating to foreign currency transactions are recognized in "Other Income (Expense) - net" on the Statements of Income. See Note 16 for additional information.
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
Cash	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."
Property, Plant and Equipment	(PPL Electric)PPL Electric capitalizes interest costs as part of construction costs.
Compensation and Benefits	Stock-Based Compensation (PPL, PPL Electric and LKE) 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-
Income Taxes	(PPL Electric, LKE, 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.
LG And E And KU Energy LLC [Member]
Summary of Significant Accounting Policies [Line Items]
Business and Consolidation	LKE is a utility holding company with cost-based rate-regulated utility operations through its subsidiaries, 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.
Accounts Receivable	(PPL, LKE, LG&E and KU) LKE, 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, LKE, 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 LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, at the time of retirement, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability. 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	Stock-Based Compensation (PPL, PPL Electric and LKE) 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-
Income Taxes	(PPL Electric, LKE, 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	LKE is a utility holding company with cost-based rate-regulated utility operations through its subsidiaries, 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.
Accounts Receivable	(PPL, LKE, LG&E and KU) LKE, 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, LKE, 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 LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, at the time of retirement, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability. 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, LKE, 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	LKE is a utility holding company with cost-based rate-regulated utility operations through its subsidiaries, 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.
Accounts Receivable	(PPL, LKE, LG&E and KU) LKE, 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, LKE, 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 LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, at the time of retirement, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability. 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, LKE, 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, 2020
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, 2020
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, primarily associated with PPL's investments in U.K. subsidiaries. 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 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 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. These transactions generally include foreign currency forwards and options to hedge GBP-denominated earnings translation risk associated with PPL's U.K. subsidiaries that report their financial statements in GBP. As such, these transactions reduce earnings volatility due solely to changes in foreign currency exchange rates. PPL also hedges anticipated transactions, including the previously announced potential 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.
LG And E And KU Energy LLC [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.
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, 2020
Summary of Significant Accounting Policies [Line Items]
Weighted-average Rates of Depreciation	Following are the weighted-average annual rates of depreciation, for regulated utility plant, for the years ended December 31: 2020 2019 2018 PPL 2.81 % 2.84 % 2.77 % PPL Electric 2.99 % 3.05 % 3.01 % LKE 4.00 % 3.96 % 3.69 % LG&E 4.00 % 3.87 % 3.63 % KU 4.00 % 4.02 % 3.74 %
Schedule of Utility Inventory	"Fuel, materials and supplies" on the Balance Sheets consisted of the following at December 31: 2020 PPL PPL Electric LKE LG&E KU Fuel $ 95 $ — $ 95 $ 38 $ 57 Natural gas stored underground 30 — 30 30 — Materials and supplies 236 59 117 51 66 Total $ 361 $ 59 $ 242 $ 119 $ 123 2019 PPL PPL Electric LKE LG&E KU Fuel $ 106 $ — $ 106 $ 43 $ 63 Natural gas stored underground 35 — 35 35 — Materials and supplies 191 33 109 44 65 Total $ 332 $ 33 $ 250 $ 122 $ 128
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: PPL PPL Electric December 31, December 31, December 31, December 31, Cash and cash equivalents $ 708 $ 815 $ 40 $ 262 Restricted cash - current 1 3 — 2 Restricted cash - noncurrent (a) 18 18 — — Total Cash, Cash Equivalents and Restricted Cash $ 727 $ 836 $ 40 $ 264 (a) 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. On the Balance Sheets, the current portion of restricted cash is included in "Other current assets," while the noncurrent portion is included in "Other noncurrent assets."
Accounts Receivable, Allowance for Credit Loss	The changes in the allowance for doubtful accounts are included in the following table. Amounts relate to “accounts receivable-customer” except as noted. Additions Balance at Charged to Income Charged to Other Accounts Deductions (b) Balance at PPL 2020 (a) $ 60 (a) $ 31 $ — $ 16 $ 75 (c) (d) 2019 56 37 3 38 58 2018 51 41 3 39 56 PPL Electric 2020 $ 30 (a) $ 19 $ — $ 8 $ 41 (c) 2019 27 26 — 25 28 2018 24 29 — 26 27 LKE 2020 $ 28 $ 9 $ — $ 5 $ 32 (d) 2019 27 8 3 10 28 2018 25 10 3 11 27 LG&E 2020 $ 1 $ 4 $ — $ 2 $ 3 2019 1 2 2 4 1 2018 1 4 1 5 1 KU 2020 $ 1 $ 4 $ — $ 3 $ 2 2019 2 4 1 6 1 2018 1 5 2 6 2 (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 receivables.
PPL Electric Utilities Corp [Member]
Summary of Significant Accounting Policies [Line Items]
Intercompany tax receivables (payables)	At December 31, the following intercompany tax receivables (payables) were recorded: 2020 2019 PPL Electric $ (9) $ 3 LKE (12) (8) LG&E (1) (4) KU (5) (6)
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: PPL PPL Electric December 31, December 31, December 31, December 31, Cash and cash equivalents $ 708 $ 815 $ 40 $ 262 Restricted cash - current 1 3 — 2 Restricted cash - noncurrent (a) 18 18 — — Total Cash, Cash Equivalents and Restricted Cash $ 727 $ 836 $ 40 $ 264 (a) 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. On the Balance Sheets, the current portion of restricted cash is included in "Other current assets," while the noncurrent portion is included in "Other noncurrent assets."
LG And E And KU Energy LLC [Member]
Summary of Significant Accounting Policies [Line Items]
Intercompany tax receivables (payables)	At December 31, the following intercompany tax receivables (payables) were recorded: 2020 2019 PPL Electric $ (9) $ 3 LKE (12) (8) LG&E (1) (4) KU (5) (6)
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: 2020 2019 PPL Electric $ (9) $ 3 LKE (12) (8) LG&E (1) (4) KU (5) (6)
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: 2020 2019 PPL Electric $ (9) $ 3 LKE (12) (8) LG&E (1) (4) KU (5) (6)

Segment and Related Informati_2

Segment and Related Information (Tables)	12 Months Ended
	Dec. 31, 2020
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: 2020 2019 2018 Operating Revenues from external customers (a) U.K. Regulated $ 2,133 $ 2,167 $ 2,268 Kentucky Regulated 3,106 3,206 3,214 Pennsylvania Regulated 2,330 2,358 2,277 Corporate and Other 38 38 26 Total $ 7,607 $ 7,769 $ 7,785 Depreciation U.K. Regulated $ 265 $ 250 $ 247 Kentucky Regulated 606 547 475 Pennsylvania Regulated 403 386 352 Corporate and Other 13 16 20 Total $ 1,287 $ 1,199 $ 1,094 Amortization (b) U.K. Regulated $ 16 $ 25 $ 34 Kentucky Regulated 19 27 18 Pennsylvania Regulated 26 24 22 Corporate and Other 11 5 4 Total $ 72 $ 81 $ 78 Unrealized (gains) losses on derivatives and other hedging activities (c) U.K. Regulated $ 271 $ 62 $ (190) Kentucky Regulated 5 6 6 Corporate and Other 4 5 (2) Total $ 280 $ 73 $ (186) Interest Expense U.K. Regulated $ 400 $ 405 $ 413 Kentucky Regulated 300 298 274 Pennsylvania Regulated 172 169 159 Corporate and Other 129 122 117 Total $ 1,001 $ 994 $ 963 Income Before Income Taxes U.K. Regulated $ 958 $ 1,169 $ 1,339 Kentucky Regulated 516 530 531 Pennsylvania Regulated 664 607 567 Corporate and Other (167) (151) (152) Total $ 1,971 $ 2,155 $ 2,285 2020 2019 2018 Income Taxes (d) U.K. Regulated $ 272 $ 192 $ 225 Kentucky Regulated 98 94 120 Pennsylvania Regulated 167 149 136 Corporate and Other (35) (26) (23) Total $ 502 $ 409 $ 458 Deferred income taxes and investment tax credits (e) U.K. Regulated $ 233 $ 140 $ 118 Kentucky Regulated 64 82 94 Pennsylvania Regulated 82 90 125 Corporate and Other 23 (3) 18 Total $ 402 $ 309 $ 355 Net Income U.K. Regulated $ 686 $ 977 $ 1,114 Kentucky Regulated 418 436 411 Pennsylvania Regulated 497 458 431 Corporate and Other (132) (125) (129) Total $ 1,469 $ 1,746 $ 1,827 (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, debt discounts and premiums and debt issuance costs. (c) Includes unrealized gains and losses from economic activity. See Note 18 for additional information. (d) Represents both current and deferred income taxes, including investment tax credits. See Note 6 for additional information on the impact of the TCJA in 2018. (e) 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: 2020 2019 2018 Expenditures for long-lived assets U.K. Regulated $ 995 $ 857 $ 954 Kentucky Regulated 966 1,097 1,117 Pennsylvania Regulated 1,154 1,121 1,196 Corporate and Other 158 32 1 Total $ 3,273 $ 3,107 $ 3,268 The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated results as of: As of December 31, 2020 2019 Total Assets U.K. Regulated (a) $ 19,094 $ 17,622 Kentucky Regulated 15,943 15,597 Pennsylvania Regulated 12,347 11,918 Corporate and Other (b) 732 543 Total $ 48,116 $ 45,680 (a) Includes $14.4 billion and $13.2 billion of net PP&E as of December 31, 2020 and December 31, 2019. WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP. (b) Primarily consists of unallocated items, including cash, PP&E, goodwill, the elimination of inter-segment transactions as well as the assets of Safari Energy.
Geographic Data	Geographic data for the years ended December 31 are as follows: 2020 2019 2018 Revenues from external customers U.K. $ 2,133 $ 2,167 $ 2,268 U.S. 5,474 5,602 5,517 Total $ 7,607 $ 7,769 $ 7,785
Long-lived Assets	Geographic data for the years ended December 31 are as follows: As of December 31, 2020 2019 Long-Lived Assets U.K. $ 14,805 $ 13,618 U.S. 24,851 23,607 Total $ 39,656 $ 37,225

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	12 Months Ended
	Dec. 31, 2020
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: 2020 PPL PPL Electric LKE LG&E KU Operating Revenues (a) $ 7,607 $ 2,331 $ 3,106 $ 1,456 $ 1,690 Revenues derived from: Alternative revenue programs (b) (24) (12) (12) (8) (4) Other (c) (27) (3) (17) (7) (10) Revenues from Contracts with Customers $ 7,556 $ 2,316 $ 3,077 $ 1,441 $ 1,676 2019 PPL PPL Electric LKE LG&E KU Operating Revenues (a) $ 7,769 $ 2,358 $ 3,206 $ 1,500 $ 1,740 Revenues derived from: Alternative revenue programs (b) (30) (6) (24) (10) (14) Other (c) (38) (10) (21) (9) (12) Revenues from Contracts with Customers $ 7,701 $ 2,342 $ 3,161 $ 1,481 $ 1,714 2018 PPL PPL Electric LKE LG&E KU Operating Revenues (a) $ 7,785 $ 2,277 $ 3,214 $ 1,496 $ 1,760 Revenues derived from: Alternative revenue programs (b) 32 (6) 38 12 26 Other (c) (38) (12) (17) (5) (12) Revenues from Contracts with Customers $ 7,779 $ 2,259 $ 3,235 $ 1,503 $ 1,774 (a) For the years ended December 31, 2020 and 2019, PPL includes $2.1 billion and $2.2 billion of revenues from external customers reported by the U.K. Regulated segment. PPL Electric and LKE represent revenues from external customers reported by the Pennsylvania Regulated and Kentucky Regulated segments. 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 program for LG&E, and the generation formula rate for KU. 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: 2020 PPL (d) PPL Electric (d) LKE LG&E KU Licensed energy suppliers (a) $ 1,990 $ — $ — $ — $ — Residential 2,585 1,238 1,347 676 671 Commercial 1,185 314 871 444 427 Industrial 582 44 538 173 365 Other (b) 484 50 261 114 147 Wholesale - municipal 20 — 20 — 20 Wholesale - other (c) 40 — 40 34 46 Transmission 670 670 — — — Revenues from Contracts with Customers $ 7,556 $ 2,316 $ 3,077 $ 1,441 $ 1,676 2019 PPL (d) PPL Electric (d) LKE LG&E KU Licensed energy suppliers (a) $ 2,032 $ — $ — $ — $ — Residential 2,610 1,288 1,322 668 654 Commercial 1,257 349 908 466 442 Industrial 621 59 562 180 382 Other (b) 495 52 277 121 156 Wholesale - municipal 43 — 43 — 43 Wholesale - other (c) 49 — 49 46 37 Transmission 594 594 — — — Revenues from Contracts with Customers $ 7,701 $ 2,342 $ 3,161 $ 1,481 $ 1,714 2018 PPL PPL Electric LKE LG&E KU Licensed energy suppliers (a) $ 2,127 $ — $ — $ — $ — Residential 2,704 1,379 1,325 666 659 Commercial 1,233 368 865 455 410 Industrial 624 54 570 180 390 Other (b) 489 53 278 129 149 Wholesale - municipal 118 — 118 — 118 Wholesale - other (c) 79 — 79 73 48 Transmission 405 405 — — — Revenues from Contracts with Customers $ 7,779 $ 2,259 $ 3,235 $ 1,503 $ 1,774 (a) Represents customers of WPD. (b) Primarily includes revenues from pole attachments, street lighting, other public authorities and other non-core businesses. (c) Includes wholesale power and transmission revenues. LG&E and KU amounts include intercompany power sales and transmission revenues, which are eliminated upon consolidation at LKE. (d) In 2020 and 2019, management deemed it appropriate to present the revenue offset associated with network integration transmission service (NITS) as distribution revenue rather than transmission revenue.
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: 2020 2019 2018 PPL $ 29 $ 27 $ 34 PPL Electric 17 21 24 LKE 8 6 9 LG&E 4 2 4 KU 4 4 5
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 LKE LG&E KU Contract liabilities as of December 31, 2020 $ 48 $ 23 $ 11 $ 5 $ 6 Contract liabilities as of December 31, 2019 44 21 9 5 4 Revenue recognized during the year ended December 31, 2020 that was included in the contract liability balance at December 31, 2019 29 9 9 5 4 Contract liabilities as of December 31, 2019 $ 44 $ 21 $ 9 $ 5 $ 4 Contract liabilities as of December 31, 2018 42 23 9 5 4 Revenue recognized during the year ended December 31, 2019 that was included in the contract liability balance at December 31, 2018 32 11 9 5 4 Contract liabilities as of December 31, 2018 $ 42 $ 23 $ 9 $ 5 $ 4 Contract liabilities as of December 31, 2017 29 19 8 4 4 Revenue recognized during the year ended December 31, 2018 that was included in the contract liability balance at December 31, 2017 21 8 8 4 4

Income and Other Taxes (Tables)

Income and Other Taxes (Tables)	12 Months Ended
	Dec. 31, 2020
Income Taxes [Line Items]
Tax Reform	The final amounts reported in PPL's 2017 federal income tax return, provisional amounts for the year ended December 31, 2017, the related measurement period adjustments, and the resulting tax impact for the year ended December 31, 2018 were as follows. Taxable Income (Loss) (a) Adjustments per 2017 Tax Return Adjustments per 2017 Tax Provision 2018 Adjustments PPL Deemed Dividend $ 397 $ 462 $ (65) Bonus Depreciation (b) (67) — (67) Consolidated Federal Net Operating Loss due to the TCJA (c) (330) (462) 132 Total $ — $ — $ — PPL Electric Bonus Depreciation (b) $ (39) $ — $ (39) Consolidated Federal Net Operating Loss reallocated due to the TCJA (c) (68) (105) 37 Total $ (107) $ (105) $ (2) LKE Bonus Depreciation (b) $ (28) $ — $ (28) Consolidated Federal Net Operating Loss reallocated due to the TCJA (c) (32) (45) 13 Total $ (60) $ (45) $ (15) LG&E Bonus Depreciation (b) $ (17) $ — $ (17) Consolidated Federal Net Operating Loss reallocated due to the TCJA (c) 17 — 17 Total $ — $ — $ — KU Bonus Depreciation (b) $ (11) $ — $ (11) Consolidated Federal Net Operating Loss reallocated due to the TCJA (c) 11 — 11 Total $ — $ — $ — (a) The above table reflects, for each item, the amount subject to change as a result of the TCJA and does not reflect the total amount of each item included in the return and the provision. (b) The TCJA increased the bonus depreciation percentage from 50% to 100% for qualified property acquired and placed in service after September 27, 2017 and before January 1, 2018. Increases in tax depreciation reduce the Registrants' taxes payable and increase net deferred tax liabilities with no impact to “Income Taxes” on the Statements of Income. (c) An increase in the consolidated federal net operating loss reduces net deferred tax liabilities with the opposite effect if there is a decrease in the consolidated federal net operating loss. These increases or decreases have no impact to “Income Taxes” on the Statements of Income. Income Tax Expense (Benefit) Adjustments per 2017 Tax Return Adjustments per 2017 Tax Provision 2018 Adjustments PPL Deemed Dividend $ 139 $ 161 $ (22) Foreign Tax Credits (157) (205) 48 Valuation of Foreign Tax Credit Carryforward 110 145 (35) Reduction in U.S. federal income tax rate 229 220 9 Total $ 321 $ 321 $ — PPL Electric Reduction in U.S. federal income tax rate $ (13) $ (13) $ — LKE Reduction in U.S. federal income tax rate $ 110 $ 112 $ (2)
Components of Income (Loss) Before Income Taxes	"Income Before Income Taxes" included the following: 2020 2019 2018 Domestic income $ 902 $ 964 $ 1,127 Foreign income 1,069 1,191 1,158 Total $ 1,971 $ 2,155 $ 2,285
Components of Deferred Tax Assets and Liabilities	Significant components of PPL's deferred income tax assets and liabilities were as follows: 2020 2019 Deferred Tax Assets Deferred investment tax credits $ 30 $ 31 Regulatory liabilities 68 75 Income taxes due to customers 444 462 Accrued pension and postretirement costs 106 211 Federal loss carryforwards 234 324 State loss carryforwards 448 432 Federal and state tax credit carryforwards 401 402 Foreign capital loss carryforwards 370 320 Foreign - other 6 8 Contributions in aid of construction 115 112 Domestic - other 136 99 Valuation allowances (906) (834) Total deferred tax assets 1,452 1,642 Deferred Tax Liabilities Domestic plant - net 3,700 3,546 Regulatory assets 195 262 Foreign plant - net 911 765 Foreign - pensions 127 72 Domestic - other 70 61 Total deferred tax liabilities 5,003 4,706 Net deferred tax liability $ 3,551 $ 3,064
Summary of Operating Loss Carryforwards and Tax Credit Carryforwards	At December 31, 2020, 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 Federal net operating losses $ 1,111 $ 234 $ — 2035-2037 State net operating losses 6,032 448 (419) 2021-2040 Foreign capital losses (a) 1,945 370 (370) Indefinite Federal - Other 13 2 — Indefinite State - Other 2 — — Indefinite Credit carryforwards Federal investment tax credit 134 — 2025-2040 Federal foreign tax credits (b) 218 (113) 2024-2027 Federal - other 32 (4) 2021-2040 State Recycling Credit 16 — 2028 State - other 1 — Indefinite (a) 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.
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 2020 $ 834 $ 69 (a) $ 7 $ 4 $ 906 2019 808 31 — 5 834 2018 838 26 — 56 (b) 808 (a) The cancellation of the reduction of the U.K. statutory income tax rate in 2020 resulted in a $38 million increase in deferred tax assets and corresponding valuation allowances. See "Reconciliation of Income Tax Expense" below for additional information on the impact of the U.K. Finance Act 2020. In addition, deferred tax assets and corresponding valuation allowances were increased in 2020 by approximately $11 million due to the effect of foreign currency exchange rates.
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: 2020 2019 2018 Income Tax Expense (Benefit) Current - Federal $ (9) $ (10) $ (19) Current - State 24 19 17 Current - Foreign 85 91 104 Total Current Expense (Benefit) 100 100 102 Deferred - Federal 123 139 203 Deferred - State 94 76 100 Deferred - Foreign (a) 215 123 107 Total Deferred Expense (Benefit), excluding operating loss carryforwards 432 338 410 Amortization of investment tax credit (3) (3) (3) Tax expense (benefit) of operating loss carryforwards Deferred - Federal 6 7 (20) Deferred - State (33) (33) (31) Total Tax Expense (Benefit) of Operating Loss Carryforwards (27) (26) (51) Total income tax expense (benefit) $ 502 $ 409 $ 458 Total income tax expense (benefit) - Federal $ 117 $ 133 $ 161 Total income tax expense (benefit) - State 85 62 86 Total income tax expense (benefit) - Foreign 300 214 211 Total income tax expense (benefit) $ 502 $ 409 $ 458 (a) 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: 2020 2019 2018 Other comprehensive income $ (19) $ (93) $ (6) Total $ (19) $ (93) $ (6)
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: 2020 2019 2018 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 414 $ 453 $ 480 Increase (decrease) due to: State income taxes, net of federal income tax benefit 48 45 40 Valuation allowance adjustments (a) 26 22 21 Impact of lower U.K. income tax rates (26) (25) (25) U.S. income tax on foreign earnings - net of foreign tax credit 11 2 3 Federal and state income tax return adjustments (9) 1 — Impact of the U.K. Finance Acts on deferred tax balances (b) 101 (14) (13) Depreciation and other items not normalized (5) (10) (11) Amortization of excess deferred federal and state income taxes (43) (40) (37) Interest benefit on U.K. financing activities (12) (12) (17) Deferred tax impact of Kentucky tax reform (c) — — 9 Kentucky recycling credit, net of federal income tax expense (d) — (18) — Other (3) 5 8 Total increase (decrease) 88 (44) (22) Total income tax expense (benefit) $ 502 $ 409 $ 458 Effective income tax rate 25.5% 19.0% 20.0% (a) In 2020, 2019 and 2018, PPL recorded deferred income tax expense of $24 million, $25 million and $24 million for valuation allowances primarily related to increased Pennsylvania net operating loss carryforwards expected to be unutilized. (b) In 2018 and 2019, PPL reduced its net deferred tax liabilities as a result of the U.K. Finance Act 2016 that was enacted in September 2016 and reduced the U.K. statutory income tax rate effective April, 2020 to 17%. In 2020, the U.K. Finance Act 2020 cancelled the tax rate reduction 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. (c) In 2018, PPL recorded deferred income tax expense, primarily associated with LKE’s non-regulated entities, due to the Kentucky corporate income tax rate reduction from 6% to 5%, as enacted by HB 487, effective January 1, 2018.
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: 2020 2019 2018 Taxes, other than income State gross receipts $ 100 $ 107 $ 103 Foreign property 127 127 134 Domestic - other 80 79 75 Total $ 307 $ 313 $ 312
Summary of Income Tax Examinations	With few exceptions, at December 31, 2020, these jurisdictions, as well as the tax years that are no longer subject to examination, were as follows. PPL PPL Electric LKE LG&E KU U.S. (federal) 2016 and prior 2016 and prior 2016 and prior 2016 and prior 2016 and prior Pennsylvania (state) 2016 and prior 2016 and prior Kentucky (state) 2014 and prior 2014 and prior 2014 and prior 2014 and prior U.K. (foreign) 2016 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: 2020 2019 Deferred Tax Assets Accrued pension and postretirement costs $ 25 $ 81 Contributions in aid of construction 91 88 Regulatory liabilities 24 31 Income taxes due to customers 162 170 State loss carryforwards — 6 Federal loss carryforwards 52 78 Other 29 23 Total deferred tax assets 383 477 Deferred Tax Liabilities Electric utility plant - net 1,826 1,761 Regulatory assets 86 139 Other 30 24 Total deferred tax liabilities 1,942 1,924 Net deferred tax liability $ 1,559 $ 1,447
Summary of Operating Loss Carryforwards and Tax Credit Carryforwards	At December 31, 2020, PPL Electric had the following loss and tax credit carryforwards and related deferred tax assets: Gross Deferred Tax Asset Expiration Loss carryforwards Federal net operating losses $ 248 $ 52 2035-2037 Credit carryforwards Federal - other 5 2031-2040
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: 2020 2019 2018 Income Tax Expense (Benefit) Current - Federal $ 61 $ 44 $ 2 Current - State 23 15 9 Total Current Expense (Benefit) 84 59 11 Deferred - Federal 45 51 96 Deferred - State 38 39 37 Total Deferred Expense (Benefit), excluding operating loss carryforwards 83 90 133 Tax expense (benefit) of operating loss carryforwards Deferred - Federal — — (8) Total Tax Expense (Benefit) of Operating Loss Carryforwards — — (8) Total income tax expense (benefit) $ 167 $ 149 $ 136 Total income tax expense (benefit) - Federal $ 106 $ 95 $ 90 Total income tax expense (benefit) - State 61 54 46 Total income tax expense (benefit) $ 167 $ 149 $ 136
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: 2020 2019 2018 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 139 $ 127 $ 119 Increase (decrease) due to: State income taxes, net of federal income tax benefit 52 47 43 Federal and state income tax return adjustments (4) 1 — Depreciation and other items not normalized (5) (10) (11) Amortization of excess deferred federal income taxes (a) (16) (18) (17) Other 1 2 2 Total increase (decrease) 28 22 17 Total income tax expense (benefit) $ 167 $ 149 $ 136 Effective income tax rate 25.2% 24.6% 24.0% (a) In 2020, 2019 and 2018, 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: 2020 2019 2018 Taxes, other than income State gross receipts $ 100 $ 107 $ 103 Property and other 7 5 6 Total $ 107 $ 112 $ 109
LG And E And KU Energy LLC [Member]
Income Taxes [Line Items]
Components of Deferred Tax Assets and Liabilities	Significant components of LKE's deferred income tax assets and liabilities were as follows: 2020 2019 Deferred Tax Assets Federal loss carryforwards $ 107 $ 140 State loss carryforwards 28 31 Federal tax credit carryforwards 159 162 Contributions in aid of construction 23 23 Regulatory liabilities 43 44 Accrued pension and postretirement costs 57 71 State tax credit carryforwards 17 19 Income taxes due to customers 282 292 Deferred investment tax credits 30 31 Lease liabilities 13 14 Valuation allowances (4) (6) Other 29 28 Total deferred tax assets 784 849 Deferred Tax Liabilities Plant - net 1,831 1,778 Regulatory assets 109 122 Lease right-of-use assets 11 12 Other 8 6 Total deferred tax liabilities 1,959 1,918 Net deferred tax liability $ 1,175 $ 1,069
Summary of Operating Loss Carryforwards and Tax Credit Carryforwards	At December 31, 2020, LKE 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 carryforwards Federal net operating losses $ 511 $ 107 $ — 2035 - 2037 Federal charitable contributions 1 — — 2024 State net operating losses 710 28 — 2029 - 2038 Gross Deferred Tax Asset Valuation Allowance Expiration Credit carryforwards Federal investment tax credit 134 — 2025 - 2028, 2036 - 2040 Federal - other 25 (4) 2021-2040 State - recycling credit 16 — 2028 State - other 1 — Indefinite
Schedule of Valuation and Qualifying Accounts of Deferred Tax Assets	Changes in deferred tax valuation allowances were: Balance at Additions Deductions Balance 2020 $ 6 $ — $ 2 (a) $ 4 2019 8 3 5 (a) 6 2018 8 — — 8 (a) Tax credits expiring.
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: 2020 2019 2018 Income Tax Expense (Benefit) Current - Federal $ 41 $ 20 $ 31 Current - State 1 — 4 Total Current Expense (Benefit) 42 20 35 Deferred - Federal 43 81 65 Deferred - State (a) 24 5 34 Total Deferred Expense (Benefit), excluding benefits of operating loss carryforwards 67 86 99 Amortization of investment tax credit - Federal (3) (3) (3) Tax expense (benefit) of operating loss carryforwards Deferred - Federal — — (2) Total Tax Expense (Benefit) of Operating Loss Carryforwards — — (2) Total income tax expense (benefit) (b) $ 106 $ 103 $ 129 Total income tax expense (benefit) - Federal $ 81 $ 98 $ 91 Total income tax expense (benefit) - State 25 5 38 Total income tax expense (benefit) (b) $ 106 $ 103 $ 129 (a) In 2019, LKE 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.
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: 2020 2019 2018 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 117 $ 120 $ 121 Increase (decrease) due to: State income taxes, net of federal income tax benefit 22 23 22 Amortization of investment tax credit (3) (3) (3) Amortization of excess deferred federal and state income taxes (28) (23) (20) Deferred tax impact of state tax reform (a) — — 9 Kentucky Recycling Credit, net of federal income tax expense (b) — (18) — Other (2) 4 — Total increase (decrease) (11) (17) 8 Total income tax expense (benefit) $ 106 $ 103 $ 129 Effective income tax rate 19.1% 18.0% 22.5% (a) In 2018, LKE recorded deferred income tax expense, primarily associated with LKE's non-regulated entities, due to the Kentucky corporate income tax rate reduction from 6% to 5%, as enacted by HB 487, effective January 1, 2018.
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: 2020 2019 2018 Taxes, other than income Property and other $ 77 $ 74 $ 70 Total $ 77 $ 74 $ 70
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: 2020 2019 Deferred Tax Assets Contributions in aid of construction $ 15 $ 15 Regulatory liabilities 20 19 Accrued pension and postretirement costs — 6 Deferred investment tax credits 8 8 Income taxes due to customers 132 136 State tax credit carryforwards 12 14 Lease liabilities 5 5 Valuation allowances (12) (14) Other 11 10 Total deferred tax assets 191 199 Deferred Tax Liabilities Plant - net 833 811 Regulatory assets 66 77 Lease right-of-use assets 4 4 Other 4 4 Total deferred tax liabilities 907 896 Net deferred tax liability $ 716 $ 697
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: 2020 2019 2018 Income Tax Expense (Benefit) Current - Federal $ 53 $ 4 $ — Current - State 7 4 4 Total Current Expense (Benefit) 60 8 4 Deferred - Federal (4) 46 51 Deferred - State 7 10 10 Total Deferred Expense (Benefit) 3 56 61 Amortization of investment tax credit - Federal (1) (1) (1) Total income tax expense (benefit) $ 62 $ 63 $ 64 Total income tax expense (benefit) - Federal $ 48 $ 49 $ 50 Total income tax expense (benefit) - State 14 14 14 Total income tax expense (benefit) $ 62 $ 63 $ 64
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: 2020 2019 2018 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 64 $ 62 $ 62 Increase (decrease) due to: State income taxes, net of federal income tax benefit 12 12 11 Amortization of excess deferred federal and state income taxes (11) (10) (8) Kentucky recycling credit, net of federal income tax expense (a) — (14) — Valuation allowance adjustments (a) — 14 — Other (3) (1) (1) Total increase (decrease) (2) 1 2 Total income tax expense (benefit) $ 62 $ 63 $ 64 Effective income tax rate 20.3% 21.4% 21.5%
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: 2020 2019 2018 Taxes, other than income Property and other $ 40 $ 39 $ 36 Total $ 40 $ 39 $ 36
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: 2020 2019 Deferred Tax Assets Contributions in aid of construction $ 8 $ 8 Regulatory liabilities 23 25 Deferred investment tax credits 22 23 Income taxes due to customers 150 156 State tax credit carryforwards 5 5 Lease liabilities 8 8 Valuation allowances (4) (4) Other 4 3 Total deferred tax assets 216 224 Deferred Tax Liabilities Plant - net 992 959 Regulatory assets 43 45 Accrued pension and postretirement costs 8 2 Lease right-of-use assets 7 7 Other 1 3 Total deferred tax liabilities 1,051 1,016 Net deferred tax liability $ 835 $ 792
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: 2020 2019 2018 Income Tax Expense (Benefit) Current - Federal $ 40 $ 35 $ 22 Current - State 3 5 6 Total Current Expense (Benefit) 43 40 28 Deferred - Federal 11 28 40 Deferred - State 11 13 10 Total Deferred Expense (Benefit) 22 41 50 Amortization of investment tax credit - Federal (2) (2) (2) Total income tax expense (benefit) $ 63 $ 79 $ 76 Total income tax expense (benefit) - Federal $ 49 $ 61 $ 60 Total income tax expense (benefit) - State 14 18 16 Total income tax expense (benefit) $ 63 $ 79 $ 76
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: 2020 2019 2018 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 72 $ 78 $ 76 Increase (decrease) due to: State income taxes, net of federal income tax benefit 14 15 13 Amortization of investment tax credit (2) (2) (2) Amortization of excess deferred federal and state income taxes (17) (13) (12) Kentucky recycling credit, net of federal income tax expense (a) — (4) — Valuation allowance adjustments (a) — 4 — Other (4) 1 1 Total increase (decrease) (9) 1 — Total income tax expense (benefit) $ 63 $ 79 $ 76 Effective income tax rate 18.4% 21.2% 21.0%
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: 2020 2019 2018 Taxes, other than income Property and other $ 37 $ 35 $ 34 Total $ 37 $ 35 $ 34

Utility Rate Regulation (Tables

Utility Rate Regulation (Tables)	12 Months Ended
	Dec. 31, 2020
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 2020 2019 2020 2019 Current Regulatory Assets: Plant outage costs $ 46 $ 32 $ — $ — Gas supply clause 4 8 — — Smart meter rider 17 13 17 13 Storm costs 7 — 7 — Transmission formula rate 15 3 15 3 Transmission service charge — 10 — 10 Other 10 1 1 — Total current regulatory assets (a) $ 99 $ 67 $ 40 $ 26 Noncurrent Regulatory Assets: Defined benefit plans $ 570 $ 800 $ 290 $ 467 Storm costs 17 39 — 15 Unamortized loss on debt 30 41 8 18 Interest rate swaps 23 22 — — Terminated interest rate swaps 75 81 — — Accumulated cost of removal of utility plant 240 220 240 220 AROs 300 279 — — Act 129 compliance rider — 6 — 6 Other 7 4 3 — Total noncurrent regulatory assets $ 1,262 $ 1,492 $ 541 $ 726 PPL PPL Electric 2020 2019 2020 2019 Current Regulatory Liabilities: Generation supply charge $ 21 $ 23 $ 21 $ 23 Environmental cost recovery 4 5 — — Universal service rider 22 9 22 9 Fuel adjustment clause 5 8 — — TCJA customer refund 11 61 11 59 Storm damage expense rider 6 5 6 5 Act 129 compliance rider 7 — 7 — Other 3 4 1 — Total current regulatory liabilities $ 79 $ 115 $ 68 $ 96 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 653 $ 640 $ — $ — Power purchase agreement - OVEC 43 51 — — Net deferred taxes 1,690 1,756 560 588 Defined benefit plans 60 51 18 11 Terminated interest rate swaps 66 68 — — Other 18 6 — — Total noncurrent regulatory liabilities $ 2,530 $ 2,572 $ 578 $ 599 LKE LG&E KU 2020 2019 2020 2019 2020 2019 Current Regulatory Assets: Plant outage costs $ 46 $ 32 $ 12 $ 16 $ 34 $ 16 Gas supply clause 4 8 4 8 — — Other 9 1 7 1 2 — Total current regulatory assets $ 59 $ 41 $ 23 $ 25 $ 36 $ 16 Noncurrent Regulatory Assets: Defined benefit plans $ 280 $ 333 $ 174 $ 206 $ 106 $ 127 Storm costs 17 24 11 14 6 10 Unamortized loss on debt 22 23 13 14 9 9 Interest rate swaps 23 22 23 22 — — Terminated interest rate swaps 75 81 44 47 31 34 AROs 300 279 85 76 215 203 Other 4 4 1 1 3 3 Total noncurrent regulatory assets $ 721 $ 766 $ 351 $ 380 $ 370 $ 386 LKE LG&E KU 2020 2019 2020 2019 2020 2019 Current Regulatory Liabilities: Environmental cost recovery $ 4 $ 5 $ — $ 1 $ 4 $ 4 Fuel adjustment clauses 5 8 — — 5 8 Other 2 6 — 1 2 5 Total current regulatory liabilities $ 11 $ 19 $ — $ 2 $ 11 $ 17 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 653 $ 640 $ 274 $ 266 $ 379 $ 374 Power purchase agreement - OVEC 43 51 30 35 13 16 Net deferred taxes 1,130 1,168 528 544 602 624 Defined benefit plans 42 40 — — 42 40 Terminated interest rate swaps 66 68 33 34 33 34 Other 18 6 17 4 1 2 Total noncurrent regulatory liabilities $ 1,952 $ 1,973 $ 882 $ 883 $ 1,070 $ 1,090 (a) For PPL, these amounts are included in "Other current assets" on the Balance Sheets.

Financing Activities (Tables)

Financing Activities (Tables)	12 Months Ended
	Dec. 31, 2020
Debt Disclosure [Line Items]
Commercial paper	December 31, 2020 December 31, 2019 Weighted - Capacity Commercial Unused Weighted - Commercial PPL Capital Funding 0.25% $ 1,500 $ 402 $ 1,098 2.13% $ 450 PPL Electric 650 — 650 — LG&E 0.28% 350 262 88 2.07% 238 KU 0.28% 350 203 147 2.02% 150 Total $ 2,850 $ 867 $ 1,983 $ 838
Long-term Debt	Long-term Debt (All Registrants) December 31, Weighted-Average Maturities (g) 2020 2019 PPL U.S. Senior Unsecured Notes 3.95 % 2021 - 2047 $ 4,850 $ 4,325 Senior Secured Notes/First Mortgage Bonds (a) (b) (c) 3.81 % 2021 - 2050 8,955 8,705 Junior Subordinated Notes 4.35 % 2067 - 2073 930 930 Term Loan Credit Facility 0.85 % 2022 100 — Total U.S. Long-term Debt 14,835 13,960 U.K. Senior Unsecured Notes (d) 4.69 % 2021 - 2040 7,197 6,874 Index-linked Senior Unsecured Notes (e) 1.42 % 2028 - 2056 1,150 1,104 Term Loan Credit Facility 1.46 % 2024 67 64 Total U.K. Long-term Debt (f) 8,414 8,042 Total Long-term Debt Before Adjustments 23,249 22,002 Fair market value adjustments 8 12 Unamortized premium and (discount), net 2 5 Unamortized debt issuance costs (132) (126) Total Long-term Debt 23,127 21,893 Less current portion of Long-term Debt 1,574 1,172 Total Long-term Debt, noncurrent $ 21,553 $ 20,721 PPL Electric Senior Secured Notes/First Mortgage Bonds (a) (b) 3.79 % 2021 - 2049 $ 4,289 $ 4,039 Total Long-term Debt Before Adjustments 4,289 4,039 Unamortized discount (23) (24) Unamortized debt issuance costs (30) (30) Total Long-term Debt 4,236 3,985 Less current portion of Long-term Debt 400 — Total Long-term Debt, noncurrent $ 3,836 $ 3,985 LKE Senior Unsecured Notes 4.38 % 2021 $ 250 $ 725 First Mortgage Bonds (a) (c) 3.82 % 2023 - 2050 4,666 4,666 Long-term debt to affiliate 3.89 % 2026 - 2030 1,200 650 Total Long-term Debt Before Adjustments 6,116 6,041 Unamortized premium 5 5 Unamortized discount (13) (12) Unamortized debt issuance costs (34) (32) Total Long-term Debt 6,074 6,002 Less current portion of Long-term Debt 674 975 Total Long-term Debt, noncurrent $ 5,400 $ 5,027 December 31, Weighted-Average Maturities (g) 2020 2019 LG&E First Mortgage Bonds (a) (c) 3.69 % 2025 - 2049 $ 2,024 $ 2,024 Total Long-term Debt Before Adjustments 2,024 2,024 Unamortized discount (4) (4) Unamortized debt issuance costs (13) (15) Total Long-term Debt 2,007 2,005 Less current portion of Long-term Debt 292 — Total Long-term Debt, noncurrent $ 1,715 $ 2,005 KU First Mortgage Bonds (a) (c) 3.92 % 2023 - 2050 $ 2,642 $ 2,642 Total Long-term Debt Before Adjustments 2,642 2,642 Unamortized premium 5 5 Unamortized discount (9) (8) Unamortized debt issuance costs (20) (16) Total Long-term Debt 2,618 2,623 Less current portion of Long-term Debt 132 500 Total Long-term Debt, noncurrent $ 2,486 $ 2,123 (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 $10.8 billion and $10.1 billion at December 31, 2020 and 2019. 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 $5.5 billion and $5.3 billion at December 31, 2020 and 2019. 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 $6.7 billion and $6.6 billion at December 31, 2020 and 2019. (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, 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, 2020, the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a term rate mode totaled $848 million for LKE, comprised of $539 million and $309 million for LG&E and KU respectively. At December 31, 2020, the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a variable rate mode totaled $33 million for LKE and KU respectively. 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) Includes £225 million ($300 million at December 31, 2020) of notes that may be redeemed, in total but not in part, on December 21, 2026, at the greater of the principal value or a value determined by reference to the gross redemption yield on a nominated U.K. Government bond. (e) The principal amount of the notes issued by WPD (South West), WPD (East Midlands) and WPD (South Wales) is adjusted based on changes in a specified index, as detailed in the terms of the related indentures. The adjustment to the principal amounts from 2019 to 2020 was an increase of approximately £10 million ($13 million) resulting from inflation. In addition, this amount includes £331 million ($441 million at December 31, 2020) of notes issued by WPD (South West) that may be redeemed, in total by series, on December 1, 2026, at the greater of the adjusted principal value and a make-whole value determined by reference to the gross real yield on a nominated U.K. government bond. (f) Includes £5.8 billion ($7.7 billion at December 31, 2020) of notes that may be put by the holders to the issuer for redemption if the long-term credit ratings assigned to the notes are withdrawn by any of the rating agencies (Moody's or S&P) or reduced to a non-investment grade rating of Ba1 or BB+ or lower in connection with a restructuring event, which includes the loss of, or a material adverse change to, the distribution licenses under which the issuer operates. (g) The table reflects principal maturities only, based on stated maturities or earlier put dates, and the weighted-average rates as of December 31, 2020.
Long-term Debt Maturities	The aggregate maturities of long-term debt, based on stated maturities or earlier put dates, for the periods 2021 through 2025 and thereafter are as follows: PPL PPL LKE LG&E KU 2021 $ 1,574 $ 400 $ 674 $ 292 $ 132 2022 1,374 474 — — — 2023 2,552 340 13 — 13 2024 950 — — — — 2025 883 — 550 300 250 Thereafter 15,916 3,075 4,879 1,432 2,247 Total $ 23,249 $ 4,289 $ 6,116 $ 2,024 $ 2,642

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2020
Leases [Line Items]
Lessor, Operating Lease, Payments to be Received, Maturity [Table Text Block]	PPL, LKE, LG&E and KU expect to receive over the remaining term of their operating lease agreements for the years ended December 31: 2020 PPL LKE LG&E KU 2021 $ 11 $ 5 $ — $ 5 2022 6 — — — 2023 6 1 — — 2024 5 — — — 2025 4 — — — Thereafter 12 — — — Total $ 44 $ 6 $ — $ 5 Lease income recognized for the twelve months ended December 31, 2020 $ 21 $ 15 $ 6 $ 9 Lease income recognized for the twelve months ended December 31, 2019 21 13 5 8
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: 2020 PPL LKE LG&E KU Lease cost: Operating lease cost $ 30 $ 22 $ 8 $ 13 Short-term lease cost 9 2 1 1 Total lease cost $ 39 $ 24 $ 9 $ 14 2019 PPL LKE LG&E KU Lease cost: Operating lease cost $ 33 $ 25 $ 12 $ 13 Short-term lease cost 7 2 1 1 Total lease cost $ 40 $ 27 $ 13 $ 14 The following table provides other key information related to the Registrants' operating leases at December 31: 2020 PPL LKE LG&E KU Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 26 $ 18 $ 7 $ 11 Right-of-use asset obtained in exchange for new operating lease liabilities 17 16 6 9 2019 PPL LKE LG&E KU Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 29 $ 21 $ 9 $ 11 Right-of-use asset obtained in exchange for new operating lease liabilities 46 16 5 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, 2020. PPL LKE LG&E KU 2021 $ 27 $ 17 $ 6 $ 10 2022 22 13 5 8 2023 18 10 4 6 2024 15 8 3 4 2025 8 6 3 3 Thereafter 20 3 1 2 Total $ 110 $ 57 $ 22 $ 33 Weighted-average discount rate 3.35% 3.66% 3.53% 3.68% Weighted-average remaining lease term (in years) 8 4 4 4 Current lease liabilities (a) $ 24 $ 16 $ 6 $ 9 Non-current lease liabilities (a) 70 37 15 21 Right-of-use assets (b) 87 46 17 27 (a) Current lease liabilities are included in "Other Current Liabilities" on the Balance Sheets. Non-current lease liabilities are included in "Other deferred credits and noncurrent liabilities" on the Balance Sheets. The difference between the total future minimum lease payments and the recorded lease liabilities is due to the impact of discounting. (b) Right-of-use assets are included in "Other noncurrent assets" on the Balance Sheets.
LG And E And KU Energy LLC [Member]
Leases [Line Items]
Lessor, Operating Lease, Payments to be Received, Maturity [Table Text Block]	PPL, LKE, LG&E and KU expect to receive over the remaining term of their operating lease agreements for the years ended December 31: 2020 PPL LKE LG&E KU 2021 $ 11 $ 5 $ — $ 5 2022 6 — — — 2023 6 1 — — 2024 5 — — — 2025 4 — — — Thereafter 12 — — — Total $ 44 $ 6 $ — $ 5 Lease income recognized for the twelve months ended December 31, 2020 $ 21 $ 15 $ 6 $ 9 Lease income recognized for the twelve months ended December 31, 2019 21 13 5 8
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: 2020 PPL LKE LG&E KU Lease cost: Operating lease cost $ 30 $ 22 $ 8 $ 13 Short-term lease cost 9 2 1 1 Total lease cost $ 39 $ 24 $ 9 $ 14 2019 PPL LKE LG&E KU Lease cost: Operating lease cost $ 33 $ 25 $ 12 $ 13 Short-term lease cost 7 2 1 1 Total lease cost $ 40 $ 27 $ 13 $ 14 The following table provides other key information related to the Registrants' operating leases at December 31: 2020 PPL LKE LG&E KU Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 26 $ 18 $ 7 $ 11 Right-of-use asset obtained in exchange for new operating lease liabilities 17 16 6 9 2019 PPL LKE LG&E KU Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 29 $ 21 $ 9 $ 11 Right-of-use asset obtained in exchange for new operating lease liabilities 46 16 5 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, 2020. PPL LKE LG&E KU 2021 $ 27 $ 17 $ 6 $ 10 2022 22 13 5 8 2023 18 10 4 6 2024 15 8 3 4 2025 8 6 3 3 Thereafter 20 3 1 2 Total $ 110 $ 57 $ 22 $ 33 Weighted-average discount rate 3.35% 3.66% 3.53% 3.68% Weighted-average remaining lease term (in years) 8 4 4 4 Current lease liabilities (a) $ 24 $ 16 $ 6 $ 9 Non-current lease liabilities (a) 70 37 15 21 Right-of-use assets (b) 87 46 17 27 (a) Current lease liabilities are included in "Other Current Liabilities" on the Balance Sheets. Non-current lease liabilities are included in "Other deferred credits and noncurrent liabilities" on the Balance Sheets. The difference between the total future minimum lease payments and the recorded lease liabilities is due to the impact of discounting. (b) Right-of-use assets are included in "Other noncurrent assets" on the Balance Sheets.
Louisville Gas And Electric Co [Member]
Leases [Line Items]
Lessor, Operating Lease, Payments to be Received, Maturity [Table Text Block]	PPL, LKE, LG&E and KU expect to receive over the remaining term of their operating lease agreements for the years ended December 31: 2020 PPL LKE LG&E KU 2021 $ 11 $ 5 $ — $ 5 2022 6 — — — 2023 6 1 — — 2024 5 — — — 2025 4 — — — Thereafter 12 — — — Total $ 44 $ 6 $ — $ 5 Lease income recognized for the twelve months ended December 31, 2020 $ 21 $ 15 $ 6 $ 9 Lease income recognized for the twelve months ended December 31, 2019 21 13 5 8
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: 2020 PPL LKE LG&E KU Lease cost: Operating lease cost $ 30 $ 22 $ 8 $ 13 Short-term lease cost 9 2 1 1 Total lease cost $ 39 $ 24 $ 9 $ 14 2019 PPL LKE LG&E KU Lease cost: Operating lease cost $ 33 $ 25 $ 12 $ 13 Short-term lease cost 7 2 1 1 Total lease cost $ 40 $ 27 $ 13 $ 14 The following table provides other key information related to the Registrants' operating leases at December 31: 2020 PPL LKE LG&E KU Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 26 $ 18 $ 7 $ 11 Right-of-use asset obtained in exchange for new operating lease liabilities 17 16 6 9 2019 PPL LKE LG&E KU Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 29 $ 21 $ 9 $ 11 Right-of-use asset obtained in exchange for new operating lease liabilities 46 16 5 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, 2020. PPL LKE LG&E KU 2021 $ 27 $ 17 $ 6 $ 10 2022 22 13 5 8 2023 18 10 4 6 2024 15 8 3 4 2025 8 6 3 3 Thereafter 20 3 1 2 Total $ 110 $ 57 $ 22 $ 33 Weighted-average discount rate 3.35% 3.66% 3.53% 3.68% Weighted-average remaining lease term (in years) 8 4 4 4 Current lease liabilities (a) $ 24 $ 16 $ 6 $ 9 Non-current lease liabilities (a) 70 37 15 21 Right-of-use assets (b) 87 46 17 27 (a) Current lease liabilities are included in "Other Current Liabilities" on the Balance Sheets. Non-current lease liabilities are included in "Other deferred credits and noncurrent liabilities" on the Balance Sheets. The difference between the total future minimum lease payments and the recorded lease liabilities is due to the impact of discounting. (b) Right-of-use assets are included in "Other noncurrent assets" on the Balance Sheets.
Kentucky Utilities Co [Member]
Leases [Line Items]
Lessor, Operating Lease, Payments to be Received, Maturity [Table Text Block]	PPL, LKE, LG&E and KU expect to receive over the remaining term of their operating lease agreements for the years ended December 31: 2020 PPL LKE LG&E KU 2021 $ 11 $ 5 $ — $ 5 2022 6 — — — 2023 6 1 — — 2024 5 — — — 2025 4 — — — Thereafter 12 — — — Total $ 44 $ 6 $ — $ 5 Lease income recognized for the twelve months ended December 31, 2020 $ 21 $ 15 $ 6 $ 9 Lease income recognized for the twelve months ended December 31, 2019 21 13 5 8
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: 2020 PPL LKE LG&E KU Lease cost: Operating lease cost $ 30 $ 22 $ 8 $ 13 Short-term lease cost 9 2 1 1 Total lease cost $ 39 $ 24 $ 9 $ 14 2019 PPL LKE LG&E KU Lease cost: Operating lease cost $ 33 $ 25 $ 12 $ 13 Short-term lease cost 7 2 1 1 Total lease cost $ 40 $ 27 $ 13 $ 14 The following table provides other key information related to the Registrants' operating leases at December 31: 2020 PPL LKE LG&E KU Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 26 $ 18 $ 7 $ 11 Right-of-use asset obtained in exchange for new operating lease liabilities 17 16 6 9 2019 PPL LKE LG&E KU Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 29 $ 21 $ 9 $ 11 Right-of-use asset obtained in exchange for new operating lease liabilities 46 16 5 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, 2020. PPL LKE LG&E KU 2021 $ 27 $ 17 $ 6 $ 10 2022 22 13 5 8 2023 18 10 4 6 2024 15 8 3 4 2025 8 6 3 3 Thereafter 20 3 1 2 Total $ 110 $ 57 $ 22 $ 33 Weighted-average discount rate 3.35% 3.66% 3.53% 3.68% Weighted-average remaining lease term (in years) 8 4 4 4 Current lease liabilities (a) $ 24 $ 16 $ 6 $ 9 Non-current lease liabilities (a) 70 37 15 21 Right-of-use assets (b) 87 46 17 27 (a) Current lease liabilities are included in "Other Current Liabilities" on the Balance Sheets. Non-current lease liabilities are included in "Other deferred credits and noncurrent liabilities" on the Balance Sheets. The difference between the total future minimum lease payments and the recorded lease liabilities is due to the impact of discounting. (b) Right-of-use assets are included in "Other noncurrent assets" on the Balance Sheets.

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2020
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: 2020 2019 2018 PPL $ 35.30 $ 31.95 $ 30.58 PPL Electric 35.37 32.33 30.00 LKE 35.31 30.65 30.98
Restricted Stock and Restricted Stock Units, Activity Rollforward	Restricted stock unit activity for 2020 was: Restricted Weighted- PPL Nonvested, beginning of period 1,137,685 $ 32.76 Granted 331,160 35.30 Vested (562,848) 34.57 Forfeited (9,661) 32.97 Nonvested, end of period 896,336 32.56 PPL Electric Nonvested, beginning of period 229,860 $ 32.61 Transfer between registrants (1,197) 32.23 Granted 65,356 35.37 Vested (79,313) 34.55 Forfeited (3,986) 32.65 Nonvested, end of period 210,720 32.73 LKE Nonvested, beginning of period 166,445 $ 32.09 Transfer between registrants (1,598) 30.57 Granted 50,402 35.31 Vested (60,571) 34.88 Forfeited (1,550) 30.36 Nonvested, end of period 153,128 32.08
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: 2020 2019 2018 PPL $ 19 $ 13 $ 16 PPL Electric 3 2 2 LKE 2 1 5
Performance Units, Valuation Assumptions	The weighted-average assumptions used in the model were: 2020 2019 2018 Expected stock volatility 15.64% 17.57% 17.60% 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: 2020 2019 2018 PPL $ 37.63 $ 35.83 $ 38.26 PPL Electric 38.64 35.68 38.37 LKE 37.73 35.93 38.32 The weighted-average grant date fair value of ROE performance units granted was: 2020 2019 2018 PPL $ 34.95 $ 30.89 $ 32.21 PPL Electric 35.59 30.76 32.32 LKE 34.81 30.99 32.28
Performance Units, Activity Rollforward	TSR performance unit activity for 2020 was: TSR Performance Units Weighted- PPL Nonvested, beginning of period 739,392 $ 37.50 Granted 261,891 37.63 Forfeited (a) (375,029) 38.46 Nonvested, end of period 626,254 36.98 PPL Electric Nonvested, beginning of period 66,799 $ 37.43 Granted 21,416 38.64 Forfeited (a) (26,408) 38.37 Nonvested, end of period 61,807 37.44 LKE Nonvested, beginning of period 130,533 $ 37.60 Granted 35,538 37.73 Forfeited (a) (66,459) 38.23 Nonvested, end of period 99,612 37.23 (a) Primarily related to the forfeiture of 2017 performance units as performance during the period was below the minimum established performance threshold, which resulted in no payout. ROE performance unit activity for 2020 was: ROE Performance Unit Weighted- PPL Nonvested, beginning of period 570,765 $ 32.02 Granted 374,878 34.95 Vested (216,979) 34.42 Nonvested, end of period 728,664 32.81 PPL Electric Nonvested, beginning of period 49,194 $ 31.92 Granted 30,426 35.59 Vested (17,813) 34.41 Nonvested, end of period 61,807 33.01 LKE Nonvested, beginning of period 107,805 $ 32.20 Granted 60,286 34.81 Vested (46,384) 34.29 Nonvested, end of period 121,707 32.70
Stock Options, Activity Rollforward	Stock option activity for 2020 was: Number Weighted Weighted- Aggregate PPL Outstanding at beginning of period 1,330,943 $ 26.20 Exercised (227,927) 26.10 Outstanding and exercisable at end of period 1,103,016 26.22 1.7 $ 2
Compensation Costs for Restricted Stock, Restricted Stock Units, Performance Units and Stock Options	2020 2019 2018 PPL $ 28 $ 35 $ 25 PPL Electric 10 12 10 LKE 11 9 8 The income tax benefit related to above compensation expense was as follows: 2020 2019 2018 PPL $ 8 $ 10 $ 10 PPL Electric 3 3 3 LKE 3 2 2
Unrecognized Compensation Cost, Nonvested Restricted Stock, Restricted Stock Units, Performance Units and Stock Option Awards	At December 31, 2020, unrecognized compensation expense related to nonvested stock awards was: Unrecognized Weighted- PPL $ 16 1.7 PPL Electric 3 1.8 LKE 1 1.4
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: 2020 PPL $ 8 PPL Electric 1 LKE 2
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: 2020 2019 2018 PPL $ 35.30 $ 31.95 $ 30.58 PPL Electric 35.37 32.33 30.00 LKE 35.31 30.65 30.98
Restricted Stock and Restricted Stock Units, Activity Rollforward	Restricted stock unit activity for 2020 was: Restricted Weighted- PPL Nonvested, beginning of period 1,137,685 $ 32.76 Granted 331,160 35.30 Vested (562,848) 34.57 Forfeited (9,661) 32.97 Nonvested, end of period 896,336 32.56 PPL Electric Nonvested, beginning of period 229,860 $ 32.61 Transfer between registrants (1,197) 32.23 Granted 65,356 35.37 Vested (79,313) 34.55 Forfeited (3,986) 32.65 Nonvested, end of period 210,720 32.73 LKE Nonvested, beginning of period 166,445 $ 32.09 Transfer between registrants (1,598) 30.57 Granted 50,402 35.31 Vested (60,571) 34.88 Forfeited (1,550) 30.36 Nonvested, end of period 153,128 32.08
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: 2020 2019 2018 PPL $ 19 $ 13 $ 16 PPL Electric 3 2 2 LKE 2 1 5
Performance Units, Valuation Assumptions	The weighted-average assumptions used in the model were: 2020 2019 2018 Expected stock volatility 15.64% 17.57% 17.60% 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: 2020 2019 2018 PPL $ 37.63 $ 35.83 $ 38.26 PPL Electric 38.64 35.68 38.37 LKE 37.73 35.93 38.32 The weighted-average grant date fair value of ROE performance units granted was: 2020 2019 2018 PPL $ 34.95 $ 30.89 $ 32.21 PPL Electric 35.59 30.76 32.32 LKE 34.81 30.99 32.28
Performance Units, Activity Rollforward	TSR performance unit activity for 2020 was: TSR Performance Units Weighted- PPL Nonvested, beginning of period 739,392 $ 37.50 Granted 261,891 37.63 Forfeited (a) (375,029) 38.46 Nonvested, end of period 626,254 36.98 PPL Electric Nonvested, beginning of period 66,799 $ 37.43 Granted 21,416 38.64 Forfeited (a) (26,408) 38.37 Nonvested, end of period 61,807 37.44 LKE Nonvested, beginning of period 130,533 $ 37.60 Granted 35,538 37.73 Forfeited (a) (66,459) 38.23 Nonvested, end of period 99,612 37.23 (a) Primarily related to the forfeiture of 2017 performance units as performance during the period was below the minimum established performance threshold, which resulted in no payout. ROE performance unit activity for 2020 was: ROE Performance Unit Weighted- PPL Nonvested, beginning of period 570,765 $ 32.02 Granted 374,878 34.95 Vested (216,979) 34.42 Nonvested, end of period 728,664 32.81 PPL Electric Nonvested, beginning of period 49,194 $ 31.92 Granted 30,426 35.59 Vested (17,813) 34.41 Nonvested, end of period 61,807 33.01 LKE Nonvested, beginning of period 107,805 $ 32.20 Granted 60,286 34.81 Vested (46,384) 34.29 Nonvested, end of period 121,707 32.70
Compensation Costs for Restricted Stock, Restricted Stock Units, Performance Units and Stock Options	2020 2019 2018 PPL $ 28 $ 35 $ 25 PPL Electric 10 12 10 LKE 11 9 8 The income tax benefit related to above compensation expense was as follows: 2020 2019 2018 PPL $ 8 $ 10 $ 10 PPL Electric 3 3 3 LKE 3 2 2
Unrecognized Compensation Cost, Nonvested Restricted Stock, Restricted Stock Units, Performance Units and Stock Option Awards	At December 31, 2020, unrecognized compensation expense related to nonvested stock awards was: Unrecognized Weighted- PPL $ 16 1.7 PPL Electric 3 1.8 LKE 1 1.4
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: 2020 PPL $ 8 PPL Electric 1 LKE 2
LG And E And KU Energy LLC [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: 2020 2019 2018 PPL $ 35.30 $ 31.95 $ 30.58 PPL Electric 35.37 32.33 30.00 LKE 35.31 30.65 30.98
Restricted Stock and Restricted Stock Units, Activity Rollforward	Restricted stock unit activity for 2020 was: Restricted Weighted- PPL Nonvested, beginning of period 1,137,685 $ 32.76 Granted 331,160 35.30 Vested (562,848) 34.57 Forfeited (9,661) 32.97 Nonvested, end of period 896,336 32.56 PPL Electric Nonvested, beginning of period 229,860 $ 32.61 Transfer between registrants (1,197) 32.23 Granted 65,356 35.37 Vested (79,313) 34.55 Forfeited (3,986) 32.65 Nonvested, end of period 210,720 32.73 LKE Nonvested, beginning of period 166,445 $ 32.09 Transfer between registrants (1,598) 30.57 Granted 50,402 35.31 Vested (60,571) 34.88 Forfeited (1,550) 30.36 Nonvested, end of period 153,128 32.08
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: 2020 2019 2018 PPL $ 19 $ 13 $ 16 PPL Electric 3 2 2 LKE 2 1 5
Performance Units, Valuation Assumptions	The weighted-average assumptions used in the model were: 2020 2019 2018 Expected stock volatility 15.64% 17.57% 17.60% 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: 2020 2019 2018 PPL $ 37.63 $ 35.83 $ 38.26 PPL Electric 38.64 35.68 38.37 LKE 37.73 35.93 38.32 The weighted-average grant date fair value of ROE performance units granted was: 2020 2019 2018 PPL $ 34.95 $ 30.89 $ 32.21 PPL Electric 35.59 30.76 32.32 LKE 34.81 30.99 32.28
Performance Units, Activity Rollforward	TSR performance unit activity for 2020 was: TSR Performance Units Weighted- PPL Nonvested, beginning of period 739,392 $ 37.50 Granted 261,891 37.63 Forfeited (a) (375,029) 38.46 Nonvested, end of period 626,254 36.98 PPL Electric Nonvested, beginning of period 66,799 $ 37.43 Granted 21,416 38.64 Forfeited (a) (26,408) 38.37 Nonvested, end of period 61,807 37.44 LKE Nonvested, beginning of period 130,533 $ 37.60 Granted 35,538 37.73 Forfeited (a) (66,459) 38.23 Nonvested, end of period 99,612 37.23 (a) Primarily related to the forfeiture of 2017 performance units as performance during the period was below the minimum established performance threshold, which resulted in no payout. ROE performance unit activity for 2020 was: ROE Performance Unit Weighted- PPL Nonvested, beginning of period 570,765 $ 32.02 Granted 374,878 34.95 Vested (216,979) 34.42 Nonvested, end of period 728,664 32.81 PPL Electric Nonvested, beginning of period 49,194 $ 31.92 Granted 30,426 35.59 Vested (17,813) 34.41 Nonvested, end of period 61,807 33.01 LKE Nonvested, beginning of period 107,805 $ 32.20 Granted 60,286 34.81 Vested (46,384) 34.29 Nonvested, end of period 121,707 32.70
Compensation Costs for Restricted Stock, Restricted Stock Units, Performance Units and Stock Options	2020 2019 2018 PPL $ 28 $ 35 $ 25 PPL Electric 10 12 10 LKE 11 9 8 The income tax benefit related to above compensation expense was as follows: 2020 2019 2018 PPL $ 8 $ 10 $ 10 PPL Electric 3 3 3 LKE 3 2 2
Unrecognized Compensation Cost, Nonvested Restricted Stock, Restricted Stock Units, Performance Units and Stock Option Awards	At December 31, 2020, unrecognized compensation expense related to nonvested stock awards was: Unrecognized Weighted- PPL $ 16 1.7 PPL Electric 3 1.8 LKE 1 1.4
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: 2020 PPL $ 8 PPL Electric 1 LKE 2

Retirement and Postemployment_2

Retirement and Postemployment Benefits (Tables)	12 Months Ended
	Dec. 31, 2020
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 domestic (U.S.) and WPD's (U.K.) pension and other postretirement benefit plans for the years ended December 31. Pension Benefits U.S. U.K. Other Postretirement Benefits 2020 2019 2018 2020 2019 2018 2020 2019 2018 Net periodic defined benefit costs (credits): Service cost $ 56 $ 50 $ 62 $ 89 $ 68 $ 82 $ 6 $ 6 $ 7 Interest cost 146 164 156 143 187 185 19 22 21 Expected return on plan assets (246) (245) (249) (622) (588) (587) (21) (18) (23) Amortization of: Prior service cost (credit) 9 8 10 1 1 — 1 (1) (1) Actuarial (gain) loss 89 56 84 213 92 151 — 1 — Net periodic defined benefit costs 54 33 63 (176) (240) (169) 5 10 4 Settlements (a) 23 1 — — — — — — — Net periodic defined benefit costs $ 77 $ 34 $ 63 $ (176) $ (240) $ (169) $ 5 $ 10 $ 4 Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: Settlement (23) (1) — — — — — — — Net (gain) loss (221) (121) 157 459 723 201 (6) (18) 8 Prior service cost 1 2 1 — — 13 5 — — Amortization of: Prior service (cost) credit (9) (8) (10) (1) (1) — (1) 1 1 Actuarial gain (loss) (89) (56) (84) (213) (92) (151) — (1) — Total recognized in OCI and (341) (184) 64 245 630 63 (2) (18) 9 Total recognized in net periodic $ (264) $ (150) $ 127 $ 69 $ 390 $ (106) $ 3 $ (8) $ 13 (a) Includes 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. (b) WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP. As a result, WPD does not record regulatory assets/liabilities.
Schedule of Amounts Recognized in Other Comprehensive Income and Regulatory Assets and Liabilities	For PPL's U.S. pension benefits and for other postretirement benefits, the amounts recognized in OCI and regulatory assets/liabilities for the years ended December 31 were as follows: U.S. Pension Benefits Other Postretirement Benefits 2020 2019 2018 2020 2019 2018 OCI $ (428) $ (194) $ 90 $ (12) $ (13) $ 20 Regulatory assets/liabilities 87 10 (26) 10 (5) (11) Total recognized in OCI and $ (341) $ (184) $ 64 $ (2) $ (18) $ 9
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. The U.K. pension benefits apply to PPL only. Pension Benefits U.S. U.K. Other Postretirement Benefits 2020 2019 2018 2020 2019 2018 2020 2019 2018 PPL $ 40 $ 18 $ 40 $ (237) $ (287) $ (226) $ 4 $ 8 $ 2 PPL Electric (a) (2) (4) 4 2 4 (1) LKE (b) 20 12 21 1 2 3 LG&E (a) (b) 4 3 4 2 2 2 KU (a) (b) 1 (1) 2 — — 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 and KU do 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.
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. The U.K. pension benefits apply to PPL only. Pension Benefits U.S. U.K. Other Postretirement Benefits 2020 2019 2020 2019 2020 2019 PPL Discount rate 2.92 % 3.64 % 1.53 % 1.94 % 2.84 % 3.60 % Rate of compensation increase 3.76 % 3.79 % 3.25 % 3.25 % 3.75 % 3.76 % LKE Discount rate 2.91 % 3.62 % 2.85 % 3.59 % Rate of compensation increase 3.50 % 3.50 % 3.50 % 3.50 % LG&E Discount rate — % 3.60 % The following weighted-average assumptions were used to determine the net periodic defined benefit costs for the years ended December 31. The U.K. pension benefits apply to PPL only. Pension Benefits U.S. U.K. Other Postretirement Benefits 2020 2019 2018 2020 2019 2018 2020 2019 2018 PPL Discount rate service cost 3.64 % 4.35 % 3.70 % 2.03 % 3.12 % 2.73 % 3.60 % 4.31 % 3.64 % Discount rate interest cost 3.64 % 4.35 % 3.70 % 1.73 % 2.62 % 2.31 % 3.60 % 4.31 % 3.64 % Rate of compensation increase 3.79 % 3.79 % 3.78 % 3.25 % 3.50 % 3.50 % 3.76 % 3.76 % 3.75 % Expected return on plan assets 7.25 % 7.25 % 7.25 % 7.13 % 7.21 % 7.23 % 6.44 % 6.46 % 6.40 % LKE Discount rate 3.62 % 4.35 % 3.69 % 3.59 % 4.32 % 3.65 % Rate of compensation increase 3.50 % 3.50 % 3.50 % 3.50 % 3.50 % 3.50 % Expected return on plan assets (a) 7.25 % 7.25 % 7.25 % 7.02 % 7.00 % 7.15 % LG&E Discount rate — % 4.33 % 3.65 % Expected return on plan assets (a) — % 7.25 % 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 and LKE) The following table provides the assumed health care cost trend rates for the years ended December 31: 2020 2019 2018 PPL and LKE Health care cost trend rate assumed for next year – obligations 6.5 % 6.6 % 6.6 % – cost 6.6 % 6.6 % 6.6 % Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) – obligations 5.0 % 5.0 % 5.0 % – cost 5.0 % 5.0 % 5.0 % Year that the rate reaches the ultimate trend rate – obligations 2027 2024 2023 – cost 2024 2023 2022
Schedule of Funded Status of Defined Benefit Plans	The funded status of PPL's plans at December 31 was as follows: Pension Benefits U.S. U.K. Other Postretirement Benefits 2020 2019 2020 2019 2020 2019 Change in Benefit Obligation Benefit Obligation, beginning of period $ 4,146 $ 3,883 $ 8,515 $ 7,275 $ 557 $ 538 Service cost 56 50 89 68 6 6 Interest cost 146 164 143 187 19 22 Participant contributions — — 12 12 15 14 Plan amendments 2 2 — — 5 — Actuarial (gain) loss 256 368 624 1,220 29 34 Settlements (114) (21) — — — — Gross benefits paid (241) (300) (366) (363) (58) (58) Federal subsidy — — — — — 1 Currency conversion — — 281 116 — — Benefit Obligation, end of period 4,251 4,146 9,298 8,515 573 557 Change in Plan Assets Plan assets at fair value, beginning of period 3,585 3,109 8,945 7,801 340 301 Actual return on plan assets 723 735 805 1,095 56 71 Employer contributions 115 63 272 278 18 10 Participant contributions — — 12 12 11 10 Settlements (114) (22) — — — — Gross benefits paid (241) (300) (366) (363) (58) (52) Currency conversion — — 302 122 — — Plan assets at fair value, end of period 4,068 3,585 9,970 8,945 367 340 Funded Status, end of period $ (183) $ (561) $ 672 $ 430 $ (206) $ (217) Amounts recognized in the Balance Sheets consist of: Noncurrent asset $ 24 $ 24 $ 682 $ 440 $ — $ 11 Current liability (18) (8) — (1) (22) (2) Noncurrent liability (189) (577) (10) (9) (184) (226) Net amount recognized, end of period $ (183) $ (561) $ 672 $ 430 $ (206) $ (217) Pension Benefits U.S. U.K. Other Postretirement Benefits 2020 2019 2020 2019 2020 2019 Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: Prior service cost (credit) $ 27 $ 34 $ 11 $ 11 $ 14 $ 10 Net actuarial (gain) loss 695 1,029 3,682 3,435 — 6 Total (a) $ 722 $ 1,063 $ 3,693 $ 3,446 $ 14 $ 16 Total accumulated benefit obligation $ 4,024 $ 3,910 $ 8,516 $ 7,821 (a) WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP and as a result, does not record regulatory assets/liabilities. For PPL's U.S. pension and other postretirement benefit plans, the amounts recognized in AOCI and regulatory assets/liabilities at December 31 were as follows: U.S. Pension Benefits Other Postretirement Benefits 2020 2019 2020 2019 AOCI $ 270 $ 352 $ 10 $ 13 Regulatory assets/liabilities 452 711 4 3 Total $ 722 $ 1,063 $ 14 $ 16
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: U.S. U.K. PBO in excess of plan assets PBO in excess of plan assets 2020 2019 2020 2019 Projected benefit obligation $ 1,875 $ 3,861 $ 11 $ 10 Fair value of plan assets 1,668 3,275 — — U.S. U.K. ABO in excess of plan assets ABO in excess of plan assets 2020 2019 2020 2019 Accumulated benefit obligation $ 184 $ 3,624 $ 11 $ 10 Fair value of plan assets — 3,275 — —
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 2020 2020 2019 (a) Target Asset Growth Portfolio 56 % 57 % 55 % Equity securities 34 % 34 % Debt securities (b) 13 % 14 % Alternative investments 9 % 9 % Immunizing Portfolio 43 % 42 % 43 % Debt securities (b) 33 % 35 % Derivatives 10 % 7 % Liquidity Portfolio 1 % 1 % 2 % Total 100 % 100 % 100 % (a) Allocations exclude consideration of a group annuity contract held by the LG&E and KU Retirement Plan. (b) 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, 2020 December 31, 2019 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 $ 300 $ 300 $ — $ — $ 182 $ 182 $ — $ — Equity securities: U.S. Equity 60 60 — — 194 194 — — U.S. Equity fund measured at NAV (a) 742 — — — 451 — — — International equity fund at NAV (a) 566 — — — 554 — — — Commingled debt measured at NAV (a) 712 — — — 621 — — — Debt securities: U.S. Treasury and U.S. government sponsored 336 335 1 — 310 309 1 — Corporate 1,045 — 1,030 15 951 — 931 20 Other 13 — 13 — 14 — 14 — December 31, 2020 December 31, 2019 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Alternative investments: Real estate measured at NAV (a) 76 — — — 88 — — — Private equity measured at NAV (a) 68 — — — 62 — — — Hedge funds measured at NAV (a) 223 — — — 194 — — — Limited Partnerships at NAV (a) 6 — — — — — — — Derivatives (37) — (37) — 3 — 3 — Insurance contracts — — — — 4 — — 4 PPL Services Corporation Master Trust assets, at 4,110 $ 695 $ 1,007 $ 15 3,628 $ 685 $ 949 $ 24 Receivables and payables, net (b) 116 99 401(h) accounts restricted for other (158) (142) Total PPL Services Corporation Master Trust $ 4,068 $ 3,585 (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, 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 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2019 is as follows: Corporate Insurance Total Balance at beginning of period $ 25 $ 21 $ 46 Actual return on plan assets: Relating to assets still held at the reporting date (1) 4 3 Relating to assets sold during the period 3 — 3 Purchases, sales and settlements (7) (21) (28) Balance at end of period $ 20 $ 4 $ 24
Schedules of Target Allocation of U.S. Other Postretirement Benefit Plans VEBA Trust	The asset allocation for the PPL VEBA trusts, excluding LKE, and the target allocation, by asset class, at December 31 are detailed below. Percentage of plan assets Target Asset 2020 2019 2020 Asset Class U.S. Equity securities 42 % 45 % 45 % Debt securities (a) 55 % 52 % 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 U.S. other postretirement benefit plans by asset class and level within the fair value hierarchy was: December 31, 2020 December 31, 2019 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 $ 5 $ 5 $ — $ — $ 6 $ 6 $ — $ — U.S. Equity securities: Large-cap equity fund measure at NAV (a) 89 — — — 89 — — — Commingled debt fund measured at NAV (a) 77 — — — 68 — — — Debt securities: Corporate bonds 37 — 37 — 35 — 35 — U.S. Treasury and U.S. government sponsored 2 — 2 — — — — — Total VEBA trust assets, at fair value 210 $ 5 $ 39 $ — 198 $ 6 $ 35 $ — Receivables and payables, net (b) (1) — 401(h) account assets 158 142 Total other postretirement benefit plan assets $ 367 $ 340 (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.
Schedules of Asset Allocation of U.K. Pension Plan Assets	The asset allocation and target allocation at December 31 of WPD's pension plans are detailed below. Target Asset Percentage of plan assets Allocation 2020 2019 2020 Asset Class Cash and cash equivalents 4 % 2 % — % Equity securities U.K. — % — % 2 % European (excluding the U.K.) — % — % 1 % Asian-Pacific — % — % 1 % North American — % 1 % 1 % Emerging markets — % — % 1 % Global equities 23 % 19 % 9 % Global Tactical Asset Allocation 20 % 29 % 41 % Debt securities (a) 48 % 43 % 38 % Alternative investments 5 % 6 % 6 % Total 100 % 100 % 100 % (a) Includes commingled debt funds.
Schedule of Fair Value of Financial Assets for U.K. Pension Plan Assets	The fair value of assets in the U.K. pension plans by asset class and level within the fair value hierarchy was: December 31, 2020 December 31, 2019 Fair Value Measurement Using Fair Value Measurement Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Cash and cash equivalents $ 412 $ 412 $ — $ — $ 154 $ 154 $ — $ — Equity securities measured at NAV (a) : U.K. companies 1 — — — 22 — — — European companies (excluding the U.K.) 3 — — — 54 — — — Asian-Pacific companies 3 — — — 35 — — — North American companies 3 — — — 74 — — — Emerging markets companies 1 — — — 32 — — — Global Equities 2,253 — — — 1,684 — — — Other 1,950 — — — 2,584 — — — Debt Securities: U.K. corporate bonds — — — — 5 — 5 — U.K. corporate bonds measured at NAV (a) 574 — — — — — $ — — U.K. gilts 4,209 — 4,209 — 3,819 — 3,819 — Alternative investments: Real estate measured at NAV (a) 557 — — — 519 — — — Fair value - U.K. pension plans 9,966 $ 412 $ 4,209 $ — 8,982 $ 154 $ 3,824 $ — Receivables and payables, net (b) 4 (37) Total U.K. pension assets $ 9,970 $ 8,945 (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.
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 2021 $ 296 $ 49 $ 1 2022 284 47 — 2023 279 46 — 2024 275 44 — 2025 273 43 — 2026-2030 1,273 194 1
Schedule of Expected Cash Flows - U.K. Pension Plans - Expected Payments	The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid by the plans. Pension 2021 $ 362 2022 367 2023 370 2024 375 2025 377 2026-2030 1,884
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: 2020 2019 2018 PPL $ 42 $ 42 $ 40 PPL Electric 6 6 6 LKE 19 21 20 LG&E 6 6 6 KU 5 5 5
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: 2020 2019 Pension $ (4) $ 179 Other postretirement benefits 99 122
LG And E And KU Energy LLC [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 LKE's pension and other postretirement benefit plans for the years ended December 31. Pension Benefits Other Postretirement Benefits 2020 2019 2018 2020 2019 2018 Net periodic defined benefit costs (credits): Service cost $ 24 $ 22 $ 25 $ 4 $ 4 $ 4 Interest cost 57 66 63 7 8 8 Expected return on plan assets (101) (101) (102) (9) (8) (9) Amortization of: Prior service cost 8 8 9 1 1 1 Actuarial (gain) loss (a) 41 22 35 (1) (1) — Net periodic defined benefit costs (credits) before settlements $ 29 $ 17 $ 30 $ 2 $ 4 $ 4 Settlements (b) 15 — — — — — Net periodic defined benefit costs (credits) (c) $ 44 $ 17 $ 30 $ 2 $ 4 $ 4 Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Settlements $ (15) $ — $ — $ — $ — $ — Net (gain) loss (29) (37) 40 (1) (14) 1 Prior service cost 2 2 — 5 — — Amortization of: Prior service credit (8) (8) (9) (1) (1) (1) Actuarial gain (loss) (41) (22) (35) 1 1 — Total recognized in OCI and (91) (65) (4) 4 (14) — Total recognized in net periodic $ (47) $ (48) $ 26 $ 6 $ (10) $ 4 (a) 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 LKE's pension accounting policy and actuarial (gain)/loss calculated using a 15 year amortization period was $11 million in 2020, $5 million in 2019 and $11 million in 2018. (b) Due to the amount of lump sum payment distributions from the LKE qualified pension plan, a settlement charge of $15 million for the year ended December 31, 2020 was incurred. 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 attributable to LKE’s operations outside of the jurisdiction of the KPSC has been charged to expense. (c) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, settlement charges of $5 million in 2019 and $6 million in 2018 were 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.
Schedule of Amounts Recognized in Other Comprehensive Income and Regulatory Assets and Liabilities	For LKE's pension and other 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 2020 2019 2018 2020 2019 2018 OCI $ (5) $ 13 $ (25) $ (2) $ (7) $ 4 Regulatory assets/liabilities (86) (78) 21 6 (7) (4) Total recognized in OCI and $ (91) $ (65) $ (4) $ 4 $ (14) $ —
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. The U.K. pension benefits apply to PPL only. Pension Benefits U.S. U.K. Other Postretirement Benefits 2020 2019 2020 2019 2020 2019 PPL Discount rate 2.92 % 3.64 % 1.53 % 1.94 % 2.84 % 3.60 % Rate of compensation increase 3.76 % 3.79 % 3.25 % 3.25 % 3.75 % 3.76 % LKE Discount rate 2.91 % 3.62 % 2.85 % 3.59 % Rate of compensation increase 3.50 % 3.50 % 3.50 % 3.50 % LG&E Discount rate — % 3.60 % The following weighted-average assumptions were used to determine the net periodic defined benefit costs for the years ended December 31. The U.K. pension benefits apply to PPL only. Pension Benefits U.S. U.K. Other Postretirement Benefits 2020 2019 2018 2020 2019 2018 2020 2019 2018 PPL Discount rate service cost 3.64 % 4.35 % 3.70 % 2.03 % 3.12 % 2.73 % 3.60 % 4.31 % 3.64 % Discount rate interest cost 3.64 % 4.35 % 3.70 % 1.73 % 2.62 % 2.31 % 3.60 % 4.31 % 3.64 % Rate of compensation increase 3.79 % 3.79 % 3.78 % 3.25 % 3.50 % 3.50 % 3.76 % 3.76 % 3.75 % Expected return on plan assets 7.25 % 7.25 % 7.25 % 7.13 % 7.21 % 7.23 % 6.44 % 6.46 % 6.40 % LKE Discount rate 3.62 % 4.35 % 3.69 % 3.59 % 4.32 % 3.65 % Rate of compensation increase 3.50 % 3.50 % 3.50 % 3.50 % 3.50 % 3.50 % Expected return on plan assets (a) 7.25 % 7.25 % 7.25 % 7.02 % 7.00 % 7.15 % LG&E Discount rate — % 4.33 % 3.65 % Expected return on plan assets (a) — % 7.25 % 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 and LKE) The following table provides the assumed health care cost trend rates for the years ended December 31: 2020 2019 2018 PPL and LKE Health care cost trend rate assumed for next year – obligations 6.5 % 6.6 % 6.6 % – cost 6.6 % 6.6 % 6.6 % Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) – obligations 5.0 % 5.0 % 5.0 % – cost 5.0 % 5.0 % 5.0 % Year that the rate reaches the ultimate trend rate – obligations 2027 2024 2023 – cost 2024 2023 2022
Schedule of Funded Status of Defined Benefit Plans	The funded status of LKE's plans at December 31 was as follows: Pension Benefits Other Postretirement Benefits 2020 2019 2020 2019 Change in Benefit Obligation Benefit Obligation, beginning of period $ 1,684 $ 1,580 $ 208 $ 205 Service cost 24 22 4 4 Interest cost 57 66 7 8 Participant contributions — — 9 7 Plan amendments 2 2 5 — Actuarial (gain) loss (a) 164 166 18 5 Settlements (83) (16) — — Gross benefits paid (63) (136) (22) (21) Benefit Obligation, end of period 1,785 1,684 229 208 Change in Plan Assets Plan assets at fair value, beginning of period 1,470 1,294 141 117 Actual return on plan assets 294 304 28 27 Employer contributions 50 24 4 11 Participant contributions — — 9 7 Settlements (83) (16) — — Gross benefits paid (63) (136) (22) (21) Plan assets at fair value, end of period 1,668 1,470 160 141 Funded Status, end of period $ (117) $ (214) $ (69) $ (67) Amounts recognized in the Balance Sheets consist of: Noncurrent asset $ — $ 24 $ — $ 11 Current liability (5) (5) (2) (2) Noncurrent liability (112) (233) (67) (76) Net amount recognized, end of period $ (117) $ (214) $ (69) $ (67) Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: Prior service cost $ 23 $ 30 $ 14 $ 10 Net actuarial (gain) loss 296 380 (37) (37) Total $ 319 $ 410 $ (23) $ (27) Total accumulated benefit obligation $ 1,657 $ 1,561 (a) The actuarial (gain) loss for all pension plans in 2020 and 2019 was primarily related to changes in the discount rate used to measure the benefit obligations of those plans. The amounts recognized in AOCI and regulatory assets/liabilities at December 31 were as follows: Pension Benefits Other Postretirement Benefits 2020 2019 2020 2019 AOCI $ 127 $ 132 $ 2 $ 4 Regulatory assets/liabilities 192 278 (25) (31) Total $ 319 $ 410 $ (23) $ (27)
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 obligations (ABO) exceed the fair value of plan assets: PBO in excess of plan assets 2020 2019 Projected benefit obligation $ 1,785 $ 1,398 Fair value of plan assets 1,668 1,160 ABO in excess of plan assets 2020 2019 Accumulated benefit obligation $ 104 $ 1,276 Fair value of plan assets — 1,160
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 2020 2020 2019 (a) Target Asset Growth Portfolio 56 % 57 % 55 % Equity securities 34 % 34 % Debt securities (b) 13 % 14 % Alternative investments 9 % 9 % Immunizing Portfolio 43 % 42 % 43 % Debt securities (b) 33 % 35 % Derivatives 10 % 7 % Liquidity Portfolio 1 % 1 % 2 % Total 100 % 100 % 100 % (a) Allocations exclude consideration of a group annuity contract held by the LG&E and KU Retirement Plan. (b) 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, 2020 December 31, 2019 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 $ 300 $ 300 $ — $ — $ 182 $ 182 $ — $ — Equity securities: U.S. Equity 60 60 — — 194 194 — — U.S. Equity fund measured at NAV (a) 742 — — — 451 — — — International equity fund at NAV (a) 566 — — — 554 — — — Commingled debt measured at NAV (a) 712 — — — 621 — — — Debt securities: U.S. Treasury and U.S. government sponsored 336 335 1 — 310 309 1 — Corporate 1,045 — 1,030 15 951 — 931 20 Other 13 — 13 — 14 — 14 — December 31, 2020 December 31, 2019 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Alternative investments: Real estate measured at NAV (a) 76 — — — 88 — — — Private equity measured at NAV (a) 68 — — — 62 — — — Hedge funds measured at NAV (a) 223 — — — 194 — — — Limited Partnerships at NAV (a) 6 — — — — — — — Derivatives (37) — (37) — 3 — 3 — Insurance contracts — — — — 4 — — 4 PPL Services Corporation Master Trust assets, at 4,110 $ 695 $ 1,007 $ 15 3,628 $ 685 $ 949 $ 24 Receivables and payables, net (b) 116 99 401(h) accounts restricted for other (158) (142) Total PPL Services Corporation Master Trust $ 4,068 $ 3,585 (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, 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 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2019 is as follows: Corporate Insurance Total Balance at beginning of period $ 25 $ 21 $ 46 Actual return on plan assets: Relating to assets still held at the reporting date (1) 4 3 Relating to assets sold during the period 3 — 3 Purchases, sales and settlements (7) (21) (28) Balance at end of period $ 20 $ 4 $ 24
Schedule of Fair Value of Financial Assets for U.S. Postretirement Benefits	The fair value of assets in the U.S. other postretirement benefit plans by asset class and level within the fair value hierarchy was: December 31, 2020 December 31, 2019 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 $ 5 $ 5 $ — $ — $ 6 $ 6 $ — $ — U.S. Equity securities: Large-cap equity fund measure at NAV (a) 89 — — — 89 — — — Commingled debt fund measured at NAV (a) 77 — — — 68 — — — Debt securities: Corporate bonds 37 — 37 — 35 — 35 — U.S. Treasury and U.S. government sponsored 2 — 2 — — — — — Total VEBA trust assets, at fair value 210 $ 5 $ 39 $ — 198 $ 6 $ 35 $ — Receivables and payables, net (b) (1) — 401(h) account assets 158 142 Total other postretirement benefit plan assets $ 367 $ 340 (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 LKE. Other Postretirement Pension Benefit Expected 2021 $ 121 $ 15 $ 1 2022 119 16 — 2023 118 16 — 2024 117 16 — 2025 115 16 — 2026-2030 533 75 1
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 years ended December 31. Pension Benefits 2019 (a) 2018 Net periodic defined benefit costs (credits): Service cost $ 1 $ 1 Interest cost 11 12 Expected return on plan assets (21) (22) Amortization of: Prior service cost (credit) 5 5 Actuarial loss (b) 9 7 Net periodic defined benefit costs (credits) (c) $ 5 $ 3 Other Changes in Plan Assets and Benefit Obligations Net (gain) loss $ (19) $ 22 Prior service cost — — Amortization of: Prior service credit (5) (5) Actuarial gain (9) (7) Total recognized in regulatory assets/liabilities (33) 10 Total recognized in net periodic defined benefit costs and regulatory assets $ (28) $ 13 (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 and $2 million in 2018. (c) Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, settlement charges of $5 million in 2019 and $6 million in 2018 were 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.
Schedule of Net Periodic Defined Benefit Costs Included in Income Statement	In the table above, LG&E amounts include costs for the specific plans it sponsors and the following allocated costs of defined benefit plans sponsored by LKE. LG&E 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 LG&E from LKS. These allocations are based on LG&E's participation in those plans, which management believes are reasonable: Pension Benefits Other Postretirement Benefits 2019 (a) 2018 2019 (a) 2018 LG&E Non-Union Only $ — $ 2 $ 2 $ 2
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. The U.K. pension benefits apply to PPL only. Pension Benefits U.S. U.K. Other Postretirement Benefits 2020 2019 2020 2019 2020 2019 PPL Discount rate 2.92 % 3.64 % 1.53 % 1.94 % 2.84 % 3.60 % Rate of compensation increase 3.76 % 3.79 % 3.25 % 3.25 % 3.75 % 3.76 % LKE Discount rate 2.91 % 3.62 % 2.85 % 3.59 % Rate of compensation increase 3.50 % 3.50 % 3.50 % 3.50 % LG&E Discount rate — % 3.60 % The following weighted-average assumptions were used to determine the net periodic defined benefit costs for the years ended December 31. The U.K. pension benefits apply to PPL only. Pension Benefits U.S. U.K. Other Postretirement Benefits 2020 2019 2018 2020 2019 2018 2020 2019 2018 PPL Discount rate service cost 3.64 % 4.35 % 3.70 % 2.03 % 3.12 % 2.73 % 3.60 % 4.31 % 3.64 % Discount rate interest cost 3.64 % 4.35 % 3.70 % 1.73 % 2.62 % 2.31 % 3.60 % 4.31 % 3.64 % Rate of compensation increase 3.79 % 3.79 % 3.78 % 3.25 % 3.50 % 3.50 % 3.76 % 3.76 % 3.75 % Expected return on plan assets 7.25 % 7.25 % 7.25 % 7.13 % 7.21 % 7.23 % 6.44 % 6.46 % 6.40 % LKE Discount rate 3.62 % 4.35 % 3.69 % 3.59 % 4.32 % 3.65 % Rate of compensation increase 3.50 % 3.50 % 3.50 % 3.50 % 3.50 % 3.50 % Expected return on plan assets (a) 7.25 % 7.25 % 7.25 % 7.02 % 7.00 % 7.15 % LG&E Discount rate — % 4.33 % 3.65 % Expected return on plan assets (a) — % 7.25 % 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	(LG&E) The funded status of LG&E's plan at December 31, was as follows: Pension Benefits 2019 (a) Change in Benefit Obligation Benefit Obligation, beginning of period $ 285 Service cost 1 Interest cost 11 Actuarial (gain) loss 25 Gross benefits paid (36) Benefit Obligation, end of period 286 Change in Plan Assets Plan assets at fair value, beginning of period 281 Actual return on plan assets 64 Employer contributions 1 Gross benefits paid (36) Plan assets at fair value, end of period 310 Funded Status, end of period $ 24 Amounts recognized in the Balance Sheets consist of: Noncurrent asset (liability) $ 24 Net amount recognized, end of period $ 24 Amounts recognized in regulatory assets (pre-tax) consist of: Prior service cost $ 17 Net actuarial loss 79 Total $ 96 Total accumulated benefit obligation for defined benefit pension plan $ 286 (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. 2020 2019 Pension $ (78) $ (7) Other postretirement benefits 68 63
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 2020 2020 2019 (a) Target Asset Growth Portfolio 56 % 57 % 55 % Equity securities 34 % 34 % Debt securities (b) 13 % 14 % Alternative investments 9 % 9 % Immunizing Portfolio 43 % 42 % 43 % Debt securities (b) 33 % 35 % Derivatives 10 % 7 % Liquidity Portfolio 1 % 1 % 2 % Total 100 % 100 % 100 % (a) Allocations exclude consideration of a group annuity contract held by the LG&E and KU Retirement Plan. (b) 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, 2020 December 31, 2019 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 $ 300 $ 300 $ — $ — $ 182 $ 182 $ — $ — Equity securities: U.S. Equity 60 60 — — 194 194 — — U.S. Equity fund measured at NAV (a) 742 — — — 451 — — — International equity fund at NAV (a) 566 — — — 554 — — — Commingled debt measured at NAV (a) 712 — — — 621 — — — Debt securities: U.S. Treasury and U.S. government sponsored 336 335 1 — 310 309 1 — Corporate 1,045 — 1,030 15 951 — 931 20 Other 13 — 13 — 14 — 14 — December 31, 2020 December 31, 2019 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Alternative investments: Real estate measured at NAV (a) 76 — — — 88 — — — Private equity measured at NAV (a) 68 — — — 62 — — — Hedge funds measured at NAV (a) 223 — — — 194 — — — Limited Partnerships at NAV (a) 6 — — — — — — — Derivatives (37) — (37) — 3 — 3 — Insurance contracts — — — — 4 — — 4 PPL Services Corporation Master Trust assets, at 4,110 $ 695 $ 1,007 $ 15 3,628 $ 685 $ 949 $ 24 Receivables and payables, net (b) 116 99 401(h) accounts restricted for other (158) (142) Total PPL Services Corporation Master Trust $ 4,068 $ 3,585 (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, 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 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2019 is as follows: Corporate Insurance Total Balance at beginning of period $ 25 $ 21 $ 46 Actual return on plan assets: Relating to assets still held at the reporting date (1) 4 3 Relating to assets sold during the period 3 — 3 Purchases, sales and settlements (7) (21) (28) Balance at end of period $ 20 $ 4 $ 24
Schedule of Fair Value of Financial Assets for U.S. Postretirement Benefits	The fair value of assets in the U.S. other postretirement benefit plans by asset class and level within the fair value hierarchy was: December 31, 2020 December 31, 2019 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 $ 5 $ 5 $ — $ — $ 6 $ 6 $ — $ — U.S. Equity securities: Large-cap equity fund measure at NAV (a) 89 — — — 89 — — — Commingled debt fund measured at NAV (a) 77 — — — 68 — — — Debt securities: Corporate bonds 37 — 37 — 35 — 35 — U.S. Treasury and U.S. government sponsored 2 — 2 — — — — — Total VEBA trust assets, at fair value 210 $ 5 $ 39 $ — 198 $ 6 $ 35 $ — Receivables and payables, net (b) (1) — 401(h) account assets 158 142 Total other postretirement benefit plan assets $ 367 $ 340
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. 2020 2019 Pension $ (62) $ (31) Other postretirement benefits 16 16

Jointly Owned Utility Facilitie

Jointly Owned Utility Facilities (Tables)	12 Months Ended
	Dec. 31, 2020
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2020 and 2019, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL and LKE December 31, 2020 Trimble County Unit 1 75.00 % $ 440 $ 64 $ 2 Trimble County Unit 2 75.00 % 1,340 227 106 December 31, 2019 Trimble County Unit 1 75.00 % $ 440 $ 54 $ 2 Trimble County Unit 2 75.00 % 1,278 203 134 LG&E 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 — — December 31, 2019 E.W. Brown Units 6-7 38.00 % $ 45 $ 20 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 20 — Trimble County Unit 1 75.00 % 440 54 2 Trimble County Unit 2 14.25 % 340 43 69 Trimble County Units 5-6 29.00 % 32 12 — Trimble County Units 7-10 37.00 % 78 27 — Cane Run Unit 7 22.00 % 119 13 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 1 — — KU 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 — — December 31, 2019 E.W. Brown Units 6-7 62.00 % $ 75 $ 32 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 14 — Trimble County Unit 2 60.75 % 938 160 65 Trimble County Units 5-6 71.00 % 76 29 — Trimble County Units 7-10 63.00 % 128 46 — Cane Run Unit 7 78.00 % 429 49 1 E.W. Brown Solar Unit 61.00 % 16 2 — Solar Share 56.00 % 2 — —
LG And E And KU Energy LLC [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2020 and 2019, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL and LKE December 31, 2020 Trimble County Unit 1 75.00 % $ 440 $ 64 $ 2 Trimble County Unit 2 75.00 % 1,340 227 106 December 31, 2019 Trimble County Unit 1 75.00 % $ 440 $ 54 $ 2 Trimble County Unit 2 75.00 % 1,278 203 134 LG&E 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 — — December 31, 2019 E.W. Brown Units 6-7 38.00 % $ 45 $ 20 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 20 — Trimble County Unit 1 75.00 % 440 54 2 Trimble County Unit 2 14.25 % 340 43 69 Trimble County Units 5-6 29.00 % 32 12 — Trimble County Units 7-10 37.00 % 78 27 — Cane Run Unit 7 22.00 % 119 13 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 1 — — KU 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 — — December 31, 2019 E.W. Brown Units 6-7 62.00 % $ 75 $ 32 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 14 — Trimble County Unit 2 60.75 % 938 160 65 Trimble County Units 5-6 71.00 % 76 29 — Trimble County Units 7-10 63.00 % 128 46 — Cane Run Unit 7 78.00 % 429 49 1 E.W. Brown Solar Unit 61.00 % 16 2 — Solar Share 56.00 % 2 — —
Louisville Gas And Electric Co [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2020 and 2019, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL and LKE December 31, 2020 Trimble County Unit 1 75.00 % $ 440 $ 64 $ 2 Trimble County Unit 2 75.00 % 1,340 227 106 December 31, 2019 Trimble County Unit 1 75.00 % $ 440 $ 54 $ 2 Trimble County Unit 2 75.00 % 1,278 203 134 LG&E 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 — — December 31, 2019 E.W. Brown Units 6-7 38.00 % $ 45 $ 20 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 20 — Trimble County Unit 1 75.00 % 440 54 2 Trimble County Unit 2 14.25 % 340 43 69 Trimble County Units 5-6 29.00 % 32 12 — Trimble County Units 7-10 37.00 % 78 27 — Cane Run Unit 7 22.00 % 119 13 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 1 — — KU 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 — — December 31, 2019 E.W. Brown Units 6-7 62.00 % $ 75 $ 32 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 14 — Trimble County Unit 2 60.75 % 938 160 65 Trimble County Units 5-6 71.00 % 76 29 — Trimble County Units 7-10 63.00 % 128 46 — Cane Run Unit 7 78.00 % 429 49 1 E.W. Brown Solar Unit 61.00 % 16 2 — Solar Share 56.00 % 2 — —
Kentucky Utilities Co [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2020 and 2019, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL and LKE December 31, 2020 Trimble County Unit 1 75.00 % $ 440 $ 64 $ 2 Trimble County Unit 2 75.00 % 1,340 227 106 December 31, 2019 Trimble County Unit 1 75.00 % $ 440 $ 54 $ 2 Trimble County Unit 2 75.00 % 1,278 203 134 LG&E 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 — — December 31, 2019 E.W. Brown Units 6-7 38.00 % $ 45 $ 20 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 20 — Trimble County Unit 1 75.00 % 440 54 2 Trimble County Unit 2 14.25 % 340 43 69 Trimble County Units 5-6 29.00 % 32 12 — Trimble County Units 7-10 37.00 % 78 27 — Cane Run Unit 7 22.00 % 119 13 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 1 — — KU 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 — — December 31, 2019 E.W. Brown Units 6-7 62.00 % $ 75 $ 32 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 14 — Trimble County Unit 2 60.75 % 938 160 65 Trimble County Units 5-6 71.00 % 76 29 — Trimble County Units 7-10 63.00 % 128 46 — Cane Run Unit 7 78.00 % 429 49 1 E.W. Brown Solar Unit 61.00 % 16 2 — Solar Share 56.00 % 2 — —

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2020
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 2023 Natural Gas Retail Supply 2022 Coal 2024 Coal Transportation and Fleeting Services 2027 Natural Gas Transportation 2026 LG&E KU Total 2021 $ 23 $ 11 $ 34 2022 23 11 34 2023 24 10 34 2024 22 10 32 2025 22 10 32 Thereafter 250 109 359 Total $ 364 $ 161 $ 525 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2020 2019 2018 LG&E $ 12 $ 15 $ 14 KU 6 7 6 Total $ 18 $ 22 $ 20
Guarantees	The table below details guarantees provided as of December 31, 2020. Exposure at December 31, 2020 Expiration PPL WPD indemnifications for entities in liquidation and sales of assets $ 11 (a) 2022 WPD guarantee of pension and other obligations of unconsolidated entities 95 (b) LKE Indemnification of lease termination and other divestitures 200 (c) 2021 LG&E and KU LG&E and KU obligation of shortfall related to OVEC (d) (a) Indemnification to the liquidators and certain others for existing liabilities or expenses or liabilities arising during the liquidation process. The indemnifications are limited to distributions made from the subsidiary to its parent either prior or subsequent to liquidation or are not explicitly stated in the agreements. The indemnifications generally expire two to seven years subsequent to the date of dissolution of the entities. The exposure noted only includes those cases where the agreements provide for specific limits. In connection with their sales of various businesses, WPD and its affiliates have provided the purchasers with indemnifications that are standard for such transactions, including indemnifications for certain pre-existing liabilities and environmental and tax matters or have agreed to continue their obligations under existing third-party guarantees, either for a set period of time following the transactions or upon the condition that the purchasers make reasonable efforts to terminate the guarantees. Additionally, WPD and its affiliates remain secondarily responsible for lease payments under certain leases that they have assigned to third parties. (b) Relates to certain obligations of discontinued or modified electric associations that were guaranteed at the time of privatization by the participating members. Costs are allocated to the members and can be reallocated if an existing member becomes insolvent. At December 31, 2020, WPD has recorded an estimated discounted liability for which the expected payment/performance is probable. Neither the expiration date nor the maximum amount of potential payments for certain obligations is explicitly stated in the related agreements, and as a result, the exposure has been estimated. (c) LKE provides certain indemnifications covering the due and punctual payment, performance and discharge by each party of its respective obligations. The most comprehensive of these guarantees is the LKE guarantee covering operational, regulatory and environmental commitments and indemnifications made by WKE under a 2009 Transaction Termination Agreement. This guarantee has a term of 12 years ending July 2021, and a maximum exposure of $200 million, exclusive of certain items such as government fines and penalties that may exceed the maximum. Additionally, LKE has indemnified various third parties related to historical obligations for other divested subsidiaries and affiliates. The indemnifications vary by entity and the maximum exposures range from being capped at the sale price to no specified maximum. LKE could be required to perform on these indemnifications in the event of covered losses or liabilities being claimed by an indemnified party. LKE cannot predict the ultimate outcomes of the various indemnification scenarios, but does not expect such outcomes to result in significant losses above the amounts recorded. (d) 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. LKE's proportionate share of OVEC's outstanding debt was $104 million at December 31, 2020, consisting of LG&E's share of $72 million and KU's share of $32 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.
LG And E And KU Energy LLC [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 2023 Natural Gas Retail Supply 2022 Coal 2024 Coal Transportation and Fleeting Services 2027 Natural Gas Transportation 2026 LG&E KU Total 2021 $ 23 $ 11 $ 34 2022 23 11 34 2023 24 10 34 2024 22 10 32 2025 22 10 32 Thereafter 250 109 359 Total $ 364 $ 161 $ 525 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2020 2019 2018 LG&E $ 12 $ 15 $ 14 KU 6 7 6 Total $ 18 $ 22 $ 20
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 2023 Natural Gas Retail Supply 2022 Coal 2024 Coal Transportation and Fleeting Services 2027 Natural Gas Transportation 2026 LG&E KU Total 2021 $ 23 $ 11 $ 34 2022 23 11 34 2023 24 10 34 2024 22 10 32 2025 22 10 32 Thereafter 250 109 359 Total $ 364 $ 161 $ 525 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2020 2019 2018 LG&E $ 12 $ 15 $ 14 KU 6 7 6 Total $ 18 $ 22 $ 20
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 2023 Natural Gas Retail Supply 2022 Coal 2024 Coal Transportation and Fleeting Services 2027 Natural Gas Transportation 2026 LG&E KU Total 2021 $ 23 $ 11 $ 34 2022 23 11 34 2023 24 10 34 2024 22 10 32 2025 22 10 32 Thereafter 250 109 359 Total $ 364 $ 161 $ 525 LG&E and KU had total energy purchases under the OVEC power purchase agreement for the years ended December 31 as follows: 2020 2019 2018 LG&E $ 12 $ 15 $ 14 KU 6 7 6 Total $ 18 $ 22 $ 20

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2020
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. 2020 2019 2018 PPL Electric from PPL Services $ 50 $ 59 $ 59 LKE from PPL Services 27 28 26 PPL Electric from PPL EU Services 176 152 148 LG&E from LKS 170 160 151 KU from LKS 180 178 169
LG And E And KU Energy LLC [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. 2020 2019 2018 PPL Electric from PPL Services $ 50 $ 59 $ 59 LKE from PPL Services 27 28 26 PPL Electric from PPL EU Services 176 152 148 LG&E from LKS 170 160 151 KU from LKS 180 178 169
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. 2020 2019 2018 PPL Electric from PPL Services $ 50 $ 59 $ 59 LKE from PPL Services 27 28 26 PPL Electric from PPL EU Services 176 152 148 LG&E from LKS 170 160 151 KU from LKS 180 178 169
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. 2020 2019 2018 PPL Electric from PPL Services $ 50 $ 59 $ 59 LKE from PPL Services 27 28 26 PPL Electric from PPL EU Services 176 152 148 LG&E from LKS 170 160 151 KU from LKS 180 178 169

Other Income (Expense) - net (T

Other Income (Expense) - net (Tables)	12 Months Ended
	Dec. 31, 2020
Other Income (Expense) Net [Line Items]
Other Income (Expense) - net	The components of "Other Income (Expense) - net" for the years ended December 31, were: 2020 2019 2018 Other Income Economic foreign currency exchange contracts (Note 18) $ (98) $ (14) $ 150 Defined benefit plans - non-service credits (Note 12) 262 316 257 Interest income 10 16 6 AFUDC - equity component 20 23 21 Miscellaneous 7 7 6 Total Other Income 201 348 440 Other Expense Charitable contributions 3 17 24 Miscellaneous 29 22 20 Total Other Expense 32 39 44 Other Income (Expense) - net $ 169 $ 309 $ 396
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: 2020 2019 2018 Other Income Defined benefit plans - non-service credits (Note 12) $ 4 $ 4 $ 5 Interest income 2 2 2 AFUDC - equity component 19 23 20 Total Other Income 25 29 27 Other Expense Charitable contributions 3 3 3 Miscellaneous 4 1 1 Total Other Expense 7 4 4 Other Income (Expense) - net $ 18 $ 25 $ 23

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2020
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, 2020 December 31, 2019 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 708 $ 708 $ — $ — $ 815 $ 815 $ — $ — Restricted cash and cash equivalents (a) 19 19 — — 21 21 — — Special use funds (a): Commingled debt fund measured at NAV (b) 26 — — — 29 — — — Commingled equity fund measured at NAV (b) 25 — — — 27 — — — Total special use funds 51 — — — 56 — — — Price risk management assets (c): Foreign currency contracts — — — — 142 — 142 — Cross-currency swaps 146 — 146 — 154 — 154 — Total price risk management assets 146 — 146 — 296 — 296 — Total assets $ 924 $ 727 $ 146 $ — $ 1,188 $ 836 $ 296 $ — Liabilities Price risk management liabilities (c): Interest rate swaps $ 23 $ — $ 23 $ — $ 21 $ — $ 21 $ — Foreign currency contracts 137 — 137 — 5 — 5 — Total price risk management liabilities $ 160 $ — $ 160 $ — $ 26 $ — $ 26 $ — December 31, 2020 December 31, 2019 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Electric Assets Cash and cash equivalents $ 40 $ 40 $ — $ — $ 262 $ 262 $ — $ — Restricted cash and cash equivalents (a) — — — — 2 2 — — Total assets $ 40 $ 40 $ — $ — $ 264 $ 264 $ — $ — LKE Assets Cash and cash equivalents $ 29 $ 29 $ — $ — $ 27 $ 27 $ — $ — Total assets $ 29 $ 29 $ — $ — $ 27 $ 27 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 23 $ — $ 23 $ — $ 21 $ — $ 21 $ — Total price risk management liabilities $ 23 $ — $ 23 $ — $ 21 $ — $ 21 $ — LG&E Assets Cash and cash equivalents $ 7 $ 7 $ — $ — $ 15 $ 15 $ — $ — Total assets $ 7 $ 7 $ — $ — $ 15 $ 15 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 23 $ — $ 23 $ — $ 21 $ — $ 21 $ — Total price risk management liabilities $ 23 $ — $ 23 $ — $ 21 $ — $ 21 $ — KU Assets Cash and cash equivalents $ 22 $ 22 $ — $ — $ 12 $ 12 $ — $ — Total assets $ 22 $ 22 $ — $ — $ 12 $ 12 $ — $ — (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 "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.
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, 2020 December 31, 2019 Carrying Fair Value Carrying Fair Value PPL $ 23,127 $ 28,765 $ 21,893 $ 25,481 PPL Electric 4,236 5,338 3,985 4,589 LKE 6,074 7,589 6,002 6,766 LG&E 2,007 2,499 2,005 2,278 KU 2,618 3,334 2,623 3,003 (a) Amounts are net of debt issuance costs.

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2020
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, 2020 December 31, 2019 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) $ — $ — $ — $ 2 $ — $ — $ — $ 4 Cross-currency swaps (b) 94 — — — 5 — — — Foreign currency contracts — — — 137 — — 142 5 Total current 94 — — 139 5 — 142 9 Noncurrent: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) — — — 21 — — — 17 Cross-currency swaps (b) 52 — — — 149 — — — Total noncurrent 52 — — 21 149 — — 17 Total derivatives $ 146 $ — $ — $ 160 $ 154 $ — $ 142 $ 26 (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.
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 2020 Cash Flow Hedges: Interest rate swaps $ (9) Interest Expense $ (10) Cross-currency swaps (15) Other Income (Expense) - net (22) Total $ (24) $ (32) Net Investment Hedges: Foreign currency contracts $ 1 2019 Cash Flow Hedges: Interest rate swaps $ (30) Interest Expense $ (9) Cross-currency swaps 17 Other Income (Expense) - net (9) Total $ (13) $ (18) Net Investment Hedges: Foreign currency contracts $ 2 2018 Cash Flow Hedges: Interest rate swaps $ 4 Interest Expense $ (8) Cross-currency swaps 41 Other Income (Expense) - net 42 Interest Expense 1 Total $ 45 $ 35 Net Investment Hedges: Foreign currency contracts $ 11 Derivatives Not Designated as Location of Gain (Loss) Recognized in 2020 2019 2018 Foreign currency contracts Other Income (Expense) - net $ (98) $ (14) $ 150 Interest rate swaps Interest Expense (5) (5) (5) Total $ (103) $ (19) $ 145 Derivatives Not Designated as Location of Gain (Loss) Recognized as 2020 2019 2018 Interest rate swaps Regulatory assets - noncurrent $ (2) $ (1) $ 6 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 Other Income (Expense) - net Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 1,001 $ 169 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 (10) — 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 Other Income (Expense) - net Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 994 $ 309 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, 2020 Treasury Derivatives PPL $ 146 $ 34 $ — $ 112 $ 160 $ 34 $ — $ 126 LKE — — — — 23 — — 23 LG&E — — — — 23 — — 23 December 31, 2019 Treasury Derivatives PPL $ 296 $ 5 $ 14 $ 277 $ 26 $ 5 $ — $ 21 LKE — — — — 21 — — 21 LG&E — — — — 21 — — 21
Credit Risk-Related Contingent Features	At December 31, 2020, 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 are summarized as follows: PPL Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features $ 102 Aggregate fair value of collateral posted on these derivative instruments — Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a) 102 (a) Includes the effect of net receivables and payables already recorded on the Balance Sheet.
LG And E And KU Energy LLC [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, 2020 December 31, 2019 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ 2 $ — $ 4 Total current — 2 — 4 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 21 — 17 Total noncurrent — 21 — 17 Total derivatives $ — $ 23 $ — $ 21
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) 2020 2019 2018 Interest rate swaps Interest Expense $ (5) $ (5) $ (5) Derivative Instruments Location of Gain (Loss) 2020 2019 2018 Interest rate swaps Regulatory assets - noncurrent $ (2) $ (1) $ 6
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, 2020 Treasury Derivatives PPL $ 146 $ 34 $ — $ 112 $ 160 $ 34 $ — $ 126 LKE — — — — 23 — — 23 LG&E — — — — 23 — — 23 December 31, 2019 Treasury Derivatives PPL $ 296 $ 5 $ 14 $ 277 $ 26 $ 5 $ — $ 21 LKE — — — — 21 — — 21 LG&E — — — — 21 — — 21
Credit Risk-Related Contingent Features	At December 31, 2020, 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 are summarized as follows: PPL Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features $ 102 Aggregate fair value of collateral posted on these derivative instruments — Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a) 102 (a) Includes the effect of net receivables and payables already recorded on the Balance Sheet.
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, 2020 December 31, 2019 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ 2 $ — $ 4 Total current — 2 — 4 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 21 — 17 Total noncurrent — 21 — 17 Total derivatives $ — $ 23 $ — $ 21
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) 2020 2019 2018 Interest rate swaps Interest Expense $ (5) $ (5) $ (5) Derivative Instruments Location of Gain (Loss) 2020 2019 2018 Interest rate swaps Regulatory assets - noncurrent $ (2) $ (1) $ 6
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, 2020 Treasury Derivatives PPL $ 146 $ 34 $ — $ 112 $ 160 $ 34 $ — $ 126 LKE — — — — 23 — — 23 LG&E — — — — 23 — — 23 December 31, 2019 Treasury Derivatives PPL $ 296 $ 5 $ 14 $ 277 $ 26 $ 5 $ — $ 21 LKE — — — — 21 — — 21 LG&E — — — — 21 — — 21
Credit Risk-Related Contingent Features	At December 31, 2020, 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 are summarized as follows: PPL Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features $ 102 Aggregate fair value of collateral posted on these derivative instruments — Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a) 102 (a) Includes the effect of net receivables and payables already recorded on the Balance Sheet.
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, 2020 Treasury Derivatives PPL $ 146 $ 34 $ — $ 112 $ 160 $ 34 $ — $ 126 LKE — — — — 23 — — 23 LG&E — — — — 23 — — 23 December 31, 2019 Treasury Derivatives PPL $ 296 $ 5 $ 14 $ 277 $ 26 $ 5 $ — $ 21 LKE — — — — 21 — — 21 LG&E — — — — 21 — — 21

Goodwill and Other Intangible_2

Goodwill and Other Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2020
Goodwill and Other Intangible Assets [Line Items]
Goodwill Rollforward	The changes in the carrying amount of goodwill by segment were: U.K. Kentucky Corporate and Total 2020 2019 2020 2019 2020 2019 2020 2019 Balance at beginning of period (a) $ 2,483 $ 2,447 $ 662 $ 662 $ 53 $ 53 $ 3,198 $ 3,162 Effect of foreign currency exchange rates 76 34 — — — — 76 34 Other — 2 — — — — — 2 Balance at end of period (a) $ 2,559 $ 2,483 $ 662 $ 662 $ 53 $ 53 $ 3,274 $ 3,198 (a) There were no accumulated impairment losses related to goodwill.
Other Intangible Assets	The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2020 December 31, 2019 Gross Accumulated Gross Accumulated Subject to amortization: Contracts (a) $ 136 $ 93 $ 136 $ 84 Land rights and easements 460 142 440 135 Licenses and other 21 4 22 3 Total subject to amortization 617 239 598 222 Not subject to amortization due to indefinite life: Land rights and easements 380 — 361 — Other 6 — 6 — Total not subject to amortization due to indefinite life 386 — 367 — Total $ 1,003 $ 239 $ 965 $ 222 (a) Gross carrying amount in 2020 and 2019 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: 2020 2019 2018 Intangible assets with no regulatory offset $ 11 $ 9 $ 7 Intangible assets with regulatory offset 8 9 8 Total $ 19 $ 18 $ 15
Future Amortization Expense	Amortization expense for each of the next five years is estimated to be: 2021 2022 2023 2024 2025 Intangible assets with no regulatory offset $ 11 $ 11 $ 11 $ 11 $ 11 Intangible assets with regulatory offset 8 8 8 8 8 Total $ 19 $ 19 $ 19 $ 19 $ 19
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, 2020 December 31, 2019 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 379 $ 129 $ 370 $ 125 Licenses and other 2 1 3 1 Total subject to amortization 381 130 373 126 Not subject to amortization due to indefinite life: Land rights and easements 17 — 17 — Total $ 398 $ 130 $ 390 $ 126
Amortization Expense, Excluding Consumption of Emission Allowances / Renewable Energy Credits	Amortization expense was as follows: 2020 2019 2018 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: 2021 2022 2023 2024 2025 Intangible assets with no regulatory offset $ 4 $ 4 $ 4 $ 4 $ 4
LG And E And KU Energy LLC [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, 2020 December 31, 2019 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 22 $ 4 $ 22 $ 4 OVEC power purchase agreement (a) 125 82 125 74 Total subject to amortization $ 147 $ 86 $ 147 $ 78 (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: 2020 2019 2018 Intangible assets with regulatory offset $ 8 $ 9 $ 8
Future Amortization Expense	Amortization expense for each of the next five years is estimated to be: 2021 2022 2023 2024 2025 Intangible assets with regulatory offset $ 8 $ 8 $ 8 $ 8 $ 8
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, 2020 December 31, 2019 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 7 $ 1 $ 7 $ 1 OVEC power purchase agreement (a) 86 57 86 51 Total subject to amortization $ 93 $ 58 $ 93 $ 52 (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: 2020 2019 2018 Intangible assets with regulatory offset $ 6 $ 6 $ 6
Future Amortization Expense	Amortization expense for each of the next five years is estimated to be: 2021 2022 2023 2024 2025 Intangible assets with regulatory offset $ 6 $ 6 $ 6 $ 6 $ 6
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, 2020 December 31, 2019 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 15 $ 3 $ 15 $ 3 OVEC power purchase agreement (a) 39 25 39 23 Total subject to amortization $ 54 $ 28 $ 54 $ 26 (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: 2020 2019 2018 Intangible assets with regulatory offset $ 2 $ 3 $ 2
Future Amortization Expense	Amortization expense for each of the next five years is estimated to be: 2021 2022 2023 2024 2025 Intangible assets with regulatory offset $ 2 $ 2 $ 2 $ 2 $ 2

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2020
Asset Retirement Obligation [Line Items]
Asset Retirement Obligation Roll Forward	The changes in the carrying amounts of AROs were as follows: PPL LKE LG&E KU 2020 2019 2020 2019 2020 2019 2020 2019 ARO at beginning of period $ 282 $ 347 $ 215 $ 296 $ 73 $ 103 $ 142 $ 193 Accretion 17 19 15 17 5 6 10 11 Obligations incurred — — — — — — — — Changes in estimated timing or cost 38 12 40 (2) 13 (2) 27 — Effect of foreign currency exchange rates 1 — — — — — — — Obligations settled (88) (96) (88) (96) (24) (34) (64) (62) ARO at end of period $ 250 $ 282 $ 182 $ 215 $ 67 $ 73 $ 115 $ 142
LG And E And KU Energy LLC [Member]
Asset Retirement Obligation [Line Items]
Asset Retirement Obligation Roll Forward	The changes in the carrying amounts of AROs were as follows: PPL LKE LG&E KU 2020 2019 2020 2019 2020 2019 2020 2019 ARO at beginning of period $ 282 $ 347 $ 215 $ 296 $ 73 $ 103 $ 142 $ 193 Accretion 17 19 15 17 5 6 10 11 Obligations incurred — — — — — — — — Changes in estimated timing or cost 38 12 40 (2) 13 (2) 27 — Effect of foreign currency exchange rates 1 — — — — — — — Obligations settled (88) (96) (88) (96) (24) (34) (64) (62) ARO at end of period $ 250 $ 282 $ 182 $ 215 $ 67 $ 73 $ 115 $ 142
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 LKE LG&E KU 2020 2019 2020 2019 2020 2019 2020 2019 ARO at beginning of period $ 282 $ 347 $ 215 $ 296 $ 73 $ 103 $ 142 $ 193 Accretion 17 19 15 17 5 6 10 11 Obligations incurred — — — — — — — — Changes in estimated timing or cost 38 12 40 (2) 13 (2) 27 — Effect of foreign currency exchange rates 1 — — — — — — — Obligations settled (88) (96) (88) (96) (24) (34) (64) (62) ARO at end of period $ 250 $ 282 $ 182 $ 215 $ 67 $ 73 $ 115 $ 142
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 LKE LG&E KU 2020 2019 2020 2019 2020 2019 2020 2019 ARO at beginning of period $ 282 $ 347 $ 215 $ 296 $ 73 $ 103 $ 142 $ 193 Accretion 17 19 15 17 5 6 10 11 Obligations incurred — — — — — — — — Changes in estimated timing or cost 38 12 40 (2) 13 (2) 27 — Effect of foreign currency exchange rates 1 — — — — — — — Obligations settled (88) (96) (88) (96) (24) (34) (64) (62) ARO at end of period $ 250 $ 282 $ 182 $ 215 $ 67 $ 73 $ 115 $ 142

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Income (Loss) (Tables)	12 Months Ended
	Dec. 31, 2020
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 (b) Foreign Unrealized gains (losses) on Prior Actuarial Total PPL December 31, 2017 $ (1,089) $ (13) $ (7) $ (2,313) $ (3,422) Amounts arising during the year (444) 36 (11) (187) (606) Reclassifications from AOCI — (29) 2 142 115 Net OCI during the year (444) 7 (9) (45) (491) Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment $ — $ (1) $ (3) $ (47) (51) Defined benefit plans (b) Foreign Unrealized gains (losses) on Prior Actuarial Total 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) LKE December 31, 2017 $ (9) $ (79) $ (88) Amounts arising during the year — 7 7 Reclassifications from AOCI 2 8 10 Net OCI during the year 2 15 17 Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment (Note 1) (2) (16) (18) December 31, 2018 $ (9) $ (80) $ (89) Amounts arising during the year (1) (6) (7) Reclassifications from AOCI 1 2 3 Net OCI during the year — (4) (4) December 31, 2019 $ (9) $ (84) $ (93) Amounts arising during the year (1) (7) (8) Reclassifications from AOCI 2 13 15 Net OCI during the year 1 6 7 December 31, 2020 $ (8) $ (78) $ (86) (a) Amounts relate to the operations of WPD. (b) For PPL, substantially all of the amounts relate to WPD's pension plans. At December 31, 2020, the combined accumulated other comprehensive loss related to these plans was $2.9 billion.
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, 2020, 2019 and 2018. PPL Details about AOCI 2020 2019 2018 Affected Line Item on the Qualifying derivatives Interest rate swaps $ (10) $ (9) $ (8) Interest Expense Cross-currency swaps (22) (9) 42 Other Income (Expense) - net — — 1 Interest Expense Total Pre-tax (32) (18) 35 Income Taxes 8 5 (6) Total After-tax (24) (13) 29 Defined benefit plans Prior service costs (4) (3) (2) Net actuarial loss (256) (109) (178) Total Pre-tax (260) (112) (180) Income Taxes 52 23 36 Total After-tax (208) (89) (144) Total reclassifications during the year $ (232) $ (102) $ (115)
LG And E And KU Energy LLC [Member]
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 (b) Foreign Unrealized gains (losses) on Prior Actuarial Total PPL December 31, 2017 $ (1,089) $ (13) $ (7) $ (2,313) $ (3,422) Amounts arising during the year (444) 36 (11) (187) (606) Reclassifications from AOCI — (29) 2 142 115 Net OCI during the year (444) 7 (9) (45) (491) Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment $ — $ (1) $ (3) $ (47) (51) Defined benefit plans (b) Foreign Unrealized gains (losses) on Prior Actuarial Total 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) LKE December 31, 2017 $ (9) $ (79) $ (88) Amounts arising during the year — 7 7 Reclassifications from AOCI 2 8 10 Net OCI during the year 2 15 17 Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment (Note 1) (2) (16) (18) December 31, 2018 $ (9) $ (80) $ (89) Amounts arising during the year (1) (6) (7) Reclassifications from AOCI 1 2 3 Net OCI during the year — (4) (4) December 31, 2019 $ (9) $ (84) $ (93) Amounts arising during the year (1) (7) (8) Reclassifications from AOCI 2 13 15 Net OCI during the year 1 6 7 December 31, 2020 $ (8) $ (78) $ (86) (a) Amounts relate to the operations of WPD. (b) For PPL, substantially all of the amounts relate to WPD's pension plans. At December 31, 2020, the combined accumulated other comprehensive loss related to these plans was $2.9 billion.

Summary of Significant Accoun_4

Summary of Significant Accounting Policies (Details) - Allowance For Doubtful Accounts [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount	$ 75	$ 58	$ 56	$ 51
Additions charged to income	31	37	41
Additions charged to other accounts	0	3	3
Deductions	16	38	39
SEC Schedule, 12-09, Valuation Allowances and Reserves, Adjusted for CECL, Amount		60
PPL Electric Utilities Corp [Member]
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount	41	28	27	$ 24
Additions charged to income	19	26	29
Additions charged to other accounts	0	0	0
Deductions	$ 8	25	$ 26
SEC Schedule, 12-09, Valuation Allowances and Reserves, Adjusted for CECL, Amount		$ 30

Accounting Policies (Details)

Accounting Policies (Details) $ in Millions	12 Months Ended
	Dec. 31, 2020USD ($)Integer	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Mar. 31, 2020USD ($)	Dec. 31, 2017USD ($)
Utility Revenue (Details) [Abstract]
Operating Revenues	$ 7,607	$ 7,769	$ 7,785
Restricted Cash and Cash Equivalents [Abstract]
Cash and cash equivalents	708	815
Restricted cash - current	1	3
Restricted Cash - noncurrent	18	18
Total Cash, Cash Equivalents and Restricted Cash	727	836	643		$ 511
Property, Plant and Equipment (Numeric) [Abstract]
Interest costs, capitalized during the period	$ 9	10	15
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	$ 361	332
Balance Sheet Classification of Deferred Taxes [Abstract]
Goodwill	3,274	3,198	$ 3,162
Fuel [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	95	106
Natural Gas Stored Underground [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	30	35
Material And Supplies [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	$ 236	$ 191
Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates	2.81%	2.84%	2.77%
Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period	$ 58	$ 56	$ 51
Additions charged to income	31	37	41
Additions charged to other accounts	0	3	3
Deductions	16	38	39
Balance at end of period	$ 75	58	56
WPD [Member]
Summary of Significant Accounting Policies [Line Items]
Period of lag in reporting results for WPD (in months) | Integer	1
Revenue Recognition (Numeric) [Abstract]
Number of regulatory years later future demand revenue is affected	2 years
Percentage WPD's distribution network operators are able to retain of any under-spends	70.00%
Percentage WPD's distribution network operators bear of any over-spends	70.00%
Period of lag between incentives and penalties are reflected in customers' rates	2 years
Refunded/recovered period of lag for recovery of over and under-recovered amounts arising from 2014/15 onwards	2 years
Balance Sheet Classification of Deferred Taxes [Abstract]
Goodwill				$ 2,500
PPL Electric Utilities Corp [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues	$ 2,331	2,358	2,277
Restricted Cash and Cash Equivalents [Abstract]
Cash and cash equivalents	40	262
Restricted cash - current	0	2
Restricted Cash - noncurrent	0	0
Total Cash, Cash Equivalents and Restricted Cash	40	264	269		51
Property, Plant and Equipment (Numeric) [Abstract]
Interest costs, capitalized during the period	$ 7	8	$ 7
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)	$ (9)	3
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	59	33
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	$ 59	$ 33
PPL Electric Utilities Corp [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates	2.99%	3.05%	3.01%
PPL Electric Utilities Corp [Member] | Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period	$ 28	$ 27	$ 24
Additions charged to income	19	26	29
Additions charged to other accounts	0	0	0
Deductions	8	25	26
Balance at end of period	41	28	27
LG And E And KU Energy LLC [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues	3,106	3,206	3,214
Restricted Cash and Cash Equivalents [Abstract]
Cash and cash equivalents	$ 29	27	$ 24		30
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)	$ (12)	(8)
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	242	250
Balance Sheet Classification of Deferred Taxes [Abstract]
Goodwill	996	996
LG And E And KU Energy LLC [Member] | Fuel [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	95	106
LG And E And KU Energy LLC [Member] | Natural Gas Stored Underground [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	30	35
LG And E And KU Energy LLC [Member] | Material And Supplies [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	$ 117	$ 109
LG And E And KU Energy LLC [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates	4.00%	3.96%	3.69%
LG And E And KU Energy LLC [Member] | Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period	$ 28	$ 27	$ 25
Additions charged to income	9	8	10
Additions charged to other accounts	0	3	3
Deductions	5	10	11
Balance at end of period	32	28	27
Louisville Gas And Electric Co [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues	1,456	1,500	1,496
Restricted Cash and Cash Equivalents [Abstract]
Cash and cash equivalents	$ 7	15	$ 10		15
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)	(4)
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	119	122
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	38	43
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	30	35
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	$ 44
Louisville Gas And Electric Co [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates	4.00%	3.87%	3.63%
Louisville Gas And Electric Co [Member] | Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period	$ 1	$ 1	$ 1
Additions charged to income	4	2	4
Additions charged to other accounts	0	2	1
Deductions	2	4	5
Balance at end of period	3	1	1
Kentucky Utilities Co [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues	1,690	1,740	1,760
Restricted Cash and Cash Equivalents [Abstract]
Cash and cash equivalents	$ 22	12	$ 14		$ 15
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)	$ (5)	(6)
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	123	128
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	57	63
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	$ 65
Kentucky Utilities Co [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates	4.00%	4.02%	3.74%
Kentucky Utilities Co [Member] | Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period	$ 1	$ 2	$ 1
Additions charged to income	4	4	5
Additions charged to other accounts	0	1	2
Deductions	3	6	6
Balance at end of period	$ 2	$ 1	$ 2

New Accounting Guidance Adopted

New Accounting Guidance Adopted (Details) $ in Millions	Dec. 31, 2020USD ($)
Other Noncurrent Assets [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset	$ 87
Other Current Liabilities [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Lease Liability - Current	24
Other Deferred Credits And Noncurrent Liabilities [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Lease Liability - Noncurrent	70
LG And E And KU Energy LLC [Member] | Other Noncurrent Assets [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset	46
LG And E And KU Energy LLC [Member] | Other Current Liabilities [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Lease Liability - Current	16
LG And E And KU Energy LLC [Member] | Other Deferred Credits And Noncurrent Liabilities [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Lease Liability - Noncurrent	37
Louisville Gas And Electric Co [Member] | Other Noncurrent Assets [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset	17
Louisville Gas And Electric Co [Member] | Other Current Liabilities [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Lease Liability - Current	6
Louisville Gas And Electric Co [Member] | Other Deferred Credits And Noncurrent Liabilities [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Lease Liability - Noncurrent	15
Kentucky Utilities Co [Member] | Other Noncurrent Assets [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset	27
Kentucky Utilities Co [Member] | Other Current Liabilities [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Lease Liability - Current	9
Kentucky Utilities Co [Member] | Other Deferred Credits And Noncurrent Liabilities [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Lease Liability - Noncurrent	$ 21

Segment and Related Informati_3

Segment and Related Information (Income Statement and Balance Sheet Data) (Details) $ in Millions		12 Months Ended
		Dec. 31, 2020USD ($)Integer	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)
Income Statement Data
Operating Revenues from external customers		$ 7,607	$ 7,769	$ 7,785
Depreciation		1,287	1,199	1,094
Amortization		72	81	78
Unrealized (gains) losses on derivatives and other hedging activities		280	73	(186)
Interest Expense		1,001	994	963
Income Before Income Taxes		1,971	2,155	2,285
Income Taxes		502	409	458
Deferred income taxes and investment tax credits		402	309	355
Net income		1,469	1,746	1,827
Cash Flow Data
Expenditures for long-lived assets		3,273	3,107	3,268
Balance Sheet Data
Total Assets		$ 48,116	45,680
Segment Information (Numeric) [Abstract]
Number of reportable segments | Integer		3
U.K. Regulated [Member]
Income Statement Data
Operating Revenues from external customers		$ 2,133	2,167	2,268
Depreciation		265	250	247
Amortization		16	25	34
Unrealized (gains) losses on derivatives and other hedging activities		271	62	(190)
Interest Expense		400	405	413
Income Before Income Taxes		958	1,169	1,339
Income Taxes		272	192	225
Deferred income taxes and investment tax credits		233	140	118
Net income		686	977	1,114
Cash Flow Data
Expenditures for long-lived assets		995	857	954
Balance Sheet Data
Total Assets		19,094	17,622
Segment Information (Numeric) [Abstract]
Net property, plant and equipment not subject to accounting for the effects of certain types of regulation		14,400	13,200
Kentucky Regulated [Member]
Income Statement Data
Operating Revenues from external customers		3,106	3,206	3,214
Depreciation		606	547	475
Amortization		19	27	18
Unrealized (gains) losses on derivatives and other hedging activities		5	6	6
Interest Expense		300	298	274
Income Before Income Taxes		516	530	531
Income Taxes		98	94	120
Deferred income taxes and investment tax credits		64	82	94
Net income		418	436	411
Cash Flow Data
Expenditures for long-lived assets		966	1,097	1,117
Balance Sheet Data
Total Assets		15,943	15,597
Pennsylvania Regulated [Member]
Income Statement Data
Operating Revenues from external customers		2,330	2,358	2,277
Depreciation		403	386	352
Amortization		26	24	22
Interest Expense		172	169	159
Income Before Income Taxes		664	607	567
Income Taxes		167	149	136
Deferred income taxes and investment tax credits		82	90	125
Net income		497	458	431
Cash Flow Data
Expenditures for long-lived assets		1,154	1,121	1,196
Balance Sheet Data
Total Assets		12,347	11,918
Corporate And Other [Member]
Income Statement Data
Operating Revenues from external customers		38	38	26
Depreciation		13	16	20
Amortization		11	5	4
Unrealized (gains) losses on derivatives and other hedging activities		4	5	(2)
Interest Expense		129	122	117
Income Before Income Taxes		(167)	(151)	(152)
Income Taxes		(35)	(26)	(23)
Deferred income taxes and investment tax credits		23	(3)	18
Net income		(132)	(125)	(129)
Cash Flow Data
Expenditures for long-lived assets		158	32	1
Balance Sheet Data
Total Assets		732	543
PPL Electric Utilities Corp [Member]
Income Statement Data
Operating Revenues from external customers		2,331	2,358	2,277
Depreciation		403	386	352
Amortization		26	24	22
Interest Expense		173	170	159
Income Before Income Taxes		664	606	566
Income Taxes		167	149	136
Deferred income taxes and investment tax credits		83	90	125
Net income	[1]	497	457	430
Balance Sheet Data
Total Assets		$ 12,324	11,901
Segment Information (Numeric) [Abstract]
Number of operating segments | Integer		2
Number of reportable segments | Integer		1
LG And E And KU Energy LLC [Member]
Income Statement Data
Operating Revenues from external customers		$ 3,106	3,206	3,214
Depreciation		606	547	475
Amortization		19	27	18
Interest Expense		223	226	206
Income Before Income Taxes		556	571	574
Income Taxes		106	103	129
Deferred income taxes and investment tax credits		64	82	94
Net income		450	468	445
Balance Sheet Data
Total Assets		$ 16,277	15,931
Segment Information (Numeric) [Abstract]
Number of operating segments | Integer		1
Number of reportable segments | Integer		1
Louisville Gas And Electric Co [Member]
Income Statement Data
Operating Revenues from external customers		$ 1,456	1,500	1,496
Depreciation		259	231	195
Amortization		9	15	14
Interest Expense		87	87	76
Income Before Income Taxes		306	295	297
Income Taxes		62	63	64
Deferred income taxes and investment tax credits		3	56	60
Net income	[2]	244	232	233
Balance Sheet Data
Total Assets		$ 7,345	7,133
Segment Information (Numeric) [Abstract]
Number of operating segments | Integer		1
Number of reportable segments | Integer		1
Kentucky Utilities Co [Member]
Income Statement Data
Operating Revenues from external customers		$ 1,690	1,740	1,760
Depreciation		346	315	279
Amortization		8	10	3
Interest Expense		113	109	100
Income Before Income Taxes		343	372	362
Income Taxes		63	79	76
Deferred income taxes and investment tax credits		20	39	48
Net income	[3]	280	293	$ 286
Balance Sheet Data
Total Assets		$ 9,072	$ 8,825
Segment Information (Numeric) [Abstract]
Number of operating segments | Integer		1
Number of reportable segments | Integer		1
[1]	Net income equals comprehensive income.
[2]	Net income equals comprehensive income.
[3]	Net income equals comprehensive income.

Segment and Related Informati_4

Segment and Related Information (Geographic Data) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues from external customers	$ 7,607	$ 7,769	$ 7,785
Long-lived assets	39,656	37,225
U.S. [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues from external customers	5,474	5,602	5,517
Long-lived assets	24,851	23,607
U.K. [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Long-lived assets	14,805	13,618
U.K. Regulated [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues from external customers	$ 2,133	$ 2,167	$ 2,268

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Details) $ in Millions	12 Months Ended
	Dec. 31, 2020USD ($)Days	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)
Revenue from contracts with customers [Line Items]
Operating Revenues	$ 7,607	$ 7,769	$ 7,785
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs	(24)	(30)	32
Other Revenue	(27)	(38)	(38)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	7,556	7,701	7,779
Credit loss from contract with customer [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	29	27	34
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	48	44	42	$ 29
Contract with Customer, Liability, Revenue Recognized	29	32	21
Licensed energy supplier [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	1,990	2,032	2,127
Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	2,585	2,610	2,704
Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	1,185	1,257	1,233
Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	582	621	624
Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	484	495	489
Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	20	43	118
Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	40	49	79
Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	670	594	405
Pennsylvania Regulated [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues	$ 2,330	2,358	2,277
Number Of Days Due From Invoice Date | Days	21
U.K. Regulated [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues	$ 2,133	2,167	2,268
Number Of Days Due From Invoice Date | Days	14
Kentucky Regulated [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues	$ 3,106	3,206	3,214
Number Of Days Due From Invoice Date | Days	22
Corporate Segment [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues	$ 38	38	26
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	$ 2,331	2,358	2,277
Number Of Days Due From Invoice Date | Days	21
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs	$ (12)	(6)	(6)
Other Revenue	(3)	(10)	(12)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	2,316	2,342	2,259
Credit loss from contract with customer [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	17	21	24
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	23	21	23	19
Contract with Customer, Liability, Revenue Recognized	9	11	8
PPL Electric Utilities Corp [Member] | Licensed energy supplier [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0	0	0
PPL Electric Utilities Corp [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	1,238	1,288	1,379
PPL Electric Utilities Corp [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	314	349	368
PPL Electric Utilities Corp [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	44	59	54
PPL Electric Utilities Corp [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	50	52	53
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	670	594	405
LG And E And KU Energy LLC [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues	3,106	3,206	3,214
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs	(12)	(24)	38
Other Revenue	(17)	(21)	(17)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	3,077	3,161	3,235
Credit loss from contract with customer [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	8	6	9
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	11	9	9	8
Contract with Customer, Liability, Revenue Recognized	9	9	8
LG And E And KU Energy LLC [Member] | Licensed energy supplier [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0	0	0
LG And E And KU Energy LLC [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	1,347	1,322	1,325
LG And E And KU Energy LLC [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	871	908	865
LG And E And KU Energy LLC [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	538	562	570
LG And E And KU Energy LLC [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	261	277	278
LG And E And KU Energy LLC [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	20	43	118
LG And E And KU Energy LLC [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	40	49	79
LG And E And KU Energy LLC [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	$ 0	0	0
LG And E And KU Energy LLC [Member] | LGE [Member]
Revenue from contracts with customers [Line Items]
Number Of Days Due From Invoice Date | Days	22
LG And E And KU Energy LLC [Member] | KU [Member]
Revenue from contracts with customers [Line Items]
Number Of Days Due From Invoice Date | Days	22
Louisville Gas And Electric Co [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues	$ 1,456	1,500	1,496
Number Of Days Due From Invoice Date | Days	22
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs	$ (8)	(10)	12
Other Revenue	(7)	(9)	(5)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	1,441	1,481	1,503
Credit loss from contract with customer [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	4	2	4
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	5	5	5	4
Contract with Customer, Liability, Revenue Recognized	5	5	4
Louisville Gas And Electric Co [Member] | Licensed energy supplier [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0	0	0
Louisville Gas And Electric Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	676	668	666
Louisville Gas And Electric Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	444	466	455
Louisville Gas And Electric Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	173	180	180
Louisville Gas And Electric Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	114	121	129
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	34	46	73
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	$ 1,690	1,740	1,760
Number Of Days Due From Invoice Date | Days	22
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs	$ (4)	(14)	26
Other Revenue	(10)	(12)	(12)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	1,676	1,714	1,774
Credit loss from contract with customer [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	4	4	5
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	6	4	4	$ 4
Contract with Customer, Liability, Revenue Recognized	4	4	4
Kentucky Utilities Co [Member] | Licensed energy supplier [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	0	0	0
Kentucky Utilities Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	671	654	659
Kentucky Utilities Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	427	442	410
Kentucky Utilities Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	365	382	390
Kentucky Utilities Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	147	156	149
Kentucky Utilities Co [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	20	43	118
Kentucky Utilities Co [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers	46	37	48
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]: 2020-12-31 - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020
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	$ 46
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, 2020	Dec. 31, 2019	Dec. 31, 2018
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	$ 7,556	$ 7,701	$ 7,779
Licensed energy supplier [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,990	2,032	2,127
Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	2,585	2,610	2,704
Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,185	1,257	1,233
Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	582	621	624
Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	484	495	489
Wholesale Municipal [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	20	43	118
Wholesale Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	40	49	79
Transmission [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	670	594	405
PPL Electric Utilities Corp [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	2,316	2,342	2,259
PPL Electric Utilities Corp [Member] | Licensed energy supplier [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
PPL Electric Utilities Corp [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,238	1,288	1,379
PPL Electric Utilities Corp [Member] | Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	314	349	368
PPL Electric Utilities Corp [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	44	59	54
PPL Electric Utilities Corp [Member] | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	50	52	53
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	670	594	405
LG And E And KU Energy LLC [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	3,077	3,161	3,235
LG And E And KU Energy LLC [Member] | Licensed energy supplier [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
LG And E And KU Energy LLC [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,347	1,322	1,325
LG And E And KU Energy LLC [Member] | Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	871	908	865
LG And E And KU Energy LLC [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	538	562	570
LG And E And KU Energy LLC [Member] | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	261	277	278
LG And E And KU Energy LLC [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	20	43	118
LG And E And KU Energy LLC [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	40	49	79
LG And E And KU Energy LLC [Member] | Transmission [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
Kentucky Utilities Co [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,676	1,714	1,774
Kentucky Utilities Co [Member] | Licensed energy supplier [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
Kentucky Utilities Co [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	671	654	659
Kentucky Utilities Co [Member] | Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	427	442	410
Kentucky Utilities Co [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	365	382	390
Kentucky Utilities Co [Member] | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	147	156	149
Kentucky Utilities Co [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	20	43	118
Kentucky Utilities Co [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	46	37	48
Kentucky Utilities 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, 2020	Dec. 31, 2019	Dec. 31, 2018
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

Income and Other Taxes (Tax Ref

Income and Other Taxes (Tax Reform) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Tax Reform [Line Items]
Income Tax Expense (Benefit)	$ 502	$ 409	$ 458
Net Increase in Regulatory Liability	63	88	(13)
Deferred Tax Liabilities, Net	3,551	3,064
Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			0
Income Tax Expense (Benefit)			321
Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member] | Deemed Dividend [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			397
Income Tax Expense (Benefit)			139
Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member] | Bonus Depreciation [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			(67)
Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			(330)
Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member] | Foreign Tax Credit [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)			(157)
Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member] | Valuation Of Foreign Tax Credit Carryforward [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)			110
Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member] | Reduction In U.S. Federal Income Tax Rate [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)			229
Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			0
Income Tax Expense (Benefit)			321
Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member] | Deemed Dividend [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			462
Income Tax Expense (Benefit)			161
Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member] | Bonus Depreciation [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			0
Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			(462)
Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member] | Foreign Tax Credit [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)			(205)
Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member] | Valuation Of Foreign Tax Credit Carryforward [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)			145
Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member] | Reduction In U.S. Federal Income Tax Rate [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)			220
Tax Cuts And Jobs Act [Member] | 2018 Adjustment [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			0
Income Tax Expense (Benefit)			0
Tax Cuts And Jobs Act [Member] | 2018 Adjustment [Member] | Deemed Dividend [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			(65)
Income Tax Expense (Benefit)			(22)
Tax Cuts And Jobs Act [Member] | 2018 Adjustment [Member] | Bonus Depreciation [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			(67)
Tax Cuts And Jobs Act [Member] | 2018 Adjustment [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			132
Tax Cuts And Jobs Act [Member] | 2018 Adjustment [Member] | Foreign Tax Credit [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)			48
Tax Cuts And Jobs Act [Member] | 2018 Adjustment [Member] | Valuation Of Foreign Tax Credit Carryforward [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)			(35)
Tax Cuts And Jobs Act [Member] | 2018 Adjustment [Member] | Reduction In U.S. Federal Income Tax Rate [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)			9
PPL Electric Utilities Corp [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	167	149	136
Net Increase in Regulatory Liability	40	43	19
Deferred Tax Liabilities, Net	1,559	1,447
PPL Electric Utilities Corp [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			(107)
PPL Electric Utilities Corp [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member] | Bonus Depreciation [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			(39)
PPL Electric Utilities Corp [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			(68)
PPL Electric Utilities Corp [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member] | Reduction In U.S. Federal Income Tax Rate [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)			(13)
PPL Electric Utilities Corp [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			(105)
PPL Electric Utilities Corp [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member] | Bonus Depreciation [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			0
PPL Electric Utilities Corp [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			(105)
PPL Electric Utilities Corp [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member] | Reduction In U.S. Federal Income Tax Rate [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)			(13)
PPL Electric Utilities Corp [Member] | Tax Cuts And Jobs Act [Member] | 2018 Adjustment [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			(2)
PPL Electric Utilities Corp [Member] | Tax Cuts And Jobs Act [Member] | 2018 Adjustment [Member] | Bonus Depreciation [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			(39)
PPL Electric Utilities Corp [Member] | Tax Cuts And Jobs Act [Member] | 2018 Adjustment [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			37
PPL Electric Utilities Corp [Member] | Tax Cuts And Jobs Act [Member] | 2018 Adjustment [Member] | Reduction In U.S. Federal Income Tax Rate [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)			0
LG And E And KU Energy LLC [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	106	103	129
Net Increase in Regulatory Liability	26	45	(32)
Deferred Tax Liabilities, Net	1,175	1,069
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			(60)
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member] | Bonus Depreciation [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			(28)
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			(32)
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member] | Reduction In U.S. Federal Income Tax Rate [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)			110
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			(45)
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member] | Bonus Depreciation [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			0
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			(45)
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member] | Reduction In U.S. Federal Income Tax Rate [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)			112
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member] | 2018 Adjustment [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			(15)
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member] | 2018 Adjustment [Member] | Bonus Depreciation [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			(28)
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member] | 2018 Adjustment [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			13
LG And E And KU Energy LLC [Member] | Tax Cuts And Jobs Act [Member] | 2018 Adjustment [Member] | Reduction In U.S. Federal Income Tax Rate [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)			(2)
Louisville Gas And Electric Co [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	62	63	64
Net Increase in Regulatory Liability	0	19	(5)
Deferred Tax Liabilities, Net	716	697
Louisville Gas And Electric Co [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			0
Louisville Gas And Electric Co [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member] | Bonus Depreciation [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			(17)
Louisville Gas And Electric Co [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			17
Louisville Gas And Electric Co [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			0
Louisville Gas And Electric Co [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member] | Bonus Depreciation [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			0
Louisville Gas And Electric Co [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			0
Louisville Gas And Electric Co [Member] | Tax Cuts And Jobs Act [Member] | 2018 Adjustment [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			0
Louisville Gas And Electric Co [Member] | Tax Cuts And Jobs Act [Member] | 2018 Adjustment [Member] | Bonus Depreciation [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			(17)
Louisville Gas And Electric Co [Member] | Tax Cuts And Jobs Act [Member] | 2018 Adjustment [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			17
Kentucky Utilities Co [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	63	79	76
Net Increase in Regulatory Liability	26	26	(27)
Deferred Tax Liabilities, Net	$ 835	$ 792
Kentucky Utilities Co [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			0
Kentucky Utilities Co [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member] | Bonus Depreciation [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			(11)
Kentucky Utilities Co [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Return [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			11
Kentucky Utilities Co [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			0
Kentucky Utilities Co [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member] | Bonus Depreciation [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			0
Kentucky Utilities Co [Member] | Tax Cuts And Jobs Act [Member] | Adjustments Per 2017 Tax Provision [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			0
Kentucky Utilities Co [Member] | Tax Cuts And Jobs Act [Member] | 2018 Adjustment [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			0
Kentucky Utilities Co [Member] | Tax Cuts And Jobs Act [Member] | 2018 Adjustment [Member] | Bonus Depreciation [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			(11)
Kentucky Utilities Co [Member] | Tax Cuts And Jobs Act [Member] | 2018 Adjustment [Member] | Consolidated Federal Net Operating Losses Due To The TCJA [Member]
Tax Reform [Line Items]
Taxable Income (Loss)			$ 11

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, 2020	Dec. 31, 2019	Dec. 31, 2018
Income Before Income Taxes (Details) [Abstract]
Domestic income	$ 902	$ 964	$ 1,127
Foreign income	1,069	1,191	1,158
Income Before Income Taxes	1,971	2,155	2,285
Deferred Tax Assets
Deferred investment tax credits	30	31
Regulatory liabilities	68	75
Income taxes due to customer	444	462
Accrued pension and postretirement costs	106	211
Federal loss carryforwards	234	324
State loss carryforwards	448	432
Foreign capital loss carryforwards	370	320
Foreign - other	6	8
Contributions in aid of construction	115	112
Domestic - other	136	99
Valuation allowances	(906)	(834)
Total deferred tax assets	1,452	1,642
Deferred Tax Liabilities
Domestic plant - net	3,700	3,546
Regulatory assets	195	262
Foreign plant - net	911	765
Foreign - pensions	127	72
Domestic - other	70	61
Total deferred tax liabilities	5,003	4,706
Net deferred tax liability	3,551	3,064
Loss carryforwards
Federal loss carryforwards	234	324
State loss carryforwards	448	432
Foreign capital loss carryforwards	370	320
Deferred tax asset credit carryforwards	401	402
Federal [Member]
Deferred Tax Assets
Federal loss carryforwards	234
Loss carryforwards
Net operating losses	1,111
Federal loss carryforwards	234
Other Federal Loss Carryforwards	2
Loss carryforward valuation allowance on net operating losses	0
Other Loss Carryforward	13
Loss Carryforward Valuation Allowance Other	0
Federal [Member] | General Business Tax Credit Carryforward [Member]
Loss carryforwards
Deferred tax asset credit carryforwards	32
State [Member]
Deferred Tax Assets
State loss carryforwards	448
Loss carryforwards
Net operating losses	6,032
State loss carryforwards	448
Other Federal Loss Carryforwards	0
Loss carryforward valuation allowance on net operating losses	(419)
Other Loss Carryforward	2
Loss Carryforward Valuation Allowance Other	0
State [Member] | General Business Tax Credit Carryforward [Member]
Loss carryforwards
Deferred tax asset credit carryforwards	1
Foreign Tax Authority [Member]
Deferred Tax Assets
Foreign capital loss carryforwards	370
Loss carryforwards
Capital losses	1,945
Foreign capital loss carryforwards	370
Loss carryforward valuation allowance on capital losses	(370)
Deferred Tax Assets, Capital Loss Carryforwards, U.K. Finance Act 2020	106
Other Noncurrent Assets [Member]
Deferred Tax Liabilities
Deferred Tax Assets, State Taxes	17	24
PPL Electric Utilities Corp [Member]
Income Before Income Taxes (Details) [Abstract]
Income Before Income Taxes	664	606	566
Deferred Tax Assets
Regulatory liabilities	24	31
Income taxes due to customer	162	170
Accrued pension and postretirement costs	25	81
Federal loss carryforwards	52	78
State loss carryforwards	0	6
Contributions in aid of construction	91	88
Domestic - other	29	23
Total deferred tax assets	383	477
Deferred Tax Liabilities
Domestic plant - net	1,826	1,761
Regulatory assets	86	139
Domestic - other	30	24
Total deferred tax liabilities	1,942	1,924
Net deferred tax liability	1,559	1,447
Loss carryforwards
Federal loss carryforwards	52	78
State loss carryforwards	0	6
PPL Electric Utilities Corp [Member] | Federal [Member]
Deferred Tax Assets
Federal loss carryforwards	52
Loss carryforwards
Net operating losses	248
Federal loss carryforwards	52
PPL Electric Utilities Corp [Member] | Federal [Member] | General Business Tax Credit Carryforward [Member]
Loss carryforwards
Deferred tax asset credit carryforwards	5
LG And E And KU Energy LLC [Member]
Income Before Income Taxes (Details) [Abstract]
Income Before Income Taxes	556	571	574
Deferred Tax Assets
Deferred investment tax credits	30	31
Regulatory liabilities	43	44
Income taxes due to customer	282	292
Deferred Tax Assets, Lease Liabilities	13	14
Accrued pension and postretirement costs	57	71
State tax credit carryforwards	17	19
Federal loss carryforwards	107	140
State loss carryforwards	28	31
Contributions in aid of construction	23	23
Domestic - other	29	28
Valuation allowances	(4)	(6)
Total deferred tax assets	784	849
Deferred Tax Liabilities
Domestic plant - net	1,831	1,778
Regulatory assets	109	122
Lease right-of-use assets	11	12
Domestic - other	8	6
Total deferred tax liabilities	1,959	1,918
Net deferred tax liability	1,175	1,069
Loss carryforwards
Federal loss carryforwards	107	140
State loss carryforwards	28	31
Deferred tax asset credit carryforwards	159	162
LG And E And KU Energy LLC [Member] | Federal [Member]
Deferred Tax Assets
Federal loss carryforwards	107
Loss carryforwards
Net operating losses	511
Charitable contributions	1
Federal loss carryforwards	107
Charitable contribution carryforwards	0
Loss carryforward valuation allowance on net operating losses	0
Charitable Contributions Loss Carryforwards valuation allowance	0
LG And E And KU Energy LLC [Member] | Federal [Member] | General Business Tax Credit Carryforward [Member]
Loss carryforwards
Deferred tax asset credit carryforwards	25
LG And E And KU Energy LLC [Member] | State [Member]
Deferred Tax Assets
State loss carryforwards	28
Loss carryforwards
Net operating losses	710
State loss carryforwards	28
Loss carryforward valuation allowance on net operating losses	0
LG And E And KU Energy LLC [Member] | State [Member] | General Business Tax Credit Carryforward [Member]
Loss carryforwards
Deferred tax asset credit carryforwards	1
Louisville Gas And Electric Co [Member]
Income Before Income Taxes (Details) [Abstract]
Income Before Income Taxes	306	295	297
Deferred Tax Assets
Deferred investment tax credits	8	8
Regulatory liabilities	20	19
Income taxes due to customer	132	136
Deferred Tax Assets, Lease Liabilities	5	5
Accrued pension and postretirement costs	0	6
State tax credit carryforwards	12	14
Contributions in aid of construction	15	15
Domestic - other	11	10
Valuation allowances	(12)	(14)
Total deferred tax assets	191	199
Deferred Tax Liabilities
Domestic plant - net	833	811
Regulatory assets	66	77
Lease right-of-use assets	4	4
Domestic - other	4	4
Total deferred tax liabilities	907	896
Net deferred tax liability	716	697
Louisville Gas And Electric Co [Member] | Federal [Member] | General Business Tax Credit Carryforward [Member]
Deferred Tax Assets
State tax credit carryforwards	12
Valuation allowances	(12)
Kentucky Utilities Co [Member]
Income Before Income Taxes (Details) [Abstract]
Income Before Income Taxes	343	372	$ 362
Deferred Tax Assets
Deferred investment tax credits	22	23
Regulatory liabilities	23	25
Income taxes due to customer	150	156
Deferred Tax Assets, Lease Liabilities	8	8
State tax credit carryforwards	5	5
Contributions in aid of construction	8	8
Domestic - other	4	3
Valuation allowances	(4)	(4)
Total deferred tax assets	216	224
Deferred Tax Liabilities
Domestic plant - net	992	959
Regulatory assets	43	45
Accrued pension and postretirement costs	8	2
Lease right-of-use assets	7	7
Domestic - other	1	3
Total deferred tax liabilities	1,051	1,016
Net deferred tax liability	835	$ 792
Kentucky Utilities Co [Member] | Federal [Member] | General Business Tax Credit Carryforward [Member]
Deferred Tax Assets
State tax credit carryforwards	5
Valuation allowances	$ (4)

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, 2020	Dec. 31, 2019	Dec. 31, 2018
Credit carryforwards
Deferred tax asset credit carryforwards	$ 401	$ 402
Deferred Tax Assets, Valuation Allowances	906	834
Tax Cuts And Jobs Act [Member]
Credit carryforwards
Permanently reinvested cumulative undistributed foreign earnings	8,000
Investment Tax Credit [Member] | Federal [Member]
Credit carryforwards
Deferred tax asset credit carryforwards	134
Credit Carryforward Valuation Allowance Investment Tax Credit	0
Foreign Tax Credit [Member] | Federal [Member]
Credit carryforwards
Deferred tax asset credit carryforwards	218
Credit Carryforward Valuation Allowance Foreign Tax Credits	(113)
Foreign Tax Credit [Member] | Federal [Member] | Tax Year 2016 [Member] | Tax Cuts And Jobs Act [Member]
Credit carryforwards
Deferred Tax Assets, Foreign Tax Credit Carryforwards	62
Foreign Tax Credit [Member] | Federal [Member] | Tax Year 2017 [Member] | Tax Cuts And Jobs Act [Member]
Credit carryforwards
Deferred Tax Assets, Foreign Tax Credit Carryforwards	156
Recycling Tax Credit [Member] | State [Member]
Credit carryforwards
Deferred tax asset credit carryforwards	16
Credit Carryforward Valuation Allowance Other	0
Other [Member] | Federal [Member]
Credit carryforwards
Deferred tax asset credit carryforwards	32
Credit Carryforward Valuation Allowance Other	(4)
Other [Member] | State [Member]
Credit carryforwards
Deferred tax asset 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	834	808	$ 838
Additions charged to income	69	31	26
Additions charged to other accounts	7	0	0
Deductions	4	5	56
Balance at end of period	906	834	808
Decrease of the valuation allowance as a result of a change in foreign tax credits available			35
Decrease of the valuation allowance as a result of the change in currency exchange rates	11		19
Increase of the valuation allowance as a result of the reduction in the U.S. federal corporate income tax rate	38
PPL Electric Utilities Corp [Member] | Other [Member] | Federal [Member]
Credit carryforwards
Deferred tax asset credit carryforwards	5
LG And E And KU Energy LLC [Member]
Credit carryforwards
State tax credit carryforwards	17	19
Deferred tax asset credit carryforwards	159	162
Deferred Tax Assets, Valuation Allowances	4	6
LG And E And KU Energy LLC [Member] | Investment Tax Credit [Member] | Federal [Member]
Credit carryforwards
Deferred tax asset credit carryforwards	134
Credit Carryforward Valuation Allowance Investment Tax Credit	0
LG And E And KU Energy LLC [Member] | Recycling Tax Credit [Member] | State [Member]
Credit carryforwards
Deferred tax asset credit carryforwards	16
Credit Carryforward Valuation Allowance Other	0
LG And E And KU Energy LLC [Member] | Other [Member] | Federal [Member]
Credit carryforwards
Deferred tax asset credit carryforwards	25
Credit Carryforward Valuation Allowance Other	(4)
LG And E And KU Energy LLC [Member] | Other [Member] | State [Member]
Credit carryforwards
Deferred tax asset credit carryforwards	1
Credit Carryforward Valuation Allowance Other	0
LG And E And KU Energy LLC [Member] | Valuation Allowance Of Deferred Tax Assets [Member]
Valuation Allowances and Reserves (Details) [Roll Forward]
Balance at beginning of period	6	8	8
Additions charged to other accounts	0	3	0
Deductions	2	5	0
Balance at end of period	4	6	$ 8
Louisville Gas And Electric Co [Member]
Credit carryforwards
State tax credit carryforwards	12	14
Deferred Tax Assets, Valuation Allowances	12	14
Louisville Gas And Electric Co [Member] | Other [Member] | Federal [Member]
Credit carryforwards
State tax credit carryforwards	12
Deferred Tax Assets, Valuation Allowances	12
Kentucky Utilities Co [Member]
Credit carryforwards
State tax credit carryforwards	5	5
Deferred Tax Assets, Valuation Allowances	4	$ 4
Kentucky Utilities Co [Member] | Other [Member] | Federal [Member]
Credit carryforwards
State tax credit carryforwards	5
Deferred Tax Assets, Valuation Allowances	4
Kentucky Utilities Co [Member] | Other [Member] | Federal [Member] | Tax Credit Carryforward Expiration Year 2028 [Member]
Credit carryforwards
State tax credit carryforwards	4
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, 2020	Dec. 31, 2019	Dec. 31, 2018
Income Tax Expense (Benefit)
Current - Federal	$ (9)	$ (10)	$ (19)
Current - State	24	19	17
Current - Foreign	85	91	104
Total Current Expense	100	100	102
Deferred - Federal	123	139	203
Deferred - State	94	76	100
Deferred - Foreign	215	123	107
Total Deferred Expense (Benefit), excluding operating loss carry forwards	432	338	410
Amortization of investment tax credit	(3)	(3)	(3)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Deferred - Federal	6	7	(20)
Deferred - State	(33)	(33)	(31)
Total Tax Expense (Benefit) of Operating Loss Carryforwards	(27)	(26)	(51)
Total income tax from continuing operations	502	409	458
Income tax expense [Abstract]
Total income tax expense - Federal	117	133	161
Total income tax expense - State	85	62	86
Total income tax expense - Foreign	300	214	211
Total income tax from continuing operations	502	409	458
Income Tax Expense (Benefit) Excluded From Income Taxes [Abstract]
Other comprehensive income	(19)	(93)	(6)
Total income tax expense (benefits) excluded from incomes taxes from continuing operations	(19)	(93)	(6)
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate	414	453	480
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	48	45	40
Valuation allowance adjustments	26	22	21
Impact of lower U.K. income tax rates	(26)	(25)	(25)
U.S. income tax on foreign earnings - net of foreign tax credit	11	2	3
Effective Income Tax Rate Reconciliation, Prior Year Income Taxes, Amount	(9)	1	0
Impact of the United Kingdom Finance Acts on deferred tax balances	101	(14)	(13)
Depreciation and other items not normalized	(5)	(10)	(11)
Amortization of excess deferred federal and state income taxes	(43)	(40)	(37)
Interest benefit on United Kingdom financing entities	(12)	(12)	(17)
Deferred tax impact of Kentucky tax reform	0	0	9
Kentucky recycling credit, net of federal income tax expense	0	(18)	0
Other	(3)	5	8
Total increase (decrease)	88	(44)	(22)
Total income tax from continuing operations	$ 502	$ 409	$ 458
Effective income tax rate	25.50%	19.00%	20.00%
Expense related to increased Pennsylvania net operating loss carryforwards expected to be unutilized	$ 24	$ 25	$ 24
Taxes, other than income
State gross receipts	100	107	103
Foreign property	127	127	134
Domestic property and other	80	79	75
Total	307	313	312
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, U.K. Finance Act 2020, Amount	106
Foreign Tax Authority [Member]
Income Tax Expense (Benefit)
Deferred - Foreign	106
PPL Electric Utilities Corp [Member]
Income Tax Expense (Benefit)
Current - Federal	61	44	2
Current - State	23	15	9
Total Current Expense	84	59	11
Deferred - Federal	45	51	96
Deferred - State	38	39	37
Total Deferred Expense (Benefit), excluding operating loss carry forwards	83	90	133
Tax expense (benefit) of operating loss carryforwards [Abstract]
Deferred - Federal	0	0	(8)
Total Tax Expense (Benefit) of Operating Loss Carryforwards	0	0	(8)
Total income tax from continuing operations	167	149	136
Income tax expense [Abstract]
Total income tax expense - Federal	106	95	90
Total income tax expense - State	61	54	46
Total income tax from continuing operations	167	149	136
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate	139	127	119
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	52	47	43
Effective Income Tax Rate Reconciliation, Prior Year Income Taxes, Amount	(4)	1	0
Depreciation and other items not normalized	(5)	(10)	(11)
Amortization of excess deferred federal and state income taxes	(16)	(18)	(17)
Other	1	2	2
Total increase (decrease)	28	22	17
Total income tax from continuing operations	$ 167	$ 149	$ 136
Effective income tax rate	25.20%	24.60%	24.00%
Taxes, other than income
State gross receipts	$ 100	$ 107	$ 103
Domestic property and other	7	5	6
Total	107	112	109
LG And E And KU Energy LLC [Member]
Income Tax Expense (Benefit)
Current - Federal	41	20	31
Current - State	1	0	4
Total Current Expense	42	20	35
Deferred - Federal	43	81	65
Deferred - State	24	5	34
Total Deferred Expense (Benefit), excluding operating loss carry forwards	67	86	99
Amortization of investment tax credit	(3)	(3)	(3)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Deferred - Federal	0	0	(2)
Total Tax Expense (Benefit) of Operating Loss Carryforwards	0	0	(2)
Total income tax from continuing operations	106	103	129
Income tax expense [Abstract]
Total income tax expense - Federal	81	98	91
Total income tax expense - State	25	5	38
Total income tax from continuing operations	106	103	129
Income Tax Expense (Benefit) Excluded From Income Taxes [Abstract]
Other comprehensive income	2	(1)	5
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate	117	120	121
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	22	23	22
Valuation allowance adjustments	(28)	(23)	(20)
Amortization of investment tax credit	(3)	(3)	(3)
Deferred tax impact of Kentucky tax reform	0	0	9
Kentucky recycling credit, net of federal income tax expense	0	(18)	0
Other	(2)	4	0
Total increase (decrease)	(11)	(17)	8
Total income tax from continuing operations	$ 106	$ 103	$ 129
Effective income tax rate	19.10%	18.00%	22.50%
Taxes, other than income
Domestic property and other	$ 77	$ 74	$ 70
Total	77	74	70
Louisville Gas And Electric Co [Member]
Income Tax Expense (Benefit)
Current - Federal	53	4	0
Current - State	7	4	4
Total Current Expense	60	8	4
Deferred - Federal	(4)	46	51
Deferred - State	7	10	10
Total Deferred Expense (Benefit), excluding operating loss carry forwards	3	56	61
Amortization of investment tax credit	(1)	(1)	(1)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Total income tax from continuing operations	62	63	64
Income tax expense [Abstract]
Total income tax expense - Federal	48	49	50
Total income tax expense - State	14	14	14
Total income tax from continuing operations	62	63	64
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate	64	62	62
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	12	12	11
Valuation allowance adjustments	0	14	0
Amortization of excess deferred federal and state income taxes	(11)	(10)	(8)
Kentucky recycling credit, net of federal income tax expense	0	(14)	0
Other	(3)	(1)	(1)
Total increase (decrease)	(2)	1	2
Total income tax from continuing operations	$ 62	$ 63	$ 64
Effective income tax rate	20.30%	21.40%	21.50%
Taxes, other than income
Domestic property and other	$ 40	$ 39	$ 36
Total	40	39	36
Kentucky Utilities Co [Member]
Income Tax Expense (Benefit)
Current - Federal	40	35	22
Current - State	3	5	6
Total Current Expense	43	40	28
Deferred - Federal	11	28	40
Deferred - State	11	13	10
Total Deferred Expense (Benefit), excluding operating loss carry forwards	22	41	50
Amortization of investment tax credit	(2)	(2)	(2)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Total income tax from continuing operations	63	79	76
Income tax expense [Abstract]
Total income tax expense - Federal	49	61	60
Total income tax expense - State	14	18	16
Total income tax from continuing operations	63	79	76
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate	72	78	76
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	14	15	13
Valuation allowance adjustments	0	4	0
Amortization of investment tax credit	(2)	(2)	(2)
Amortization of excess deferred federal and state income taxes	(17)	(13)	(12)
Kentucky recycling credit, net of federal income tax expense	0	(4)	0
Other	(4)	1	1
Total increase (decrease)	(9)	1	0
Total income tax from continuing operations	$ 63	$ 79	$ 76
Effective income tax rate	18.40%	21.20%	21.00%
Taxes, other than income
Domestic property and other	$ 37	$ 35	$ 34
Total	$ 37	$ 35	$ 34

Income and Other Taxes (Unrecog

Income and Other Taxes (Unrecognized to End) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2020USD ($)Integer	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)
Income Tax Examination (Details) [Line Items]
Number of major tax jurisdictions tax returns are filed | Integer	4
Deferred Income Tax Expense (Benefit)	$ 432	$ 338	$ 410
Increase (Decrease) in Regulatory Assets and Liabilities	$ 63	88	(13)
US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2016 and prior
Pennsylvania - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2016 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	2016 and prior
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)	$ 83	90	133
Increase (Decrease) in Regulatory Assets and Liabilities	$ 40	43	19
PPL Electric Utilities Corp [Member] | US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2016 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	2016 and prior
LG And E And KU Energy LLC [Member]
Income Tax Examination (Details) [Line Items]
Number of major tax jurisdictions tax returns are filed | Integer	2
Deferred Income Tax Expense (Benefit)	$ 67	86	99
Increase (Decrease) in Regulatory Assets and Liabilities	$ 26	45	(32)
LG And E And KU Energy LLC [Member] | US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2016 and prior
LG And E And KU Energy LLC [Member] | Kentucky - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2014 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)	$ 3	56	61
Increase (Decrease) in Regulatory Assets and Liabilities	$ 0	19	(5)
Louisville Gas And Electric Co [Member] | US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2016 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)	$ 22	41	50
Increase (Decrease) in Regulatory Assets and Liabilities	$ 26	$ 26	$ (27)
Kentucky Utilities Co [Member] | US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2016 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	Dec. 31, 2020	Dec. 31, 2019
Regulatory Assets [Line Items]
Current Regulatory Assets	$ 99	$ 67
Noncurrent Regulatory Assets	1,262	1,492
Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	4	8
Smart meter rider [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	17	13
Plant outage costs [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	46	32
Transmission Formula Rate [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	15	3
Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	10
Other [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	10	1
Noncurrent Regulatory Assets	7	4
Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	570	800
Storm costs [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	7	0
Noncurrent Regulatory Assets	17	39
Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	30	41
Interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	23	22
Terminated interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	75	81
Accumulated cost of removal of utility plant [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	240	220
AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	300	279
Act 129 compliance rider [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	6
PPL Electric Utilities Corp [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	40	26
Noncurrent Regulatory Assets	541	726
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	17	13
PPL Electric Utilities Corp [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Transmission Formula Rate [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	15	3
PPL Electric Utilities Corp [Member] | Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	10
PPL Electric Utilities Corp [Member] | Other [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	1	0
Noncurrent Regulatory Assets	3	0
PPL Electric Utilities Corp [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	290	467
PPL Electric Utilities Corp [Member] | Storm costs [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	7	0
Noncurrent Regulatory Assets	0	15
PPL Electric Utilities Corp [Member] | Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	8	18
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	240	220
PPL Electric Utilities Corp [Member] | AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Act 129 compliance rider [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	6
LG And E And KU Energy LLC [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	59	41
Noncurrent Regulatory Assets	721	766
LG And E And KU Energy LLC [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	4	8
LG And E And KU Energy LLC [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	46	32
LG And E And KU Energy LLC [Member] | Other [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	9	1
Noncurrent Regulatory Assets	4	4
LG And E And KU Energy LLC [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	280	333
LG And E And KU Energy LLC [Member] | Storm costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	17	24
LG And E And KU Energy LLC [Member] | Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	22	23
LG And E And KU Energy LLC [Member] | Interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	23	22
LG And E And KU Energy LLC [Member] | Terminated interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	75	81
LG And E And KU Energy LLC [Member] | AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	300	279
Louisville Gas And Electric Co [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	23	25
Noncurrent Regulatory Assets	351	380
Louisville Gas And Electric Co [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	4	8
Louisville Gas And Electric Co [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	12	16
Louisville Gas And Electric Co [Member] | Other [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	7	1
Noncurrent Regulatory Assets	1	1
Louisville Gas And Electric Co [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	174	206
Louisville Gas And Electric Co [Member] | Storm costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	11	14
Louisville Gas And Electric Co [Member] | Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	13	14
Louisville Gas And Electric Co [Member] | Interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	23	22
Louisville Gas And Electric Co [Member] | Terminated interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	44	47
Louisville Gas And Electric Co [Member] | AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	85	76
Kentucky Utilities Co [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	36	16
Noncurrent Regulatory Assets	370	386
Kentucky Utilities Co [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Kentucky Utilities Co [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	34	16
Kentucky Utilities Co [Member] | Other [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	2	0
Noncurrent Regulatory Assets	3	3
Kentucky Utilities Co [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	106	127
Kentucky Utilities Co [Member] | Storm costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	6	10
Kentucky Utilities Co [Member] | Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	9	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	31	34
Kentucky Utilities Co [Member] | AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	$ 215	$ 203

Utility Rate Regulation (Regu_2

Utility Rate Regulation (Regulatory Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Regulatory Liabilities [Line Items]
Current regulatory liabilities	$ 79	$ 115
Noncurrent regulatory liabilities	2,530	2,572
Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	21	23
Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	4	5
Universal Service Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	22	9
Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	5	8
TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	11	61
Storm Damage Expense Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	6	5
Accumulated cost of removal of utility plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	653	640
Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	43	51
Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	1,690	1,756
Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	60	51
Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	66	68
Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	3	4
Noncurrent regulatory liabilities	18	6
Act 129 Compliance Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	7	0
PPL Electric Utilities Corp [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	68	96
Noncurrent regulatory liabilities	578	599
PPL Electric Utilities Corp [Member] | Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	21	23
PPL Electric Utilities Corp [Member] | Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Universal Service Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	22	9
PPL Electric Utilities Corp [Member] | Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	11	59
PPL Electric Utilities Corp [Member] | Storm Damage Expense Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	6	5
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	560	588
PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	18	11
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	1	0
Noncurrent regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Act 129 Compliance Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	7	0
LG And E And KU Energy LLC [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	11	19
Noncurrent regulatory liabilities	1,952	1,973
LG And E And KU Energy LLC [Member] | Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	4	5
LG And E And KU Energy LLC [Member] | Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	5	8
LG And E And KU Energy LLC [Member] | Accumulated cost of removal of utility plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	653	640
LG And E And KU Energy LLC [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	43	51
LG And E And KU Energy LLC [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	1,130	1,168
LG And E And KU Energy LLC [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	42	40
LG And E And KU Energy LLC [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	66	68
LG And E And KU Energy LLC [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	2	6
Noncurrent regulatory liabilities	18	6
Louisville Gas And Electric Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	2
Noncurrent regulatory liabilities	882	883
Louisville Gas And Electric Co [Member] | Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	1
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] | Accumulated cost of removal of utility plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	274	266
Louisville Gas And Electric Co [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	30	35
Louisville Gas And Electric Co [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	528	544
Louisville Gas And Electric Co [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	0	0
Louisville Gas And Electric Co [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	33	34
Louisville Gas And Electric Co [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	1
Noncurrent regulatory liabilities	17	4
Kentucky Utilities Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	11	17
Noncurrent regulatory liabilities	1,070	1,090
Kentucky Utilities Co [Member] | Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	4	4
Kentucky Utilities Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	5	8
Kentucky Utilities Co [Member] | Accumulated cost of removal of utility plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	379	374
Kentucky Utilities Co [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	13	16
Kentucky Utilities Co [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	602	624
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	42	40
Kentucky Utilities Co [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	33	34
Kentucky Utilities Co [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	2	5
Noncurrent regulatory liabilities	$ 1	$ 2

Utility Rate Regulation (Regu_3

Utility Rate Regulation (Regulatory Assets and Liabilities) (Details) - USD ($) $ in Millions	Sep. 29, 2020	May 21, 2020	Jun. 30, 2018	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities				$ 63	$ 88	$ (13)
Defined Benefit Plans [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period				15 years
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
LKE [Member] | Defined Benefit Plans [Member]
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				$ 79	$ 51
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] | Environmental Cost Recovery [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period				12 months
Return on equity	9.20%			9.20%	9.725%
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] | Environmental Cost Recovery [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period				12 months
Return on equity	9.20%			9.20%	9.725%
PPL Electric Utilities Corp [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities				$ 40	$ 43	19
PPL Electric Utilities Corp [Member] | TCJA customer refund [Member]
Regulatory Assets and Liabilities - Gas Line Tracker (Numeric) [Abstract]
Approved Amount Of Rate Reduction Due To TCJA			$ 43
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
PPL Electric Utilities Corp [Member] | PPL Electric [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Return on equity		11.18%
LG And E And KU Energy LLC [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities				$ 26	45	(32)
LG And E And KU Energy LLC [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				$ 79	$ 51
LG And E And KU Energy LLC [Member] | LGE [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period				12 months
LG And E And KU Energy LLC [Member] | LGE [Member] | Gas Supply Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period				18 months
LG And E And KU Energy LLC [Member] | 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	9.20%			9.20%	9.725%
LG And E And KU Energy LLC [Member] | KU [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period				12 months
LG And E And KU Energy LLC [Member] | 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	9.20%			9.20%	9.725%
Louisville Gas And Electric Co [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities				$ 0	$ 19	(5)
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				$ 44	$ 29
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] | Environmental Cost Recovery [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period				12 months
Return on equity	9.20%			9.20%	9.725%
Kentucky Utilities Co [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities				$ 26	$ 26	$ (27)
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				$ 35	$ 22
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] | Environmental Cost Recovery [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period				12 months
Return on equity	9.20%			9.20%	9.725%

Utility Rate Regulation (Regu_4

Utility Rate Regulation (Regulatory Matters) (Details) - USD ($) $ in Millions	Nov. 25, 2020	Sep. 29, 2020	May 21, 2020	Mar. 31, 2020	Jun. 30, 2022	Dec. 31, 2020	Dec. 31, 2019	May 31, 2026	Jun. 30, 2020
LKE [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Public Utilities Expected Capital Costs To Comply									$ 405
LKE [Member] | 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
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Public Utilities, Requested Bill Credit	53
LGE [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
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		9.20%				9.20%	9.725%
Requested return on equity				9.725%
Amortization period for the deferred recovery of a regulatory asset						12 months
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%
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%
KU [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
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		9.20%				9.20%	9.725%
Requested return on equity				9.725%
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%
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Public Utilities, Requested Bill Credit	$ 12
PPL Electric Utilities Corp [Member] | PPL Electric [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]
Proposed Return Of Equity From Complaint			8.00%
Amended Proposed Return On Equity From Complaint			8.50%
Change in Net Income Due to ROE Adjustment						$ 12
Act 129 Recovery Period Under Phase IV Plan								5 years
LG And E And KU Energy LLC [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Public Utilities Expected Capital Costs To Comply									405
LG And E And KU Energy LLC [Member] | 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
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Public Utilities, Requested Bill Credit	53
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Requested return on equity					10.00%
LG And E And KU Energy LLC [Member] | LGE [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Return on equity		9.20%				9.20%	9.725%
Requested return on equity				9.725%
Amortization period for the deferred recovery of a regulatory asset						12 months
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Public Utilities Expected Capital Costs To Comply									153
LG And E And KU Energy LLC [Member] | 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%
LG And E And KU Energy LLC [Member] | 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
LG And E And KU Energy LLC [Member] | 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%
LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Requested return on equity					10.00%
LG And E And KU Energy LLC [Member] | KU [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Return on equity		9.20%				9.20%	9.725%
Requested return on equity				9.725%
Amortization period for the deferred recovery of a regulatory asset						12 months
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Public Utilities Expected Capital Costs To Comply									252
LG And E And KU Energy LLC [Member] | 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%
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Public Utilities, Requested Bill Credit	$ 12
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
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		9.20%				9.20%	9.725%
Requested return on equity				9.725%
Amortization period for the deferred recovery of a regulatory asset						12 months
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Public Utilities Expected Capital Costs To Comply									153
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%
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%
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
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		9.20%				9.20%	9.725%
Requested return on equity				9.725%
Amortization period for the deferred recovery of a regulatory asset						12 months
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Public Utilities Expected Capital Costs To Comply									$ 252
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%
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, 2020	Dec. 31, 2019	Dec. 31, 2018
PPL Electric [Member]
Purchases Of Accounts Receivable [Line Items]
Purchases of accounts receivable	$ 1.1	$ 1.2	$ 1.3
PPL Electric Utilities Corp [Member]
Purchases Of Accounts Receivable [Line Items]
Purchases of accounts receivable	$ 1.1	$ 1.2	$ 1.3

Financing Activities - Credit A

Financing Activities - Credit Arrangements (Details) £ in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2020GBP (£)	Dec. 31, 2020USD ($)	Aug. 01, 2020	Jun. 01, 2020	Apr. 01, 2020USD ($)	Mar. 31, 2020USD ($)	Dec. 31, 2019GBP (£)	Dec. 31, 2019USD ($)
U.K. [Member]
Financing Activities [Line Items]
Capacity | £	£ 1,155
Borrowed | £	371						£ 243
Letters of credit and commercial paper issued | £	4						4
Unused capacity	780	$ 1,000
U.K. [Member] | Uncommitted Credit Facilities [Member]
Financing Activities [Line Items]
Capacity | £	100
Borrowed | £	60						0
Letters of credit and commercial paper issued | £	4						4
Unused capacity | £	36
WPD PLC [Member] | U.K. [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity | £	210
Borrowed	187	$ 249					155	$ 200
Letters of credit and commercial paper issued | £	0						£ 0
Unused capacity | £	£ 23
Maximum percentage of total net debt to RAV allowed under the credit facility	85.00%	85.00%
Interest rate on outstanding borrowing	0.95%	0.95%					2.52%	2.52%
WPD South West [Member] | U.K. [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity | £	£ 220
Borrowed	50	$ 67					£ 40	$ 51
Letters of credit and commercial paper issued | £	0						£ 0
Unused capacity | £	£ 170
Maximum percentage of total net debt to RAV allowed under the credit facility	85.00%	85.00%
Interest rate on outstanding borrowing	54.00%	54.00%					1.09%	1.09%
WPD East Midlands [Member] | U.K. [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity | £	£ 250
Borrowed | £	0						£ 0
Letters of credit and commercial paper issued | £	0						0
Unused capacity | £	£ 250
Maximum percentage of total net debt to RAV allowed under the credit facility	85.00%	85.00%
WPD West Midlands [Member] | U.K. [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity | £	£ 250
Borrowed	74	$ 99					48	$ 62
Letters of credit and commercial paper issued | £	0						£ 0
Unused capacity | £	£ 176
Maximum percentage of total net debt to RAV allowed under the credit facility	85.00%	85.00%
Interest rate on outstanding borrowing	0.54%	0.54%					1.11%	1.11%
PPL Capital Funding [Member] | Term Loan Due 2022 [Member] | Term Loan Credit Facility [Member]
Financing Activities [Line Items]
Capacity					$ 100
Borrowed					$ 100
Interest rate on outstanding borrowing					1.72%
PPL Capital Funding [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Potential capacity increase		$ 250
PPL Capital Funding [Member] | Term Loan Credit Facility [Member]
Financing Activities [Line Items]
Capacity					$ 100	$ 200
Borrowed					$ 100	$ 200
Interest rate on outstanding borrowing					173.00%	1.96%
PPL Capital Funding [Member] | U.S. [Member]
Financing Activities [Line Items]
Capacity		1,950
Borrowed		400						$ 0
Letters of credit and commercial paper issued		417						465
Unused capacity		1,133
PPL Capital Funding [Member] | U.S. [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity		1,450
Borrowed		0						0
Letters of credit and commercial paper issued		402						450
Unused capacity		$ 1,048
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%	70.00%
PPL Capital Funding [Member] | U.S. [Member] | Syndicated Credit Facility 1 [Member]
Financing Activities [Line Items]
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%	70.00%
PPL Capital Funding [Member] | U.S. [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
Potential capacity increase		30
PPL Capital Funding [Member] | U.S. [Member] | Term Loan Credit Facility [Member]
Financing Activities [Line Items]
Capacity		200
Borrowed		200						0
Letters of credit and commercial paper issued		0						0
Unused capacity		$ 0
PPL Capital Funding [Member] | U.S. [Member] | Revolving Credit Facility [Member]
Financing Activities [Line Items]
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%	70.00%
PPL Capital Funding [Member] | U.S. [Member] | Term Loan Facility #2
Financing Activities [Line Items]
Capacity		$ 100
Borrowed		100						0
Letters of credit and commercial paper issued		0						0
Unused capacity		0
PPL Capital Funding [Member] | U.S. [Member] | Term Loan Facility #3
Financing Activities [Line Items]
Capacity		100
Borrowed		100						0
Letters of credit and commercial paper issued		0						0
Unused capacity		0
PPL Capital Funding [Member] | U.S. [Member] | Bilateral Credit Facility #2
Financing Activities [Line Items]
Capacity		50
Borrowed		0						0
Letters of credit and commercial paper issued		15						15
Unused capacity		35
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%	70.00%
Potential capacity increase		$ 250
LKE [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%	70.00%
LGE [Member]
Financing Activities [Line Items]
Capacity		$ 500
Borrowed		0						0
Letters of credit and commercial paper issued		262						238
Unused capacity		238
LGE [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity		500
Borrowed		0						0
Letters of credit and commercial paper issued		262						238
Unused capacity		$ 238
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%	70.00%
Potential capacity increase		$ 250
KU [Member]
Financing Activities [Line Items]
Capacity		400
Borrowed		0						0
Letters of credit and commercial paper issued		203						150
Unused capacity		197
KU [Member] | First Mortgage Bonds Due 2050 [Member] | First Mortgage Bonds [Member]
Financing Activities [Line Items]
Stated interest rate				3.30%
KU [Member] | Debt Instrument, Redemption, Period One [Member] | First Mortgage Bonds due 2020 [Member] | First Mortgage Bonds [Member]
Financing Activities [Line Items]
Stated interest rate			3.25%
KU [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity		400
Borrowed		0						0
Letters of credit and commercial paper issued		203						150
Unused capacity		$ 197
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%	70.00%
Potential capacity increase		$ 250
KU [Member] | Letter Of Credit Facility [Member]
Financing Activities [Line Items]
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%	70.00%
WPD [Member] | U.K. [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Minimum interest coverage ratio allowed under the credit facility	3.0
WPD South Wales [Member] | U.K. [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity | £	£ 125
Borrowed | £	0						£ 0
Letters of credit and commercial paper issued | £	0						£ 0
Unused capacity | £	£ 125
Maximum percentage of total net debt to RAV allowed under the credit facility	85.00%	85.00%
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%	70.00%
LG And E And KU Energy LLC [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%	70.00%
LG And E And KU Energy LLC [Member] | LGE [Member]
Financing Activities [Line Items]
Capacity		$ 500
Borrowed		0						0
Letters of credit and commercial paper issued		262						238
Unused capacity		238
LG And E And KU Energy LLC [Member] | LGE [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity		500
Borrowed		0						0
Letters of credit and commercial paper issued		262						238
Unused capacity		$ 238
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%	70.00%
Potential capacity increase		$ 250
LG And E And KU Energy LLC [Member] | KU [Member]
Financing Activities [Line Items]
Capacity		400
Borrowed		0						0
Letters of credit and commercial paper issued		203						150
Unused capacity		197
LG And E And KU Energy LLC [Member] | KU [Member] | First Mortgage Bonds Due 2050 [Member] | First Mortgage Bonds [Member]
Financing Activities [Line Items]
Stated interest rate				3.30%
LG And E And KU Energy LLC [Member] | KU [Member] | Debt Instrument, Redemption, Period One [Member] | First Mortgage Bonds due 2020 [Member] | First Mortgage Bonds [Member]
Financing Activities [Line Items]
Stated interest rate			3.25%	3.25%
LG And E And KU Energy LLC [Member] | KU [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity		400
Borrowed		0						0
Letters of credit and commercial paper issued		203						150
Unused capacity		$ 197
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%	70.00%
Potential capacity increase		$ 250
LG And E And KU Energy LLC [Member] | KU [Member] | Letter Of Credit Facility [Member]
Financing Activities [Line Items]
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%	70.00%
Louisville Gas And Electric Co [Member]
Financing Activities [Line Items]
Capacity		$ 500
Borrowed		0						0
Letters of credit and commercial paper issued		262						238
Unused capacity		238
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		262						238
Unused capacity		$ 238
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%	70.00%
Potential capacity increase		$ 250
Kentucky Utilities Co [Member]
Financing Activities [Line Items]
Capacity		400
Borrowed		0						0
Letters of credit and commercial paper issued		203						150
Unused capacity		197
Kentucky Utilities Co [Member] | First Mortgage Bonds Due 2050 [Member] | First Mortgage Bonds [Member]
Financing Activities [Line Items]
Stated interest rate				3.30%
Kentucky Utilities Co [Member] | Debt Instrument, Redemption, Period One [Member] | First Mortgage Bonds due 2020 [Member] | First Mortgage Bonds [Member]
Financing Activities [Line Items]
Stated interest rate			3.25%	3.25%
Kentucky Utilities Co [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity		400
Borrowed		0						0
Letters of credit and commercial paper issued		203						$ 150
Unused capacity		$ 197
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%	70.00%
Potential capacity increase		$ 250
Kentucky Utilities Co [Member] | Letter Of Credit Facility [Member]
Financing Activities [Line Items]
Maximum percentage of debt to total capitalization allowed under the credit facility	70.00%	70.00%
PPL Electric [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Potential capacity increase		$ 250

Financing Activities - Short-te

Financing Activities - Short-term Debt (Details) - Commercial Paper [Member] - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Short-term Debt [Line Items]
Capacity	$ 2,850
Commercial paper issuances	867	$ 838
Unused capacity	$ 1,983
PPL Capital Funding [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	0.25%	2.13%
Capacity	$ 1,500
Commercial paper issuances	402	$ 450
Unused capacity	$ 1,098
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	0.28%	2.07%
Capacity	$ 350
Commercial paper issuances	262	$ 238
Unused capacity	$ 88
KU [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	0.28%	2.02%
Capacity	$ 350
Commercial paper issuances	203	$ 150
Unused capacity	$ 147
PPL Electric Utilities Corp [Member]
Short-term Debt [Line Items]
Weighted-average interest rate
Capacity	$ 650
Commercial paper issuances	0	$ 0
Unused capacity	$ 650
LG And E And KU Energy LLC [Member] | LGE [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	0.28%	2.07%
Capacity	$ 350
Commercial paper issuances	262	$ 238
Unused capacity	$ 88
LG And E And KU Energy LLC [Member] | KU [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	0.28%	2.02%
Capacity	$ 350
Commercial paper issuances	203	$ 150
Unused capacity	$ 147
Louisville Gas And Electric Co [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	0.28%	2.07%
Capacity	$ 350
Commercial paper issuances	262	$ 238
Unused capacity	$ 88
Kentucky Utilities Co [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	0.28%	2.02%
Capacity	$ 350
Commercial paper issuances	203	$ 150
Unused capacity	$ 147

Financing Activities - Long-ter

Financing Activities - Long-term Debt (Details) £ in Millions, $ in Millions	Oct. 01, 2020USD ($)	Oct. 01, 2020GBP (£)	Oct. 31, 2020USD ($)	Jun. 30, 2020USD ($)	Apr. 30, 2020USD ($)	Dec. 31, 2020USD ($)	Jan. 01, 2021USD ($)	Dec. 31, 2020GBP (£)	Oct. 01, 2020GBP (£)	Sep. 01, 2020USD ($)	Aug. 01, 2020USD ($)	Jun. 01, 2020USD ($)	Apr. 01, 2020USD ($)	Mar. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Debt Instrument [Line Items]
Principal outstanding						$ 23,249									$ 22,002
Unamortized premium and (discount), net						2									5
Unamortized debt issuance costs						(132)									(126)
Total Long-term Debt						23,127									21,893
Less current portion of Long-term debt						1,574									1,172
Long-term Debt						21,553									20,721
Aggregate maturities of long-term debt (Details) [Abstract]
2021						1,574
2022						1,374
2023						2,552
2024						950
2025						883
Thereafter						15,916
WPD [Member] | Senior Notes [Member] | Senior Notes Due 2021 [Member] | Intent to Redeem [Member] | Subsequent Event [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount							$ 500
Stated interest rate							5.375%
WPD South West [Member] | Index-linked Senior Unsecured Notes [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount that may be redeemed in total by series						441		£ 331
WPD South Wales [Member] | Senior Notes [Member] | Senior Notes Due 2020 [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount | £									£ 150
Stated interest rate	9.25%								9.25%
WPD South Wales [Member] | Senior Notes [Member] | Senior Notes Due 2035 [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount | £									£ 250
Stated interest rate	1.625%								1.625%
Aggregate maturities of long-term debt (Details) [Abstract]
Proceeds from Issuance of Secured Debt	$ 319	£ 247
PPL Capital Funding [Member] | Term Loan Credit Facility [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity													$ 100	$ 200
Interest rate on outstanding borrowing													173.00%	1.96%
PPL Capital Funding [Member] | Term Loan Credit Facility [Member] | Term Loan Due 2022 [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity													$ 100
Interest rate on outstanding borrowing													1.72%
PPL Capital Funding [Member] | Senior Notes [Member] | Senior Notes Due 2030 [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount													$ 1,000
Stated interest rate													4.125%
Aggregate maturities of long-term debt (Details) [Abstract]
Proceeds from Issuance of Secured Debt					$ 993
PPL Electric [Member] | Pollution Control Revenue Refunding Bonds [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Stated interest rate	0.40%								0.40%
PPL Electric [Member] | Pollution Control Revenue Refunding Bonds, 2008 Series [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 90
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						10,800									10,100
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 2023 [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 250
Aggregate maturities of long-term debt (Details) [Abstract]
Proceeds from Issuance of Debt			$ 249
LGE [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity						$ 500
LGE [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien						$ 5,500									5,300
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
LKE [Member] | 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						$ 848
Aggregate amount of tax-exempt revenue bonds in a variable rate mode						33
LKE [Member] | Senior Notes [Member] | Senior Notes Due 2020 [Member] | Debt Instrument, Redemption, Period One [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount											$ 475
Stated interest rate											3.75%
KU [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity						400
KU [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien						$ 6,700									6,600
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
KU [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds Due 2050 [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount												$ 500
Stated interest rate												3.30%
Aggregate maturities of long-term debt (Details) [Abstract]
Proceeds from Issuance of First Mortgage Bond				$ 493
KU [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds due 2020 [Member] | Debt Instrument, Redemption, Period One [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount											$ 500
Stated interest rate											3.25%
WPD South West, WPD East Midlands and WPD South Wales [Member] | Index-linked Senior Unsecured Notes [Member]
Long-term Debt (Numeric) [Abstract]
Increase (decrease) in principal due to inflation						$ 13		£ 10
LOUISVILLE GAS And ELECTRIC CO [Member] | Jefferson County Pollution Control Revenue Bonds, 2001 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount										$ 23
Stated interest rate										0.90%
LOUISVILLE GAS And ELECTRIC CO [Member] | Pollution Control Revenue Bonds, 2016 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount										$ 125
Stated interest rate										1.30%
U.S. [Member]
Debt Instrument [Line Items]
Principal outstanding						$ 14,835									13,960
U.S. [Member] | Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						3.95%		3.95%
Principal outstanding						$ 4,850									4,325
U.S. [Member] | Senior Secured Notes - First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						3.81%		3.81%
Principal outstanding						$ 8,955									8,705
U.S. [Member] | Senior Secured Notes - First Mortgage Bonds [Member] | Potential To Be Called Within One Year [Member]
Debt Instrument [Line Items]
Principal outstanding						$ 250
U.S. [Member] | Junior Subordinated Notes [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						4.35%		4.35%
Principal outstanding						$ 930									930
U.S. [Member] | Term Loan Credit Facility [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						0.85%		0.85%
Principal outstanding						$ 100									0
U.S. [Member] | PPL Capital Funding [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity						1,950
U.S. [Member] | PPL Capital Funding [Member] | Term Loan Credit Facility [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity						200
U.K. [Member]
Debt Instrument [Line Items]
Principal outstanding						8,414									8,042
Fair market value adjustments						$ 8									12
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity | £								£ 1,155
U.K. [Member] | Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						4.69%		4.69%
Principal outstanding						$ 7,197									6,874
Long-term Debt (Numeric) [Abstract]
Principal amount that may be redeemed in total but not in part						$ 300		£ 225
U.K. [Member] | Term Loan Credit Facility [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						1.46%		1.46%
Principal outstanding						$ 67									64
U.K. [Member] | Index-linked Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						1.42%		1.42%
Principal outstanding						$ 1,150									1,104
U.K. [Member] | Long-term Debt [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount that may be put back to the issuer						7,700		£ 5,800
PPL Electric Utilities Corp [Member]
Debt Instrument [Line Items]
Principal outstanding						4,289									4,039
Unamortized discount						(23)									(24)
Unamortized debt issuance costs						(30)									(30)
Total Long-term Debt						4,236									3,985
Less current portion of Long-term debt						400									0
Long-term Debt						3,836									3,985
Aggregate maturities of long-term debt (Details) [Abstract]
2021						400
2022						474
2023						340
2024						0
2025						0
Thereafter						$ 3,075
PPL Electric Utilities Corp [Member] | Pollution Control Revenue Refunding Bonds [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Stated interest rate	0.40%								0.40%
PPL Electric Utilities Corp [Member] | Pollution Control Revenue Refunding Bonds, 2008 Series [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 90
PPL Electric Utilities Corp [Member] | Senior Secured Notes - First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						3.79%		3.79%
Principal outstanding						$ 4,289									4,039
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						10,800									10,100
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 2023 [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 250
Aggregate maturities of long-term debt (Details) [Abstract]
Proceeds from Issuance of Debt			$ 249
LG And E And KU Energy LLC [Member]
Debt Instrument [Line Items]
Principal outstanding						$ 6,116									6,041
Debt Instrument, Unamortized Premium						5									5
Unamortized discount						(13)									(12)
Unamortized debt issuance costs						(34)									(32)
Total Long-term Debt						6,074									6,002
Less current portion of Long-term debt						674									975
Long-term Debt						5,400									5,027
Aggregate maturities of long-term debt (Details) [Abstract]
2021						674
2022						0
2023						13
2024						0
2025						550
Thereafter						$ 4,879
LG And E And KU Energy LLC [Member] | Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						4.38%		4.38%
Principal outstanding						$ 250									725
LG And E And KU Energy LLC [Member] | Senior Secured Notes - First Mortgage Bonds [Member] | Potential To Be Called Within One Year [Member]
Debt Instrument [Line Items]
Principal outstanding						$ 250
LG And E And KU Energy LLC [Member] | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						3.82%		3.82%
Principal outstanding						$ 4,666									4,666
LG And E And KU Energy LLC [Member] | 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						848
Aggregate amount of tax-exempt revenue bonds in a variable rate mode						$ 33
LG And E And KU Energy LLC [Member] | PPL Affiliate [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						3.89%		3.89%
Principal outstanding						$ 1,200									650
LG And E And KU Energy LLC [Member] | Senior Notes [Member] | Senior Notes Due 2020 [Member] | Debt Instrument, Redemption, Period One [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount											$ 475
Stated interest rate											3.75%
LG And E And KU Energy LLC [Member] | LGE [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity						500
LG And E And KU Energy LLC [Member] | LGE [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien						$ 5,500									5,300
LG And E And KU Energy LLC [Member] | 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
LG And E And KU Energy LLC [Member] | KU [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity						$ 400
LG And E And KU Energy LLC [Member] | KU [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien						$ 6,700									6,600
LG And E And KU Energy LLC [Member] | 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
LG And E And KU Energy LLC [Member] | KU [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds Due 2050 [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount												$ 500
Stated interest rate												3.30%
Aggregate maturities of long-term debt (Details) [Abstract]
Proceeds from Issuance of First Mortgage Bond				493
LG And E And KU Energy LLC [Member] | KU [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds due 2020 [Member] | Debt Instrument, Redemption, Period One [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount											$ 500
Stated interest rate											3.25%	3.25%
LG And E And KU Energy LLC [Member] | LOUISVILLE GAS And ELECTRIC CO [Member] | Jefferson County Pollution Control Revenue Bonds, 2001 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount										$ 23
Stated interest rate										0.90%
LG And E And KU Energy LLC [Member] | LOUISVILLE GAS And ELECTRIC CO [Member] | Pollution Control Revenue Bonds, 2016 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount										$ 125
Stated interest rate										1.30%
LOUISVILLE GAS And ELECTRIC CO [Member]
Debt Instrument [Line Items]
Principal outstanding						$ 2,024									2,024
Unamortized discount						(4)									(4)
Unamortized debt issuance costs						(13)									(15)
Total Long-term Debt						2,007									2,005
Less current portion of Long-term debt						292									0
Long-term Debt						1,715									2,005
Aggregate maturities of long-term debt (Details) [Abstract]
2021						292
2022						0
2023						0
2024						0
2025						300
Thereafter						1,432
Capacity						500
LOUISVILLE GAS And ELECTRIC CO [Member] | Jefferson County Pollution Control Revenue Bonds, 2001 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount										$ 23
Stated interest rate										0.90%
LOUISVILLE GAS And ELECTRIC CO [Member] | Pollution Control Revenue Bonds, 2016 Series A [Member] | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount										$ 125
Stated interest rate										1.30%
LOUISVILLE GAS And ELECTRIC CO [Member] | Senior Secured Notes - First Mortgage Bonds [Member] | Potential To Be Called Within One Year [Member]
Debt Instrument [Line Items]
Principal outstanding						$ 250
LOUISVILLE GAS And ELECTRIC CO [Member] | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						3.69%		3.69%
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						$ 5,500									5,300
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						$ 539
Kentucky Utilities Co [Member]
Debt Instrument [Line Items]
Principal outstanding						2,642									2,642
Debt Instrument, Unamortized Premium						5									5
Unamortized discount						(9)									(8)
Unamortized debt issuance costs						(20)									(16)
Total Long-term Debt						2,618									2,623
Less current portion of Long-term debt						132									500
Long-term Debt						2,486									2,123
Aggregate maturities of long-term debt (Details) [Abstract]
2021						132
2022						0
2023						13
2024						0
2025						250
Thereafter						2,247
Capacity						400
Kentucky Utilities Co [Member] | Senior Secured Notes - First Mortgage Bonds [Member] | Potential To Be Called Within One Year [Member]
Debt Instrument [Line Items]
Principal outstanding						$ 250
Kentucky Utilities Co [Member] | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate						3.92%		3.92%
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						$ 6,700									$ 6,600
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
Kentucky Utilities Co [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds Due 2050 [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount												$ 500
Stated interest rate												3.30%
Aggregate maturities of long-term debt (Details) [Abstract]
Proceeds from Issuance of First Mortgage Bond				$ 493
Kentucky Utilities Co [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds due 2020 [Member] | Debt Instrument, Redemption, Period One [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount											$ 500
Stated interest rate											3.25%	3.25%

Financing Activities Financing

Financing Activities Financing Activities- Equity Securities (Details) - USD ($) shares in Thousands, $ in Millions		12 Months Ended
		Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Feb. 28, 2018
Equity Programs [Line Items]
Issuance of common stock		$ 34	$ 1,167	$ 698
Common Stock [Member]
Equity Programs [Line Items]
Common stock shares issued	[1]	1,674	46,910	26,925
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
[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
	Nov. 30, 2020	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Distributions [Line Items]
Current quarterly common stock dividend (in dollars per share)	$ 0.4150	$ 1.66	$ 1.65	$ 1.64
Annualized current quarterly common stock dividend (in dollars per share)	$ 1.66
Deferred Interest Payment		$ 0
LKE [Member]
Distributions [Line Items]
Restricted net assets at end of period		3,000
Unrestricted assets at the end of period		$ 3,700
Minimum adjusted equity to total capitalization in order to pay dividends		30.00%
LG And E And KU Energy LLC [Member]
Distributions [Line Items]
Restricted net assets at end of period		$ 3,000
Unrestricted assets at the end of period		$ 3,700
Minimum adjusted equity to total capitalization in order to pay dividends		30.00%
Louisville Gas And Electric Co [Member]
Distributions [Line Items]
Restricted net assets at end of period		$ 1,300
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		$ 1,700
Unrestricted assets at the end of period		$ 2,000
Minimum adjusted equity to total capitalization in order to pay dividends		30.00%

Leases - Lessee (Details)

Leases - Lessee (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2026	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Lease, Cost [Abstract]
Operating lease cost	$ 30	$ 33
Short-term lease cost	9	7
Total lease cost	39	40
Operating cash flows from operating leases	26	29
Right-of-use asset obtained in exchange for new operating lease liabilities	17	46
Lessee, Operating Lease, Liability, Payment, Due [Abstract]
2020								$ 27
2021							$ 22
2022						$ 18
2023					$ 15
2024				$ 8
Thereafter			$ 20
Total	$ 110
Assets and Liabilities, Lessee [Abstract]
Weighted-average discount rate	3.35%
Weighted-average remaining lease term (in years)	8 years
Other Current Liabilities [Member]
Assets and Liabilities, Lessee [Abstract]
Current lease liabilities	$ 24
Other Deferred Credits And Noncurrent Liabilities [Member]
Assets and Liabilities, Lessee [Abstract]
Non-current lease liabilities	70
Other Noncurrent Assets [Member]
Assets and Liabilities, Lessee [Abstract]
Right-of-use assets	87
LG And E And KU Energy LLC [Member]
Lease, Cost [Abstract]
Operating lease cost	22	25
Short-term lease cost	2	2
Total lease cost	24	27
Operating cash flows from operating leases	18	21
Right-of-use asset obtained in exchange for new operating lease liabilities	16	16
Lessee, Operating Lease, Liability, Payment, Due [Abstract]
2020								17
2021							13
2022						10
2023					8
2024				6
Thereafter			3
Total	$ 57
Assets and Liabilities, Lessee [Abstract]
Weighted-average discount rate	3.66%
Weighted-average remaining lease term (in years)	4 years
LG And E And KU Energy LLC [Member] | Minimum [Member]
Lessee, Lease, Description [Line Items]
Lessee, Operating Lease, Renewal Term	1 year
LG And E And KU Energy LLC [Member] | Maximum [Member]
Lessee, Lease, Description [Line Items]
Lessee, Operating Lease, Renewal Term	10 years
LG And E And KU Energy LLC [Member] | Other Current Liabilities [Member]
Assets and Liabilities, Lessee [Abstract]
Current lease liabilities	$ 16
LG And E And KU Energy LLC [Member] | Other Deferred Credits And Noncurrent Liabilities [Member]
Assets and Liabilities, Lessee [Abstract]
Non-current lease liabilities	37
LG And E And KU Energy LLC [Member] | Other Noncurrent Assets [Member]
Assets and Liabilities, Lessee [Abstract]
Right-of-use assets	46
Louisville Gas And Electric Co [Member]
Lease, Cost [Abstract]
Operating lease cost	8	12
Short-term lease cost	1	1
Total lease cost	9	13
Operating cash flows from operating leases	7	9
Right-of-use asset obtained in exchange for new operating lease liabilities	6	5
Lessee, Operating Lease, Liability, Payment, Due [Abstract]
2020								6
2021							5
2022						4
2023					3
2024				3
Thereafter			1
Total	$ 22
Assets and Liabilities, Lessee [Abstract]
Weighted-average discount rate	3.53%
Weighted-average remaining lease term (in years)	4 years
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 Current Liabilities [Member]
Assets and Liabilities, Lessee [Abstract]
Current lease liabilities	$ 6
Louisville Gas And Electric Co [Member] | Other Deferred Credits And Noncurrent Liabilities [Member]
Assets and Liabilities, Lessee [Abstract]
Non-current lease liabilities	15
Louisville Gas And Electric Co [Member] | Other Noncurrent Assets [Member]
Assets and Liabilities, Lessee [Abstract]
Right-of-use assets	17
Kentucky Utilities Co [Member]
Lease, Cost [Abstract]
Operating lease cost	13	13
Short-term lease cost	1	1
Total lease cost	14	14
Operating cash flows from operating leases	11	11
Right-of-use asset obtained in exchange for new operating lease liabilities	9	$ 11
Lessee, Operating Lease, Liability, Payment, Due [Abstract]
2020								$ 10
2021							$ 8
2022						$ 6
2023					$ 4
2024				$ 3
Thereafter			$ 2
Total	$ 33
Assets and Liabilities, Lessee [Abstract]
Weighted-average discount rate	3.68%
Weighted-average remaining lease term (in years)	4 years
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 Current Liabilities [Member]
Assets and Liabilities, Lessee [Abstract]
Current lease liabilities	$ 9
Kentucky Utilities Co [Member] | Other Deferred Credits And Noncurrent Liabilities [Member]
Assets and Liabilities, Lessee [Abstract]
Non-current lease liabilities	21
Kentucky Utilities Co [Member] | Other Noncurrent Assets [Member]
Assets and Liabilities, Lessee [Abstract]
Right-of-use assets	$ 27

Leases Leases - Lessor (Details

Leases Leases - Lessor (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2026	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Lessor, Lease, Description [Line Items]
2020								$ 11
2021							$ 6
2022						$ 6
2023					$ 5
2024				$ 4
Thereafter			$ 12
Total	$ 44
Lease income recognized	21	$ 21
LG And E And KU Energy LLC [Member]
Lessor, Lease, Description [Line Items]
2020								5
2021							0
2022						1
2023					0
2024				0
Thereafter			0
Total	6
Lease income recognized	15	13
Louisville Gas And Electric Co [Member]
Lessor, Lease, Description [Line Items]
2020								0
2021							0
2022						0
2023					0
2024				0
Thereafter			0
Total	0
Lease income recognized	6	5
Kentucky Utilities Co [Member]
Lessor, Lease, Description [Line Items]
2020								$ 5
2021							$ 0
2022						$ 0
2023					$ 0
2024				$ 0
Thereafter			$ 0
Total	5
Lease income recognized	$ 9	$ 8

Stock-Based Compensation (Detai

Stock-Based Compensation (Details)	12 Months Ended
	Dec. 31, 2020USD ($)Integer$ / sharesshares	Dec. 31, 2019USD ($)$ / sharesshares	Dec. 31, 2018USD ($)$ / shares
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)	1,137,685
Granted (in shares)	331,160
Vested (in shares)	(562,848)
Forfeited (in shares)	(9,661)
Nonvested, end of period (in shares)	896,336	1,137,685
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	$ 32.76
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	35.30	$ 31.95	$ 30.58
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	34.57
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	32.97
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 32.56	$ 32.76
Total fair value of units vested during the period | $	$ 19,000,000	$ 13,000,000	$ 16,000,000
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)	739,392
Granted (in shares)	261,891
Vested (in shares)	0
Forfeited (in shares)	(375,029)
Nonvested, end of period (in shares)	626,254	739,392
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	$ 37.50
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	37.63	$ 35.83	$ 38.26
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	38.46
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 36.98	$ 37.50
Total fair value of units vested during the period | $		$ 3,000,000
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	15.64%	17.57%	17.60%
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)	570,765
Granted (in shares)	374,878
Vested (in shares)	(216,979)
Nonvested, end of period (in shares)	728,664	570,765
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	$ 32.02
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	34.95	$ 30.89	$ 32.21
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	34.42
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 32.81	$ 32.02
Total fair value of units vested during the period | $	$ 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)	1,330,943
Exercised (in shares)	(227,927)
Weighted average remaining contractual term (in years)	1 year 8 months 12 days
Outstanding at end of period (in shares)	1,103,016	1,330,943
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	$ 26.20
Weighted average exercise price per share, exercised (in dollars per share) | $ / shares	26.10
Weighted average exercise price per share at end of period (in dollars per share) | $ / shares	$ 26.22	$ 26.20
Aggregate total intrinsic value | $	$ 2,000,000
Cash received from exercise of stock options | $	8,000,000	$ 53,000,000	$ 5,000,000
Total intrinsic value of stock options exercised | $		11,000,000
All Plans [Member] | All Awards [Member]
Aggregate disclosures [Abstract]
Compensation expense | $	28,000,000	35,000,000	25,000,000
Income tax benefit | $	8,000,000	$ 10,000,000	$ 10,000,000
Unrecognized compensation expense | $	$ 16,000,000
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)	229,860
Transfer between registrants	(1,197)
Granted (in shares)	65,356
Vested (in shares)	(79,313)
Forfeited (in shares)	(3,986)
Nonvested, end of period (in shares)	210,720	229,860
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	$ 32.61
Weighted-average grant date fair value per share, transfer between registrants (in dollars per share) | $ / shares	32.23
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	35.37	$ 32.33	$ 30
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	34.55
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	32.65
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 32.73	$ 32.61
Total fair value of units vested during the period | $	$ 3,000,000	$ 2,000,000	$ 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)	66,799
Granted (in shares)	21,416
Vested (in shares)	0
Forfeited (in shares)	(26,408)
Nonvested, end of period (in shares)	61,807	66,799
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	$ 37.43
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	38.64	$ 35.68	$ 38.37
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	38.37
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 37.44	$ 37.43
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)	49,194
Granted (in shares)	30,426
Vested (in shares)	(17,813)
Nonvested, end of period (in shares)	61,807	49,194
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	$ 31.92
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	35.59	$ 30.76	$ 32.32
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	34.41
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 33.01	$ 31.92
Total fair value of units vested during the period | $	$ 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	15.64%	17.57%	17.60%
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 | $	$ 10,000,000	$ 12,000,000	$ 10,000,000
Income tax benefit | $	3,000,000	$ 3,000,000	$ 3,000,000
Unrecognized compensation expense | $	$ 3,000,000
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
LG And E And KU Energy LLC [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)	166,445
Transfer between registrants	(1,598)
Granted (in shares)	50,402
Vested (in shares)	(60,571)
Forfeited (in shares)	(1,550)
Nonvested, end of period (in shares)	153,128	166,445
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	$ 32.09
Weighted-average grant date fair value per share, transfer between registrants (in dollars per share) | $ / shares	30.57
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	35.31	$ 30.65	$ 30.98
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	34.88
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	30.36
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 32.08	$ 32.09
Total fair value of units vested during the period | $	$ 2,000,000	$ 1,000,000	$ 5,000,000
Fair value assumptions and methodology [Abstract]
Award vesting period (in years)	3 years
LG And E And KU Energy LLC [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)	130,533
Granted (in shares)	35,538
Vested (in shares)	0
Forfeited (in shares)	(66,459)
Nonvested, end of period (in shares)	99,612	130,533
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	$ 37.60
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	37.73	$ 35.93	$ 38.32
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	38.23
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 37.23	$ 37.60
Period over which performance units fair value is recognized (in years)	3 years
Maximum payout percentage of target award	200.00%
LG And E And KU Energy LLC [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
LG And E And KU Energy LLC [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
LG And E And KU Energy LLC [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)	107,805
Granted (in shares)	60,286
Vested (in shares)	(46,384)
Nonvested, end of period (in shares)	121,707	107,805
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	$ 32.20
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	34.81	$ 30.99	$ 32.28
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	34.29
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 32.70	$ 32.20
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%
LG And E And KU Energy LLC [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	15.64%	17.57%	17.60%
LG And E And KU Energy LLC [Member] | All Plans [Member] | Stock Options [Member]
Stock options - additional disclosures [Abstract]
Period after which, employee stock options expire (in years)	10 years
LG And E And KU Energy LLC [Member] | All Plans [Member] | All Awards [Member]
Aggregate disclosures [Abstract]
Compensation expense | $	$ 11,000,000	$ 9,000,000	$ 8,000,000
Income tax benefit | $	3,000,000	$ 2,000,000	$ 2,000,000
Unrecognized compensation expense | $	$ 1,000,000
Weighted-average period for recognition | Integer	1.4
LG And E And KU Energy LLC [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
LG And E And KU Energy LLC [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, 2020	Dec. 31, 2019	Dec. 31, 2018
Pension Plan [Member] | U.S. [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost	$ 56	$ 50	$ 62
Interest cost	146	164	156
Expected return on plan assets	(246)	(245)	(249)
Amortization of:
Prior service cost (credit)	9	8	10
Actuarial (gain) loss	89	56	84
Net periodic defined benefit costs (credits) prior to settlements and termination benefits	54	33	63
Settlements	23	1	0
Net Periodic Defined Benefit Costs (Credits)	77	34	63
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Settlement	(23)	(1)	0
Net (gain) loss	(221)	(121)	157
Prior service costs (credit)	1	2	1
Amortization of: [Abstract]
Prior service (cost) credit	(9)	(8)	(10)
Actuarial gain (loss)	(89)	(56)	(84)
Total recognized in OCI and regulatory assets/liabilities	(341)	(184)	64
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	(264)	(150)	127
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
OCI	(428)	(194)	90
Regulatory assets/liabilities	87	10	(26)
Total recognized in OCI and regulatory assets/liabilities	(341)	(184)	64
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	40	18	40
Pension Plan [Member] | U.K. [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost	89	68	82
Interest cost	143	187	185
Expected return on plan assets	(622)	(588)	(587)
Amortization of:
Prior service cost (credit)	1	1	0
Actuarial (gain) loss	213	92	151
Net periodic defined benefit costs (credits) prior to settlements and termination benefits	(176)	(240)	(169)
Settlements	0	0	0
Net Periodic Defined Benefit Costs (Credits)	(176)	(240)	(169)
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Settlement	0	0	0
Net (gain) loss	459	723	201
Prior service costs (credit)	0	0	13
Amortization of: [Abstract]
Prior service (cost) credit	(1)	(1)	0
Actuarial gain (loss)	(213)	(92)	(151)
Total recognized in OCI and regulatory assets/liabilities	245	630	63
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	69	390	(106)
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	245	630	63
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	(237)	(287)	(226)
Other Postretirement Benefits Plan [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost	6	6	7
Interest cost	19	22	21
Expected return on plan assets	(21)	(18)	(23)
Amortization of:
Prior service cost (credit)	1	(1)	(1)
Actuarial (gain) loss	0	1	0
Net periodic defined benefit costs (credits) prior to settlements and termination benefits	5	10	4
Settlements	0	0	0
Net Periodic Defined Benefit Costs (Credits)	5	10	4
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Settlement	0	0	0
Net (gain) loss	(6)	(18)	8
Prior service costs (credit)	5	0	0
Amortization of: [Abstract]
Prior service (cost) credit	(1)	1	1
Actuarial gain (loss)	0	(1)	0
Total recognized in OCI and regulatory assets/liabilities	(2)	(18)	9
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	3	(8)	13
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
OCI	(12)	(13)	20
Regulatory assets/liabilities	10	(5)	(11)
Total recognized in OCI and regulatory assets/liabilities	(2)	(18)	9
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	4	8	2
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	(2)	(4)	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	2	4	(1)
LG And E And KU Energy LLC [Member] | Pension Plan [Member] | U.S. [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost	24	22	25
Interest cost	57	66	63
Expected return on plan assets	(101)	(101)	(102)
Amortization of:
Prior service cost (credit)	8	8	9
Actuarial (gain) loss	41	22	35
Net periodic defined benefit costs (credits) prior to settlements and termination benefits	29	17	30
Settlements	15	0	0
Net Periodic Defined Benefit Costs (Credits)	$ 44	$ 17	$ 30
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	$ 11	$ (5)	$ 11
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Settlement	(15)	0	0
Net (gain) loss	(29)	(37)	40
Prior service costs (credit)	2	2	0
Amortization of: [Abstract]
Prior service (cost) credit	(8)	(8)	(9)
Actuarial gain (loss)	(41)	(22)	(35)
Total recognized in OCI and regulatory assets/liabilities	(91)	(65)	(4)
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	(47)	(48)	26
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
OCI	(5)	13	(25)
Regulatory assets/liabilities	(86)	(78)	21
Total recognized in OCI and regulatory assets/liabilities	(91)	(65)	(4)
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	$ 20	$ 12	$ 21
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	$ 11	$ (5)	$ 11
LG And E And KU Energy LLC [Member] | Pension Plan [Member] | U.S. [Member] | Qualified Plan [Member]
Amortization of:
Settlements	15	5	6
LG And E And KU Energy LLC [Member] | Other Postretirement Benefits Plan [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost	4	4	4
Interest cost	7	8	8
Expected return on plan assets	(9)	(8)	(9)
Amortization of:
Prior service cost (credit)	1	1	1
Actuarial (gain) loss	(1)	(1)	0
Net periodic defined benefit costs (credits) prior to settlements and termination benefits	$ 2	$ 4	$ 4
Amortization period for the deferred recovery of a regulatory asset	15 years	15 years	15 years
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Settlement	$ 0	$ 0	$ 0
Net (gain) loss	(1)	(14)	1
Prior service costs (credit)	5	0	0
Amortization of: [Abstract]
Prior service (cost) credit	(1)	(1)	(1)
Actuarial gain (loss)	1	1	0
Total recognized in OCI and regulatory assets/liabilities	4	(14)	0
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	6	(10)	4
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
OCI	(2)	(7)	4
Regulatory assets/liabilities	6	(7)	(4)
Total recognized in OCI and regulatory assets/liabilities	4	(14)	0
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	$ 3
Amortization period for the deferred recovery of a regulatory asset	15 years	15 years	15 years
LG And E And KU Energy LLC [Member] | Other Postretirement Benefits Plan [Member] | U.S. [Member]
Amortization of:
Settlements	$ 0	$ 0	$ 0
Net Periodic Defined Benefit Costs (Credits)	$ 2	4	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	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]
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]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost		1	1
Interest cost		11	12
Expected return on plan assets		(21)	(22)
Amortization of:
Prior service cost (credit)		5	5
Actuarial (gain) loss		9	7
Net Periodic Defined Benefit Costs (Credits)		$ 5	$ 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)	$ (3)
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Net (gain) loss		(19)	22
Prior service costs (credit)		0	0
Amortization of: [Abstract]
Prior service (cost) credit		(5)	(5)
Actuarial gain (loss)		(9)	(7)
Total recognized in OCI and regulatory assets/liabilities		(33)	10
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities		(28)	13
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)	10
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	$ 4	$ 3	$ 4
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)	$ (3)
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | U.S. [Member] | Qualified Plan [Member]
Amortization of:
Settlements	$ 5	6
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | U.S. [Member] | LKE [Member]
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Costs allocated to subsidiary by plan sponsors		$ 0	$ 2
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)	$ (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]
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)	$ (3)
Louisville Gas And Electric Co [Member] | Other Postretirement Benefits Plan [Member] | LKE [Member]
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Costs allocated to subsidiary by plan sponsors		$ 2	$ 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)	$ (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	$ 1	$ (1)	$ 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	$ (1)	$ (1)	$ (2)
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)	$ (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	$ 0	$ 0	$ 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)	$ (2)

Retirement and Postemployment_4

Retirement and Postemployment Benefits (Weighted-Average Assumptions, Cost Trend Rates and Funded Status) (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	$ 706	$ 706	$ 464
Pension Plan [Member] | U.S. [Member]
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]
Benefit obligations valuation discount rate	2.92%	2.92%	3.64%
Benefit obligations valuation rate of compensation increase	3.76%	3.76%	3.79%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate - service cost		3.64%	4.35%	3.70%
Net periodic benefit costs discount rate - interest cost		3.64%	4.35%	3.70%
Net periodic benefit costs rate of compensation increase		3.79%	3.79%	3.78%
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	6.50%	6.50%	6.60%	6.60%
Health care cost trend rate assumed for next year, cost	6.60%	6.60%	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%	5.00%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate), cost	5.00%	5.00%	5.00%	5.00%
Year that the rate reaches the ultimate trend rate, obligations		2027	2024	2023
Year that the rate reaches the ultimate trend rate, cost		2024	2023	2022
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period		$ 4,146	$ 3,883
Service cost		56	50	$ 62
Interest cost		146	164	156
Participant contributions		0	0
Plan Amendments		2	2
Actuarial (gain) loss		256	368
Settlements		(114)	(21)
Gross benefits paid		(241)	(300)
Federal subsidy		0	0
Currency conversion		0	0
Benefit Obligation, end of period	$ 4,251	4,251	4,146	3,883
Change in Plan Assets [Roll Forward]
Balance at beginning of period		3,585	3,109
Actual return on plan assets		723	735
Employer contributions		115	63
Participant contributions		0	0
Settlements		(114)	(22)
Gross benefits paid		(241)	(300)
Currency conversion		0	0
Balance at end of period	4,068	4,068	3,585	$ 3,109
Funded Status, end of period	(183)	(183)	(561)
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	24	24	24
Current liability	(18)	(18)	(8)
Noncurrent liability	(189)	(189)	(577)
Net amount recognized, end of period	(183)	(183)	(561)
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)	27	27	34
Net actuarial (gain) loss	695	695	1,029
Total	722	722	1,063
Total accumulated benefit obligation for defined benefit pension plans	4,024	4,024	3,910
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
AOCI	270	270	352
Regulatory assets/liabilities	452	452	711
Total	722	722	1,063
Pension Plans Where the Projected or Accumulated Benefit Obligation Exceed the Fair Value of Plan Assets (Details) [Abstract]
Projected benefit obligations	1,875	1,875	3,861
Fair value of plan assets where the projected benefit obligations exceed the value of plan assets	1,668	1,668	3,275
Accumulated benefit obligation	184	184	3,624
Fair value of plan assets where the accumulated benefit obligations exceed the value of plan assets	$ 0	$ 0	$ 3,275
Pension Plan [Member] | U.K. [Member]
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]
Benefit obligations valuation discount rate	1.53%	1.53%	1.94%
Benefit obligations valuation rate of compensation increase	3.25%	3.25%	3.25%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate - service cost		2.03%	3.12%	2.73%
Net periodic benefit costs discount rate - interest cost		1.73%	2.62%	2.31%
Net periodic benefit costs rate of compensation increase		3.25%	3.50%	3.50%
Net periodic benefit costs expected return on plan assets		7.13%	7.21%	7.23%
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period		$ 8,515	$ 7,275
Service cost		89	68	$ 82
Interest cost		143	187	185
Participant contributions		12	12
Plan Amendments		0	0
Actuarial (gain) loss		624	1,220
Settlements		0	0
Gross benefits paid		(366)	(363)
Federal subsidy		0	0
Currency conversion		281	116
Benefit Obligation, end of period	$ 9,298	9,298	8,515	7,275
Change in Plan Assets [Roll Forward]
Balance at beginning of period		8,945	7,801
Actual return on plan assets		805	1,095
Employer contributions		272	278
Participant contributions		12	12
Settlements		0	0
Gross benefits paid		(366)	(363)
Currency conversion		302	122
Balance at end of period	9,970	9,970	8,945	$ 7,801
Funded Status, end of period	672	672	430
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	682	682	440
Current liability	0	0	(1)
Noncurrent liability	(10)	(10)	(9)
Net amount recognized, end of period	672	672	430
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)	11	11	11
Net actuarial (gain) loss	3,682	3,682	3,435
Total	3,693	3,693	3,446
Total accumulated benefit obligation for defined benefit pension plans	8,516	8,516	7,821
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
Total	3,693	3,693	3,446
Pension Plans Where the Projected or Accumulated Benefit Obligation Exceed the Fair Value of Plan Assets (Details) [Abstract]
Projected benefit obligations	11	11	10
Fair value of plan assets where the projected benefit obligations exceed the value of plan assets	0	0	0
Accumulated benefit obligation	11	11	10
Fair value of plan assets where the accumulated benefit obligations exceed the value of plan assets	$ 0	$ 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	2.84%	2.84%	3.60%
Benefit obligations valuation rate of compensation increase	3.75%	3.75%	3.76%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate - service cost		3.60%	4.31%	3.64%
Net periodic benefit costs discount rate - interest cost		3.60%	4.31%	3.64%
Net periodic benefit costs rate of compensation increase		3.76%	3.76%	3.75%
Net periodic benefit costs expected return on plan assets		6.44%	6.46%	6.40%
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period		$ 557	$ 538
Service cost		6	6	$ 7
Interest cost		19	22	21
Participant contributions		15	14
Plan Amendments		5	0
Actuarial (gain) loss		29	34
Settlements		0	0
Gross benefits paid		(58)	(58)
Federal subsidy		0	1
Currency conversion		0	0
Benefit Obligation, end of period	$ 573	573	557	538
Change in Plan Assets [Roll Forward]
Balance at beginning of period		340	301
Actual return on plan assets		56	71
Employer contributions		18	10
Participant contributions		11	10
Settlements		0	0
Gross benefits paid		(58)	(52)
Currency conversion		0	0
Balance at end of period	367	367	340	$ 301
Funded Status, end of period	(206)	(206)	(217)
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	0	0	11
Current liability	(22)	(22)	(2)
Noncurrent liability	(184)	(184)	(226)
Net amount recognized, end of period	(206)	(206)	(217)
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)	14	14	10
Net actuarial (gain) loss	0	0	6
Total	14	14	16
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
AOCI	10	10	13
Regulatory assets/liabilities	4	4	3
Total	14	14	16
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	(4)	(4)	179
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	$ 99	$ 99	$ 122
LG And E And KU Energy LLC [Member] | Pension Plan [Member] | U.S. [Member]
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]
Benefit obligations valuation discount rate	2.91%	2.91%	3.62%
Benefit obligations valuation rate of compensation increase	3.50%	3.50%	3.50%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate		3.62%	4.35%	3.69%
Net periodic benefit costs rate of compensation increase		3.50%	3.50%	3.50%
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	6.50%	6.50%	6.60%	6.60%
Health care cost trend rate assumed for next year, cost	6.60%	6.60%	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%	5.00%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate), cost	5.00%	5.00%	5.00%	5.00%
Year that the rate reaches the ultimate trend rate, obligations		2027	2024	2023
Year that the rate reaches the ultimate trend rate, cost		2024	2023	2022
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period		$ 1,684	$ 1,580
Service cost		24	22	$ 25
Interest cost		57	66	63
Participant contributions		0	0
Plan Amendments		2	2
Actuarial (gain) loss		164	166
Settlements		(83)	(16)
Gross benefits paid		(63)	(136)
Benefit Obligation, end of period	$ 1,785	1,785	1,684	1,580
Change in Plan Assets [Roll Forward]
Balance at beginning of period		1,470	1,294
Actual return on plan assets		294	304
Employer contributions	23	50	24
Participant contributions		0	0
Settlements		(83)	(16)
Gross benefits paid		(63)	(136)
Balance at end of period	1,668	1,668	1,470	$ 1,294
Funded Status, end of period	(117)	(117)	(214)
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	0	0	24
Current liability	(5)	(5)	(5)
Noncurrent liability	(112)	(112)	(233)
Net amount recognized, end of period	(117)	(117)	(214)
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)	23	23	30
Net actuarial (gain) loss	296	296	380
Total	319	319	410
Total accumulated benefit obligation for defined benefit pension plans	1,657	1,657	1,561
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
AOCI	127	127	132
Regulatory assets/liabilities	192	192	278
Total	319	319	410
Pension Plans Where the Projected or Accumulated Benefit Obligation Exceed the Fair Value of Plan Assets (Details) [Abstract]
Projected benefit obligations	1,785	1,785	1,398
Fair value of plan assets where the projected benefit obligations exceed the value of plan assets	1,668	1,668	1,160
Accumulated benefit obligation	104	104	1,276
Fair value of plan assets where the accumulated benefit obligations exceed the value of plan assets	$ 0	$ 0	$ 1,160
LG And E And KU Energy LLC [Member] | Other Postretirement Benefits Plan [Member]
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]
Benefit obligations valuation discount rate	2.85%	2.85%	3.59%
Benefit obligations valuation rate of compensation increase	3.50%	3.50%	3.50%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate		3.59%	4.32%	3.65%
Net periodic benefit costs rate of compensation increase		3.50%	3.50%	3.50%
Net periodic benefit costs expected return on plan assets		7.02%	7.00%	7.15%
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period		$ 208	$ 205
Service cost		4	4	$ 4
Interest cost		7	8	8
Participant contributions		9	7
Plan Amendments		5	0
Actuarial (gain) loss		18	5
Settlements		0	0
Gross benefits paid		(22)	(21)
Benefit Obligation, end of period	$ 229	229	208	205
Change in Plan Assets [Roll Forward]
Balance at beginning of period		141	117
Actual return on plan assets		28	27
Employer contributions		4	11
Participant contributions		9	7
Settlements		0	0
Gross benefits paid		(22)	(21)
Balance at end of period	160	160	141	$ 117
Funded Status, end of period	(69)	(69)	(67)
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	0	0	11
Current liability	(2)	(2)	(2)
Noncurrent liability	(67)	(67)	(76)
Net amount recognized, end of period	(69)	(69)	(67)
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)	14	14	10
Net actuarial (gain) loss	(37)	(37)	(37)
Total	(23)	(23)	(27)
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
AOCI	2	2	4
Regulatory assets/liabilities	(25)	(25)	(31)
Total	$ (23)	$ (23)	$ (27)
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | U.S. [Member]
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]
Benefit obligations valuation discount rate	0.00%	0.00%	3.60%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate		0.00%	4.33%	3.65%
Net periodic benefit costs expected return on plan assets		0.00%	7.25%	7.25%
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period		$ 286	$ 285
Service cost			1	$ 1
Interest cost			11	12
Actuarial (gain) loss			25
Gross benefits paid			(36)
Benefit Obligation, end of period			286	285
Change in Plan Assets [Roll Forward]
Balance at beginning of period		310	281
Actual return on plan assets			64
Employer contributions			1
Gross benefits paid			(36)
Balance at end of period			310	$ 281
Funded Status, end of period			24
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset			24
Net amount recognized, end of period			24
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)			17
Net actuarial (gain) loss			79
Total			96
Total accumulated benefit obligation for defined benefit pension plans			286
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
Total			96
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	$ (78)	(78)	(7)
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	68	68	63
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	(62)	(62)	(31)
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	$ 16	$ 16	$ 16

Retirement and Postemployment_5

Retirement and Postemployment Benefits (Plan Assets and Expected Cash Flows) (Details) - USD ($) $ in Millions	1 Months Ended		12 Months Ended
	Jan. 31, 2021	Dec. 31, 2020	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2020	Dec. 31, 2019
Pension Plan [Member] | U.S. [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	$ 4,068	$ 4,068	$ 4,068	$ 3,109	$ 4,068	$ 3,585
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	4,068		3,585	3,109
Balance at end of period		4,068	4,068	3,585
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions			$ 115	63
Amount to be contributed to plan in the next fiscal year					0
Expected amount of benefit payments in the next period for non-qualified plans					18
Estimated Future Benefit Payments (Details) [Abstract]
2021					296
2022					284
2023					279
2024					275
2025					273
2026-2030					$ 1,273
Pension Plan [Member] | U.S. [Member] | Subsequent Event [Member]
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions	30
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					$ 45
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	4,068	4,068	$ 3,585	3,585	4,068	$ 3,585
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		4,068	4,068	3,585
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	695	695	685	685	695	685
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	695		685
Balance at end of period		695	695	685
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	1,007	1,007	949	949	1,007	949
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	1,007		949
Balance at end of period		1,007	1,007	949
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	15	15	24	46	15	24
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	15		24	46
Actual return on plan assets relating to assets still held at the reporting date				3
Actual return on plan assets relating to assets sold during the period				3
Purchases, sales and settlements			(9)	(28)
Balance at end of period		15	15	24
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					300	182
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					300	182
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 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]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share					742	451
Measured at fair value not using net asset value per share					60	194
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					60	194
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 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] | International Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share					566	554
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					712	621
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					336	310
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					335	309
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 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] | 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					1,045	951
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 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share					1,030	931
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					15	20
Fair value at end of period	15	15	20	20	15	20
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	15		20	25
Actual return on plan assets relating to assets still held at the reporting date				(1)
Actual return on plan assets relating to assets sold during the period				3
Purchases, sales and settlements			(5)	(7)
Balance at end of period		15	15	20
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					13	14
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 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share					13	14
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] | 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					76	88
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	4,110	4,110	3,628	3,628	4,110	3,628
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	4,110		3,628
Balance at end of period		4,110	4,110	3,628
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					68	62
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					223	194
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					(37)	3
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 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share					(37)	3
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] | Insurance Contracts [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share					0	4
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Insurance Contracts [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] | Insurance Contracts [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] | Insurance Contracts [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	4
Fair value at end of period	0	0	0	21	0	4
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	0		4	21
Actual return on plan assets relating to assets still held at the reporting date				4
Actual return on plan assets relating to assets sold during the period				0
Purchases, sales and settlements			(4)	(21)
Balance at end of period		0	0	4
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	116	116	99	99	116	99
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	116		99
Balance at end of period		116	116	99
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	(158)	(158)	(142)	(142)	(158)	(142)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	(158)		(142)
Balance at end of period		(158)	(158)	(142)
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 not using net asset value per share					$ 6	$ 0
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Growth Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets					56.00%	57.00%
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					34.00%	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%	14.00%
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					9.00%	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%	42.00%
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					33.00%	35.00%
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					10.00%	7.00%
Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Liquidity Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets					1.00%	1.00%
Target Allocations (Details ) [Abstract]
Target asset allocation					2.00%
Pension Plan [Member] | U.K. [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	9,970	9,970	9,970	7,801	$ 9,970	$ 8,945
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	9,970		8,945	7,801
Balance at end of period		9,970	9,970	8,945
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions			$ 272	278
Amount to be contributed to plan in the next fiscal year					183
Recurrence of formal actuarial valuations (in years)			3 years
Percentage of deficit funding requirements permitted to recover in rates			78.00%
Estimated Future Benefit Payments (Details) [Abstract]
2021					362
2022					367
2023					370
2024					375
2025					377
2026-2030					1,884
Pension Plan [Member] | U.K. [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	412	412	$ 154	154	412	154
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	412		154
Balance at end of period		412	412	154
Pension Plan [Member] | U.K. [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	4,209	4,209	3,824	3,824	4,209	3,824
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	4,209		3,824
Balance at end of period		4,209	4,209	3,824
Pension Plan [Member] | U.K. [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	0	0	0	0	$ 0	$ 0
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	0		0
Balance at end of period		0	0	0
Pension Plan [Member] | U.K. [Member] | Cash And Cash Equivalents [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets					4.00%	2.00%
Target Allocations (Details ) [Abstract]
Target asset allocation					0.00%
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share					$ 412	$ 154
Pension Plan [Member] | U.K. [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					412	154
Pension Plan [Member] | U.K. [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.K. [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.K. [Member] | U.K. Companies Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets					0.00%	0.00%
Target Allocations (Details ) [Abstract]
Target asset allocation					2.00%
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share					$ 1	$ 22
Pension Plan [Member] | U.K. [Member] | European Companies Excluding U.K. Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets					0.00%	0.00%
Target Allocations (Details ) [Abstract]
Target asset allocation					1.00%
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share					$ 3	$ 54
Pension Plan [Member] | U.K. [Member] | Asian Pacific Companies Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets					0.00%	0.00%
Target Allocations (Details ) [Abstract]
Target asset allocation					1.00%
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share					$ 3	$ 35
Pension Plan [Member] | U.K. [Member] | North American Companies Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets					0.00%	1.00%
Target Allocations (Details ) [Abstract]
Target asset allocation					1.00%
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share					$ 3	$ 74
Pension Plan [Member] | U.K. [Member] | Emerging Markets Companies Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets					0.00%	0.00%
Target Allocations (Details ) [Abstract]
Target asset allocation					1.00%
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share					$ 1	$ 32
Pension Plan [Member] | U.K. [Member] | Global Equities Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets					23.00%	19.00%
Target Allocations (Details ) [Abstract]
Target asset allocation					9.00%
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share					$ 2,253	$ 1,684
Pension Plan [Member] | U.K. [Member] | Global Tactical Asset Allocation Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets					20.00%	29.00%
Target Allocations (Details ) [Abstract]
Target asset allocation					41.00%
Pension Plan [Member] | U.K. [Member] | Other Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share					$ 1,950	$ 2,584
Pension Plan [Member] | U.K. [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets					48.00%	43.00%
Target Allocations (Details ) [Abstract]
Target asset allocation					38.00%
Pension Plan [Member] | U.K. [Member] | U.K. Corporate Bonds Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share					$ 574	$ 0
Measured at fair value not using net asset value per share					0	5
Pension Plan [Member] | U.K. [Member] | U.K. Corporate Bonds Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share					0	0
Measured at fair value not using net asset value per share					0	0
Pension Plan [Member] | U.K. [Member] | U.K. Corporate Bonds Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share					0	0
Measured at fair value not using net asset value per share					0	5
Pension Plan [Member] | U.K. [Member] | U.K. Corporate Bonds Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share					0	0
Measured at fair value not using net asset value per share					0	0
Pension Plan [Member] | U.K. [Member] | U.K. Gilts Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share					4,209	3,819
Pension Plan [Member] | U.K. [Member] | U.K. Gilts 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.K. [Member] | U.K. Gilts 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					4,209	3,819
Pension Plan [Member] | U.K. [Member] | U.K. Gilts 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.K. [Member] | Alternative Investments [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets					5.00%	6.00%
Target Allocations (Details ) [Abstract]
Target asset allocation					6.00%
Pension Plan [Member] | U.K. [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					$ 557	$ 519
Pension Plan [Member] | U.K. [Member] | Total Trust Assets Prior to Adjustments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	9,966	9,966	8,982	8,982	9,966	8,982
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	9,966		8,982
Balance at end of period		9,966	9,966	8,982
Pension Plan [Member] | U.K. [Member] | Receivables And Payables Net [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	4	4	(37)	(37)	$ 4	$ (37)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	4		(37)
Balance at end of period		4	4	(37)
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	367	301	$ 367	$ 340
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	367		340	301
Balance at end of period		367	367	340
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions			18	10
Amount to be contributed to plan in the next fiscal year					35
Estimated Future Benefit Payments (Details) [Abstract]
2021					49
2022					47
2023					46
2024					44
2025					43
2026-2030					194
Expected Federal Subsidy (Details) [Abstract]
Federal subsidy 2021					1
Federal subsidy 2022					0
Federal subsidy 2023					0
Federal subsidy 2024					0
Federal subsidy 2025					0
Federal subsidy 2026-2030					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	5	5	6	6	5	6
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	5		6
Balance at end of period		5	5	6
Other Postretirement Benefits Plan [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	39	39	35	35	39	35
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	39		35
Balance at end of period		39	39	35
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	0	0	$ 0	$ 0
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	0		0
Balance at end of period		0	$ 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					$ 5	$ 6
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					5	6
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					42.00%	45.00%
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					$ 89	$ 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					$ 77	$ 68
Other Postretirement Benefits Plan [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets					55.00%	52.00%
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					$ 2	$ 0
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					2	0
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					37	35
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					37	35
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	210	210	$ 198	198	210	198
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	210		198
Balance at end of period		210	210	198
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	(1)	(1)	0	0	(1)	0
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	(1)		0
Balance at end of period		(1)	(1)	0
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	158	158	142	142	158	142
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	158		142
Balance at end of period		158	158	142
LG And E And KU Energy LLC [Member] | Pension Plan [Member] | U.S. [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	1,668	1,668	1,470	1,470	1,668	$ 1,470
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	1,668		1,470	1,294
Balance at end of period		1,668	1,668	1,470
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions		23	$ 50	$ 24
Amount to be contributed to plan in the next fiscal year					0
Expected amount of benefit payments in the next period for non-qualified plans					6
Estimated Future Benefit Payments (Details) [Abstract]
2021					121
2022					119
2023					118
2024					117
2025					115
2026-2030					$ 533
LG And E And KU Energy LLC [Member] | 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%
Information About Plan Assets (Numeric) [Abstract]
Value of plan U.S. pension trust assets that relate to PPL subsidiary					$ 1,700	$ 1,500
Undivided interest percentage in each asset category that PPL subsidiary holds				41.00%
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					45
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	4,068	4,068	$ 3,585	$ 3,585	4,068	3,585
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		4,068	4,068	3,585
LG And E And KU Energy LLC [Member] | 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	695	695	685	685	695	685
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	695		685
Balance at end of period		695	695	685
LG And E And KU Energy LLC [Member] | 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	1,007	1,007	949	949	1,007	949
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	1,007		949
Balance at end of period		1,007	1,007	949
LG And E And KU Energy LLC [Member] | 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	15	15	24	46	15	24
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	15		24	46
Actual return on plan assets relating to assets still held at the reporting date				3
Actual return on plan assets relating to assets sold during the period				3
Purchases, sales and settlements			(9)	(28)
Balance at end of period		15	15	24
LG And E And KU Energy LLC [Member] | 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					300	182
LG And E And KU Energy LLC [Member] | 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					300	182
LG And E And KU Energy LLC [Member] | 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
LG And E And KU Energy LLC [Member] | 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
LG And E And KU Energy LLC [Member] | 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					742	451
Measured at fair value not using net asset value per share					60	194
LG And E And KU Energy LLC [Member] | 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					60	194
LG And E And KU Energy LLC [Member] | 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
LG And E And KU Energy LLC [Member] | 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
LG And E And KU Energy LLC [Member] | 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					566	554
LG And E And KU Energy LLC [Member] | 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					712	621
LG And E And KU Energy LLC [Member] | 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					336	310
LG And E And KU Energy LLC [Member] | 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					335	309
LG And E And KU Energy LLC [Member] | 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
LG And E And KU Energy LLC [Member] | 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
LG And E And KU Energy LLC [Member] | 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					1,045	951
LG And E And KU Energy LLC [Member] | 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
LG And E And KU Energy LLC [Member] | 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					1,030	931
LG And E And KU Energy LLC [Member] | 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					15	20
Fair value at end of period	15	15	20	20	15	20
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	15		20	25
Actual return on plan assets relating to assets still held at the reporting date				(1)
Actual return on plan assets relating to assets sold during the period				3
Purchases, sales and settlements			(5)	(7)
Balance at end of period		15	15	20
LG And E And KU Energy LLC [Member] | 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					13	14
LG And E And KU Energy LLC [Member] | 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
LG And E And KU Energy LLC [Member] | 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					13	14
LG And E And KU Energy LLC [Member] | 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
LG And E And KU Energy LLC [Member] | 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					76	88
LG And E And KU Energy LLC [Member] | 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	4,110	4,110	3,628	3,628	4,110	3,628
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	4,110		3,628
Balance at end of period		4,110	4,110	3,628
LG And E And KU Energy LLC [Member] | 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					68	62
LG And E And KU Energy LLC [Member] | 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					223	194
LG And E And KU Energy LLC [Member] | 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					(37)	3
LG And E And KU Energy LLC [Member] | 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
LG And E And KU Energy LLC [Member] | 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					(37)	3
LG And E And KU Energy LLC [Member] | 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
LG And E And KU Energy LLC [Member] | Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Insurance Contracts [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share					0	4
LG And E And KU Energy LLC [Member] | Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Insurance Contracts [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
LG And E And KU Energy LLC [Member] | Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Insurance Contracts [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
LG And E And KU Energy LLC [Member] | 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]
Measured at fair value not using net asset value per share					0	4
Fair value at end of period	0	0	0	21	0	4
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	0		4	21
Actual return on plan assets relating to assets still held at the reporting date				4
Actual return on plan assets relating to assets sold during the period				0
Purchases, sales and settlements			(4)	(21)
Balance at end of period		0	0	4
LG And E And KU Energy LLC [Member] | 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	116	116	99	99	116	99
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	116		99
Balance at end of period		116	116	99
LG And E And KU Energy LLC [Member] | 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	(158)	(158)	(142)	(142)	(158)	(142)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	(158)		(142)
Balance at end of period		(158)	(158)	(142)
LG And E And KU Energy LLC [Member] | 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					$ 6	$ 0
LG And E And KU Energy LLC [Member] | Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Growth Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets					56.00%	57.00%
Target Allocations (Details ) [Abstract]
Target asset allocation					55.00%
LG And E And KU Energy LLC [Member] | 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					34.00%	34.00%
LG And E And KU Energy LLC [Member] | 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%	14.00%
LG And E And KU Energy LLC [Member] | 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					9.00%	9.00%
LG And E And KU Energy LLC [Member] | 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%	42.00%
Target Allocations (Details ) [Abstract]
Target asset allocation					43.00%
LG And E And KU Energy LLC [Member] | 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					33.00%	35.00%
LG And E And KU Energy LLC [Member] | 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					10.00%	7.00%
LG And E And KU Energy LLC [Member] | Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Liquidity Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets					1.00%	1.00%
Target Allocations (Details ) [Abstract]
Target asset allocation					2.00%
LG And E And KU Energy LLC [Member] | Other Postretirement Benefits Plan [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	160	160	141	141	$ 160	$ 141
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	160		141	117
Balance at end of period		160	160	141
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions			4	11
Amount to be contributed to plan in the next fiscal year					15
Estimated Future Benefit Payments (Details) [Abstract]
2021					15
2022					16
2023					16
2024					16
2025					16
2026-2030					75
Expected Federal Subsidy (Details) [Abstract]
Federal subsidy 2021					1
Federal subsidy 2022					0
Federal subsidy 2023					0
Federal subsidy 2024					0
Federal subsidy 2025					0
Federal subsidy 2026-2030					$ 1
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | U.S. [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period			310	310		$ 310
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period			$ 310	281
Balance at end of period				310
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions				$ 1
Louisville Gas And Electric Co [Member] | 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%
Information About Plan Assets (Numeric) [Abstract]
Value of plan U.S. pension trust assets that relate to PPL subsidiary						$ 310
Undivided interest percentage in each asset category that PPL subsidiary holds			9.00%	9.00%
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					$ 45
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	4,068	4,068	$ 3,585	$ 3,585	4,068	3,585
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		4,068	4,068	3,585
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Parent [Member]
Information About Plan Assets (Numeric) [Abstract]
Value of plan U.S. pension trust assets that relate to PPL subsidiary					618	251
Louisville Gas And Electric Co [Member] | 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	695	695	685	685	695	685
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	695		685
Balance at end of period		695	695	685
Louisville Gas And Electric Co [Member] | 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	1,007	1,007	949	949	1,007	949
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	1,007		949
Balance at end of period		1,007	1,007	949
Louisville Gas And Electric Co [Member] | 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	15	15	24	46	15	24
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	15		24	46
Actual return on plan assets relating to assets still held at the reporting date				3
Actual return on plan assets relating to assets sold during the period				3
Purchases, sales and settlements			(9)	(28)
Balance at end of period		15	15	24
Louisville Gas And Electric Co [Member] | 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					300	182
Louisville Gas And Electric Co [Member] | 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					300	182
Louisville Gas And Electric Co [Member] | 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
Louisville Gas And Electric Co [Member] | 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
Louisville Gas And Electric Co [Member] | 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					742	451
Measured at fair value not using net asset value per share					60	194
Louisville Gas And Electric Co [Member] | 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					60	194
Louisville Gas And Electric Co [Member] | 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
Louisville Gas And Electric Co [Member] | 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
Louisville Gas And Electric Co [Member] | 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					566	554
Louisville Gas And Electric Co [Member] | 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					712	621
Louisville Gas And Electric Co [Member] | 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					336	310
Louisville Gas And Electric Co [Member] | 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					335	309
Louisville Gas And Electric Co [Member] | 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
Louisville Gas And Electric Co [Member] | 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
Louisville Gas And Electric Co [Member] | 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					1,045	951
Louisville Gas And Electric Co [Member] | 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
Louisville Gas And Electric Co [Member] | 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					1,030	931
Louisville Gas And Electric Co [Member] | 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					15	20
Fair value at end of period	15	15	20	20	15	20
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	15		20	25
Actual return on plan assets relating to assets still held at the reporting date				(1)
Actual return on plan assets relating to assets sold during the period				3
Purchases, sales and settlements			(5)	(7)
Balance at end of period		15	15	20
Louisville Gas And Electric Co [Member] | 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					13	14
Louisville Gas And Electric Co [Member] | 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
Louisville Gas And Electric Co [Member] | 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					13	14
Louisville Gas And Electric Co [Member] | 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
Louisville Gas And Electric Co [Member] | 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					76	88
Louisville Gas And Electric Co [Member] | 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	4,110	4,110	3,628	3,628	4,110	3,628
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	4,110		3,628
Balance at end of period		4,110	4,110	3,628
Louisville Gas And Electric Co [Member] | 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					68	62
Louisville Gas And Electric Co [Member] | 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					223	194
Louisville Gas And Electric Co [Member] | 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					(37)	3
Louisville Gas And Electric Co [Member] | 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
Louisville Gas And Electric Co [Member] | 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					(37)	3
Louisville Gas And Electric Co [Member] | 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
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Insurance Contracts [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share					0	4
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Insurance Contracts [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
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Insurance Contracts [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
Louisville Gas And Electric Co [Member] | 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]
Measured at fair value not using net asset value per share					0	4
Fair value at end of period	0	0	0	21	0	4
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	0		4	21
Actual return on plan assets relating to assets still held at the reporting date				4
Actual return on plan assets relating to assets sold during the period				0
Purchases, sales and settlements			(4)	(21)
Balance at end of period		0	0	4
Louisville Gas And Electric Co [Member] | 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	116	116	99	99	116	99
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	116		99
Balance at end of period		116	116	99
Louisville Gas And Electric Co [Member] | 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	(158)	(158)	(142)	(142)	(158)	(142)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	$ (158)		(142)
Balance at end of period		$ (158)	$ (158)	$ (142)
Louisville Gas And Electric Co [Member] | 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					$ 6	$ 0
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Growth Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets					56.00%	57.00%
Target Allocations (Details ) [Abstract]
Target asset allocation					55.00%
Louisville Gas And Electric Co [Member] | 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					34.00%	34.00%
Louisville Gas And Electric Co [Member] | 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%	14.00%
Louisville Gas And Electric Co [Member] | 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					9.00%	9.00%
Louisville Gas And Electric Co [Member] | 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%	42.00%
Target Allocations (Details ) [Abstract]
Target asset allocation					43.00%
Louisville Gas And Electric Co [Member] | 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					33.00%	35.00%
Louisville Gas And Electric Co [Member] | 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					10.00%	7.00%
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Liquidity Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets					1.00%	1.00%
Target Allocations (Details ) [Abstract]
Target asset allocation					2.00%
Kentucky Utilities Co [Member] | Pension Plan [Member] | U.S. [Member] | Master Trust [Member] | Parent [Member]
Information About Plan Assets (Numeric) [Abstract]
Value of plan U.S. pension trust assets that relate to PPL subsidiary					$ 505	$ 445

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, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	$ 42	$ 42	$ 40
PPL Electric Utilities Corp [Member]
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	6	6	6
LG And E And KU Energy LLC [Member]
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	19	21	20
Louisville Gas And Electric Co [Member]
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	6	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, 2020	Dec. 31, 2019
Trimble County Unit 1 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	75.00%	75.00%
Electric plant	$ 440	$ 440
Accumulated depreciation	64	54
Construction work in progress	$ 2	$ 2
Trimble County Unit 2 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	75.00%	75.00%
Electric plant	$ 1,340	$ 1,278
Accumulated depreciation	227	203
Construction work in progress	$ 106	$ 134
LG And E And KU Energy LLC [Member] | Trimble County Unit 1 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	75.00%	75.00%
Electric plant	$ 440	$ 440
Accumulated depreciation	64	54
Construction work in progress	$ 2	$ 2
LG And E And KU Energy LLC [Member] | Trimble County Unit 2 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	75.00%	75.00%
Electric plant	$ 1,340	$ 1,278
Accumulated depreciation	227	203
Construction work in progress	$ 106	$ 134
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	$ 46	$ 45
Accumulated depreciation	22	20
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	$ 52
Accumulated depreciation	22	20
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	$ 440	$ 440
Accumulated depreciation	64	54
Construction work in progress	$ 2	$ 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	$ 370	$ 340
Accumulated depreciation	51	43
Construction work in progress	$ 54	$ 69
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	$ 33	$ 32
Accumulated depreciation	14	12
Construction work in progress	$ 1	$ 0
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	$ 77	$ 78
Accumulated depreciation	31	27
Construction work in progress	$ 1	$ 0
Louisville Gas And Electric Co [Member] | Cane Run Unit 7 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	22.00%	22.00%
Electric plant	$ 123	$ 119
Accumulated depreciation	15	13
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	$ 1
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	$ 76	$ 75
Accumulated depreciation	37	32
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	$ 46
Accumulated depreciation	20	14
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	$ 970	$ 938
Accumulated depreciation	176	160
Construction work in progress	$ 52	$ 65
Kentucky Utilities Co [Member] | Trimble County Units 5 And 6 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	71.00%	71.00%
Electric plant	$ 77	$ 76
Accumulated depreciation	33	29
Construction work in progress	$ 4	$ 0
Kentucky Utilities Co [Member] | Trimble County Units 7 Through 10 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	63.00%	63.00%
Electric plant	$ 129	$ 128
Accumulated depreciation	53	46
Construction work in progress	$ 2	$ 0
Kentucky Utilities Co [Member] | Cane Run Unit 7 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	78.00%	78.00%
Electric plant	$ 443	$ 429
Accumulated depreciation	57	49
Construction work in progress	$ 2	$ 1
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	3	2
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	$ 2	$ 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, 2020USD ($)	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Jun. 01, 2015
Claim By Former Affiliate [Abstract]
Restructuring And Related Activities Ownership Percentage By Riverstone							35.00%
LKE [Member] | Power Purchase [Member]
Energy Purchase Commitments (Numeric) [Abstract]
2021				$ 34
2022				34
2023				34
2024				32
2025				32
Thereafter				359
Total				525
Purchases				18	$ 22	$ 20
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
LG And E And KU Energy LLC [Member] | Power Purchase [Member]
Energy Purchase Commitments (Numeric) [Abstract]
2021				34
2022				34
2023				34
2024				32
2025				32
Thereafter				359
Total				525
Purchases				18	22	20
LG And E And KU Energy LLC [Member] | 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
LG And E And KU Energy LLC [Member] | 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
LG And E And KU Energy LLC [Member] | 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]
2021				23
2022				23
2023				24
2024				22
2025				22
Thereafter				250
Total				364
Purchases				12	15	14
Kentucky Utilities Co [Member] | Power Purchase [Member]
Energy Purchase Commitments (Numeric) [Abstract]
2021				11
2022				11
2023				10
2024				10
2025				10
Thereafter				109
Total				161
Purchases				6	7	$ 6
PPL Electric Additional Sites [Member] | PPL Electric [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Accrual for Environmental Loss Contingencies				$ 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

Commitments and Contingencies_3

Commitments and Contingencies (Environmental Matter and Other) (Details) $ in Millions	1 Months Ended
	Nov. 30, 2020employees	Aug. 31, 2020employees	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
PPL Electric [Member] | PPL Electric Additional Sites [Member]
Environmental Matters - Superfund And Other Remediation (Numeric) [Abstract]
Environmental site accrual | $			$ 10
PPL Electric Utilities Corp [Member] | PPL Electric Additional Sites [Member]
Environmental Matters - Superfund And Other Remediation (Numeric) [Abstract]
Environmental site accrual | $				$ 10
LG And E And KU Energy LLC [Member] | LGE [Member]
Environmental Matters - Superfund And Other Remediation (Numeric) [Abstract]
Concentration Risk Number of Union Employees	640
LG And E And KU Energy LLC [Member] | KU [Member]
Environmental Matters - Superfund And Other Remediation (Numeric) [Abstract]
Concentration Risk Number of Union Employees		48
Louisville Gas And Electric Co [Member]
Environmental Matters - Superfund And Other Remediation (Numeric) [Abstract]
Concentration Risk Number of Union Employees	640
Kentucky Utilities Co [Member]
Environmental Matters - Superfund And Other Remediation (Numeric) [Abstract]
Concentration Risk Number of Union Employees		48

Commitments and Contingencies_4

Commitments and Contingencies (Guarantees and Other Assurances) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2020USD ($)Integer	Dec. 31, 2019USD ($)
Guarantor Obligations [Line Items]
Recorded liability for all guarantees	$ 5	$ 5
Other Guarantee (Numeric) [Abstract]
Maximum aggregate coverage bodily injury and property damage	225
PPL Guarantee [Member] | Indemnification Guarantee [Member] | WPD Indemnifications For Entities In Liquidation Sales Of Assets [Member]
Guarantor Obligations [Line Items]
Maximum exposure	$ 11
Minimum period that indemnifications generally expire (in years) | Integer	2
Maximum period that indemnifications generally expire (in years) | Integer	7
PPL Guarantee [Member] | Financial Guarantee [Member] | WPD Guarantee Of Pension And Other Obligations Of Unconsolidated Entities [Member]
Guarantor Obligations [Line Items]
Maximum exposure	$ 95
LKE Guarantee [Member] | Indemnification Guarantee [Member] | Indemnification Of Lease Termination And Other Divestitures [Member]
Guarantor Obligations [Line Items]
Maximum exposure	$ 200
Term of guarantee (in years)	12 years
Maximum exposure of guarantee related to terminated lease specific to operational, regulatory and environmental issues	$ 200
LG And E And KU Energy LLC [Member] | Indemnification Guarantee [Member] | Indemnification Of Lease Termination And Other Divestitures [Member]
Guarantor Obligations [Line Items]
Maximum exposure	$ 200
Term of guarantee (in years)	12 years
Maximum exposure of guarantee related to terminated lease specific to operational, regulatory and environmental issues	$ 200
LG And E And KU Energy LLC [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	104
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	72
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	$ 32
LGE and KU [Member] | LGE And KU Guarantee [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Maximum exposure is not estimateable	The maximum exposure and the expiration date of these potential obligations are not presently determinable.
Contingent potential proportionate share of OVEC's outstanding debt	$ 104

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Aug. 01, 2020	May 01, 2020
PPL Electric Utilities Corp [Member] | PPL Services [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	$ 50	$ 59	$ 59
Intercompany Borrowings (Numeric) [Abstract]
VEBA Funds Receivable	22	32
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	12	22
PPL Electric Utilities Corp [Member] | PPL EU Services [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	176	152	148
PPL Electric Utilities Corp [Member] | PPL Energy Funding [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany note with affiliate maximum borrowing capacity	650
Notes Receivable, Related Parties, Current	0	0
LG And E And KU Energy LLC [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes payable to affiliates	251	150
Interest Expense, Related Party	37	31	25
Long-term debt to affiliate	1,200	650
LG And E And KU Energy LLC [Member] | PPL Services [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	27	28	26
LG And E And KU Energy LLC [Member] | PPL Energy Funding [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany note with affiliate maximum borrowing capacity	375
Notes payable to affiliates	$ 251	$ 150
Intercompany borrowings demand note rate on outstanding borrowing	1.65%	3.20%
LG And E And KU Energy LLC [Member] | Affiliated Entity [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes Payable, Related Parties					$ 450
LG And E And KU Energy LLC [Member] | Affiliated Entity [Member] | Note Payable [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany borrowings demand note rate on outstanding borrowing	3.90%
Interest Expense, Related Party	$ 33
Long-term debt to affiliate	$ 1,200			$ 550
LG And E And KU Energy LLC [Member] | Company Affiliate1 [Member]
Intercompany Borrowings (Numeric) [Abstract]
Debt Instrument, Term	10 years
Interest Expense, Related Party		$ 24	21
LG And E And KU Energy LLC [Member] | PPL Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany note with affiliate maximum borrowing capacity	$ 300
Long-term debt to affiliate	0	0
Louisville Gas And Electric Co [Member] | Parent And Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany Money Pool Agreement Maximum Borrowing Capacity	750
Louisville Gas And Electric Co [Member] | LKS [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	170	160	151
Kentucky Utilities Co [Member] | Parent And Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany Money Pool Agreement Maximum Borrowing Capacity	650
Kentucky Utilities Co [Member] | LKS [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	$ 180	$ 178	$ 169

Other Income (Expense) - net (D

Other Income (Expense) - net (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Other Income [Line Items]
Economic foreign currency exchange contracts	$ (98)	$ (14)	$ 150
Defined benefit plans - non-service credits	262	316	257
Interest income	10	16	6
Allowance for funds used during construction - equity component	20	23	21
Miscellaneous	7	7	6
Total Other Income	201	348	440
Other Expense [Line Items]
Charitable contributions	3	17	24
Miscellaneous	29	22	20
Total Other Expense	32	39	44
Other Income (Expense) - net	169	309	396
PPL Electric Utilities Corp [Member]
Other Income [Line Items]
Defined benefit plans - non-service credits	4	4	5
Interest income	2	2	2
Allowance for funds used during construction - equity component	19	23	20
Total Other Income	25	29	27
Other Expense [Line Items]
Charitable contributions	3	3	3
Miscellaneous	4	1	1
Total Other Expense	7	4	4
Other Income (Expense) - net	$ 18	$ 25	$ 23

Fair Value Measurements (Assets

Fair Value Measurements (Assets and Liabilities Measured on Recurring Basis Table) (Details) - Recurring [Member] - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Assets
Cash and cash equivalents	$ 708	$ 815
Restricted cash and cash equivalents	19	21
Commingled debt fund measured at NAV	26	29
Commingled equity fund measured at NAV	25	27
Total special use funds	51	56
Price risk management assets:
Foreign currency contracts	0	142
Cross-currency swaps	146	154
Total price risk management assets	146	296
Total Assets	924	1,188
Price risk management liabilities:
Interest rate swaps	23	21
Foreign currency contracts	137	5
Total price risk management liabilities	160	26
Level 1 [Member]
Assets
Cash and cash equivalents	708	815
Restricted cash and cash equivalents	19	21
Total special use funds	0	0
Price risk management assets:
Foreign currency contracts	0	0
Cross-currency swaps	0	0
Total price risk management assets	0	0
Total Assets	727	836
Price risk management liabilities:
Interest rate swaps	0	0
Foreign currency contracts	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
Total special use funds	0	0
Price risk management assets:
Foreign currency contracts	0	142
Cross-currency swaps	146	154
Total price risk management assets	146	296
Total Assets	146	296
Price risk management liabilities:
Interest rate swaps	23	21
Foreign currency contracts	137	5
Total price risk management liabilities	160	26
Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Total special use funds	0	0
Price risk management assets:
Foreign currency contracts	0	0
Cross-currency swaps	0	0
Total price risk management assets	0	0
Total Assets	0	0
Price risk management liabilities:
Interest rate swaps	0	0
Foreign currency contracts	0	0
Total price risk management liabilities	0	0
PPL Electric Utilities Corp [Member]
Assets
Cash and cash equivalents	40	262
Restricted cash and cash equivalents	0	2
Price risk management assets:
Total Assets	40	264
PPL Electric Utilities Corp [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	40	262
Restricted cash and cash equivalents	0	2
Price risk management assets:
Total Assets	40	264
PPL Electric Utilities Corp [Member] | Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Restricted 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
Restricted cash and cash equivalents	0	0
Price risk management assets:
Total Assets	0	0
LG And E And KU Energy LLC [Member]
Assets
Cash and cash equivalents	29	27
Price risk management assets:
Total Assets	29	27
Price risk management liabilities:
Interest rate swaps	23	21
Total price risk management liabilities	23	21
LG And E And KU Energy LLC [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	29	27
Price risk management assets:
Total Assets	29	27
Price risk management liabilities:
Interest rate swaps	0	0
Total price risk management liabilities	0	0
LG And E And KU Energy LLC [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	23	21
Total price risk management liabilities	23	21
LG And E And KU Energy LLC [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
Louisville Gas And Electric Co [Member]
Assets
Cash and cash equivalents	7	15
Price risk management assets:
Total Assets	7	15
Price risk management liabilities:
Interest rate swaps	23	21
Total price risk management liabilities	23	21
Louisville Gas And Electric Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	7	15
Price risk management assets:
Total Assets	7	15
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	23	21
Total price risk management liabilities	23	21
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	22	12
Price risk management assets:
Total Assets	22	12
Kentucky Utilities Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	22	12
Price risk management assets:
Total Assets	22	12
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, 2020	Dec. 31, 2019
Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	$ 23,127	$ 21,893
Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	28,765	25,481
PPL Electric Utilities Corp [Member] | Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	4,236	3,985
PPL Electric Utilities Corp [Member] | Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	5,338	4,589
LG And E And KU Energy LLC [Member] | Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	6,074	6,002
LG And E And KU Energy LLC [Member] | Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	7,589	6,766
Louisville Gas And Electric Co [Member] | Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	2,007	2,005
Louisville Gas And Electric Co [Member] | Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	2,499	2,278
Kentucky Utilities Co [Member] | Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	2,618	2,623
Kentucky Utilities Co [Member] | Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	$ 3,334	$ 3,003

Derivative Instruments and He_4

Derivative Instruments and Hedging Activities (Intro) (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Master Netting Arrangements (Numeric) [Line Items]
Cash Collateral Obligation Under Master Netting Arrangement		$ 14
Cash Collateral Posted Under Master Netting Arrangements	$ 0	0
LG And E And KU Energy LLC [Member]
Master Netting Arrangements (Numeric) [Line Items]
Cash Collateral Obligation Under Master Netting Arrangement	0	0
Cash Collateral Posted Under Master Netting Arrangements		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) £ in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2020GBP (£)
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	702
Economic Hedges [Member] | Foreign Currency Contracts [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Total exposure hedged related to foreign currency contracts for anticipated earnings hedges classified as economic activity | £				£ 4,000
Net Investment Hedges [Member] | Foreign Currency Contracts [Member]
Foreign Currency Risk - Net Investment Hedges (Numeric) [Abstract]
Net after tax gains (losses) on net investment hedges recognized in the foreign currency translation adjustment component of AOCI	33	$ 32
LGE [Member] | Economic Hedges [Member] | Interest Rate Swaps [Member]
Interest Rate Risk And Foreign Currency Risk [Line Items]
Derivative, Notional Amount	64
LG And E And KU Energy LLC [Member] | 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, 2020	Dec. 31, 2019
Derivatives Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	$ 146	$ 154
Liability value	0	0
Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	94	5
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	94	5
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	52	149
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	52	149
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	142
Liability value	160	26
Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	142
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	142
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	139	9
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	2	4
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	137	5
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	21	17
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	21	17
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
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Liability value	23	21
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
LG And E And KU Energy LLC [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
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
LG And E And KU Energy LLC [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
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	2	4
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	2	4
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	21	17
LG And E And KU Energy LLC [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	21	17
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	23	21
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	2	4
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	2	4
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	21	17
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	$ 21	$ 17

Derivative Instruments and He_7

Derivative Instruments and Hedging Activities (Gains and Losses) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Derivative Instruments Gain Loss [Line Items]
Interest Expense	$ 1,001	$ 994	$ 963
Other Income (Expense) - net	169	309	396
Cash Flow Hedges [Member]
Derivative Instruments Gain Loss [Line Items]
Gain (Loss) Reclassified from AOCI into Income	(32)	(18)	35
Cash Flow Hedges [Member] | Other Comprehensive Income [Member]
Derivative Instruments Gain Loss [Line Items]
Derivative Gain (Loss) Recognized in OCI	(24)	(13)	45
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Other Comprehensive Income [Member]
Derivative Instruments Gain Loss [Line Items]
Derivative Gain (Loss) Recognized in OCI	(9)	(30)	4
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Other Income (Expense) Net [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Amount of gain (loss) reclassified from AOCI to income	0	0
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Interest Expense [Member]
Derivative Instruments Gain Loss [Line Items]
Gain (Loss) Reclassified from AOCI into Income	(10)	(9)	(8)
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Amount of gain (loss) reclassified from AOCI to income	(10)	(9)
Cash Flow Hedges [Member] | Cross Currency Swaps [Member] | Other Comprehensive Income [Member]
Derivative Instruments Gain Loss [Line Items]
Derivative Gain (Loss) Recognized in OCI	(15)	17	41
Cash Flow Hedges [Member] | Cross Currency Swaps [Member] | Other Income (Expense) Net [Member]
Derivative Instruments Gain Loss [Line Items]
Gain (Loss) Reclassified from AOCI into Income	(22)	(9)	42
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Amount of gain (loss) reclassified from AOCI to income	(22)	(9)
Hedged Items	22	9
Cash Flow Hedges [Member] | Cross Currency Swaps [Member] | Interest Expense [Member]
Derivative Instruments Gain Loss [Line Items]
Gain (Loss) Reclassified from AOCI into Income			1
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Amount of gain (loss) reclassified from AOCI to income	0	0
Hedged Items	0	0
Net Investment Hedges [Member] | Foreign Currency Contracts [Member] | Other Comprehensive Income [Member]
Derivative Instruments Gain Loss [Line Items]
Derivative Gain (Loss) Recognized in OCI	1	2	11
Derivatives Not Designated As Hedging Instruments [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	(103)	(19)	145
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	(2)	(1)	6
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	(5)	(5)	(5)
Derivatives Not Designated As Hedging Instruments [Member] | Foreign Currency Contracts [Member] | Other Income (Expense) Net [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	(98)	(14)	150
LG And E And KU Energy LLC [Member]
Derivative Instruments Gain Loss [Line Items]
Interest Expense	223	226	206
Other Income (Expense) - net	2	(13)	(16)
LG And E And KU Energy LLC [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	(2)	(1)	6
LG And E And KU Energy LLC [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	(5)	(5)	(5)
Louisville Gas And Electric Co [Member]
Derivative Instruments Gain Loss [Line Items]
Interest Expense	87	87	76
Other Income (Expense) - net	(1)	(11)	(12)
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	(2)	(1)	6
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	(5)	(5)	(5)
Kentucky Utilities Co [Member]
Derivative Instruments Gain Loss [Line Items]
Interest Expense	113	109	100
Other Income (Expense) - net	$ 3	$ (4)	$ (6)

Derivative Instruments and He_8

Derivative Instruments and Hedging Activities (Offsetting Derivative Instruments and Credit Risk-Related Features) (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Offsetting Assets And Liabilities [Line Items]
Cash collateral received eligible for offset - assets		$ 14
Cash collateral pledged eligible for offset - liabilities	$ 0	0
Credit Risk-Related Contingent Features [Abstract]
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features	102
Aggregate fair value of collateral posted on these derivative instruments	0
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade	102
Treasury Derivatives [Member]
Offsetting Assets And Liabilities [Line Items]
Gross assets	146	296
Derivative instruments eligible for offset - assets	34	5
Cash collateral received eligible for offset - assets	0	14
Net assets	112	277
Gross liabilities	160	26
Derivative instruments eligible for offset - liabilities	34	5
Cash collateral pledged eligible for offset - liabilities	0	0
Net liabilities	126	21
LG And E And KU Energy LLC [Member]
Offsetting Assets And Liabilities [Line Items]
Cash collateral received eligible for offset - assets	0	0
Cash collateral pledged eligible for offset - liabilities		0
LG And E And KU Energy LLC [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	23	21
Derivative instruments eligible for offset - liabilities	0	0
Cash collateral pledged eligible for offset - liabilities	0	0
Net liabilities	23	21
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	23	21
Derivative instruments eligible for offset - liabilities	0	0
Cash collateral pledged eligible for offset - liabilities	0	0
Net liabilities	23	21
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) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period	$ 3,198	$ 3,162
Effect of foreign currency exchange rates	76	34
Other	0	2
Balance at end of period	3,274	3,198
U.K. Regulated [Member]
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period	2,483	2,447
Effect of foreign currency exchange rates	76	34
Other	0	2
Balance at end of period	2,559	2,483
Kentucky Regulated [Member]
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period	662	662
Effect of foreign currency exchange rates	0	0
Other	0	0
Balance at end of period	662	662
Corporate And Other [Member]
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period	53	53
Effect of foreign currency exchange rates	0	0
Other	0	0
Balance at end of period	$ 53	$ 53

Goodwill and Other Intangible_4

Goodwill and Other Intangible Assets (Other Intangibles) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Subject to amortization: [Abstract]
Gross carrying amount	$ 617	$ 598
Accumulated amortization	239	222
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount	386	367
Gross carrying amount - other intangible assets	1,003	965
Land Rights and Easements [Member]
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount	380	361
Other [Member]
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount	6	6
Contracts [Member]
Subject to amortization: [Abstract]
Gross carrying amount	136	136
Accumulated amortization	93	84
Land Rights And Easements [Member]
Subject to amortization: [Abstract]
Gross carrying amount	460	440
Accumulated amortization	142	135
Licenses And Other [Member]
Subject to amortization: [Abstract]
Gross carrying amount	21	22
Accumulated amortization	4	3
Intangible assets with no regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	11	9	$ 7
Forecasted amortization in 2021								$ 11
Forecasted amortization in 2022							$ 11
Forecasted amortization in 2023						$ 11
Forecasted amortization in 2024					$ 11
Forecasted amortization in 2025				$ 11
Intangible assets with regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	8	9	8
Forecasted amortization in 2021								8
Forecasted amortization in 2022							8
Forecasted amortization in 2023						8
Forecasted amortization in 2024					8
Forecasted amortization in 2025				8
Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits [Member]
Subject to amortization: [Abstract]
Amortization expense	19	18	15
Forecasted amortization in 2021								19
Forecasted amortization in 2022							19
Forecasted amortization in 2023						19
Forecasted amortization in 2024					19
Forecasted amortization in 2025				19
PPL Electric Utilities Corp [Member]
Subject to amortization: [Abstract]
Gross carrying amount	381	373
Accumulated amortization	130	126
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount - other intangible assets	398	390
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
PPL Electric Utilities Corp [Member] | Land Rights And Easements [Member]
Subject to amortization: [Abstract]
Gross carrying amount	379	370
Accumulated amortization	129	125
PPL Electric Utilities Corp [Member] | Licenses And Other [Member]
Subject to amortization: [Abstract]
Gross carrying amount	2	3
Accumulated amortization	1	1
LG And E And KU Energy LLC [Member]
Subject to amortization: [Abstract]
Gross carrying amount	147	147
Accumulated amortization	86	78
LG And E And KU Energy LLC [Member] | Land Rights And Easements [Member]
Subject to amortization: [Abstract]
Gross carrying amount	22	22
Accumulated amortization	4	4
LG And E And KU Energy LLC [Member] | OVEC power purchase agreement [Member]
Subject to amortization: [Abstract]
Gross carrying amount	125	125
Accumulated amortization	82	74
LG And E And KU Energy LLC [Member] | Intangible assets with regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	8	9	8
Forecasted amortization in 2021								8
Forecasted amortization in 2022							8
Forecasted amortization in 2023						8
Forecasted amortization in 2024					8
Forecasted amortization in 2025				8
Louisville Gas And Electric Co [Member]
Subject to amortization: [Abstract]
Gross carrying amount	93	93
Accumulated amortization	58	52
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	57	51
Louisville Gas And Electric Co [Member] | Intangible assets with regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	6	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	6
Kentucky Utilities Co [Member]
Subject to amortization: [Abstract]
Gross carrying amount	54	54
Accumulated amortization	28	26
Kentucky Utilities Co [Member] | Land Rights And Easements [Member]
Subject to amortization: [Abstract]
Gross carrying amount	15	15
Accumulated amortization	3	3
Kentucky Utilities Co [Member] | OVEC power purchase agreement [Member]
Subject to amortization: [Abstract]
Gross carrying amount	39	39
Accumulated amortization	25	23
Kentucky Utilities Co [Member] | Intangible assets with regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	2	3	2
Forecasted amortization in 2021	2
Forecasted amortization in 2022	2
Forecasted amortization in 2023	2
Forecasted amortization in 2024	2
Forecasted amortization in 2025	2
PPL Electric [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

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	$ 282	$ 347
Accretion	17	19
Obligations incurred	0	0
Changes in estimated cash flow or settlement date	38	12
Effect of foreign currency exchange rates	1	0
Obligations settled	(88)	(96)
Balance at End of Period	250	282
LG And E And KU Energy LLC [Member]
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	215	296
Accretion	15	17
Obligations incurred	0	0
Changes in estimated cash flow or settlement date	40	(2)
Effect of foreign currency exchange rates	0	0
Obligations settled	(88)	(96)
Balance at End of Period	182	215
Louisville Gas And Electric Co [Member]
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	73	103
Accretion	5	6
Obligations incurred	0	0
Changes in estimated cash flow or settlement date	13	(2)
Effect of foreign currency exchange rates	0	0
Obligations settled	(24)	(34)
Balance at End of Period	67	73
Kentucky Utilities Co [Member]
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	142	193
Accretion	10	11
Obligations incurred	0	0
Changes in estimated cash flow or settlement date	27	0
Effect of foreign currency exchange rates	0	0
Obligations settled	(64)	(62)
Balance at End of Period	$ 115	$ 142

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Income (Loss) (After-tax Changes by Component) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	$ (4,358)	$ (3,964)	$ (3,422)
Amounts arising during the year	(94)	(496)	(606)
Reclassifications from AOCI	232	102	115
Net OCI during the year	138	(394)	(491)
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment			(51)
Balance at end of year	(4,220)	(4,358)	(3,964)
Foreign Currency Translation Adjustments [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(1,425)	(1,533)	(1,089)
Amounts arising during the year	267	108	(444)
Reclassifications from AOCI	0	0	0
Net OCI during the year	267	108	(444)
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment			0
Balance at end of year	(1,158)	(1,425)	(1,533)
Qualifying Derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(5)	(7)	(13)
Amounts arising during the year	(19)	(11)	36
Reclassifications from AOCI	24	13	(29)
Net OCI during the year	5	2	7
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment			(1)
Balance at end of year	0	(5)	(7)
Prior Service Costs [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(18)	(19)	(7)
Amounts arising during the year	(1)	(1)	(11)
Reclassifications from AOCI	3	2	2
Net OCI during the year	2	1	(9)
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment			(3)
Balance at end of year	(16)	(18)	(19)
Defined Benefit Plans Actuarial Gain (Loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(2,910)	(2,405)	(2,313)
Amounts arising during the year	(341)	(592)	(187)
Reclassifications from AOCI	205	87	142
Net OCI during the year	(136)	(505)	(45)
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment			(47)
Balance at end of year	(3,046)	(2,910)	(2,405)
Accumulated Defined Benefit Plans Net [Member] | WPD [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at end of year	2,900
LG And E And KU Energy LLC [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(93)	(89)	(88)
Amounts arising during the year	(8)	(7)	7
Reclassifications from AOCI	15	3	10
Net OCI during the year	7	(4)	17
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment			(18)
Balance at end of year	(86)	(93)	(89)
LG And E And KU Energy LLC [Member] | Prior Service Costs [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(9)	(9)	(9)
Amounts arising during the year	(1)	(1)	0
Reclassifications from AOCI	2	1	2
Net OCI during the year	1	0	2
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment			(2)
Balance at end of year	(8)	(9)	(9)
LG And E And KU Energy LLC [Member] | Defined Benefit Plans Actuarial Gain (Loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(84)	(80)	(79)
Amounts arising during the year	(7)	(6)	7
Reclassifications from AOCI	13	2	8
Net OCI during the year	6	(4)	15
Adoption of reclassification of certain tax effects from AOCI guidance cumulative effect adjustment			(16)
Balance at end of year	$ (78)	$ (84)	$ (80)

Accumulated Other Comprehensi_4

Accumulated Other Comprehensive Income (Loss) (Income (Expense) Effect of Reclassifications) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Affected Line Item on the Statements of Income
Interest Expense	$ (1,001)	$ (994)	$ (963)
Other Income (Expense) - net	169	309	396
Total Pre-tax	1,971	2,155	2,285
Income Taxes	(502)	(409)	(458)
Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Total After-Tax	(232)	(102)	(115)
Qualifying Derivatives [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Total Pre-tax	(32)	(18)	35
Income Taxes	8	5	(6)
Total After-Tax	(24)	(13)	29
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	(10)	(9)	(8)
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	0	0	1
Other Income (Expense) - net	(22)	(9)	42
Defined Benefit Plans [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Total Pre-tax	(260)	(112)	(180)
Income Taxes	52	23	36
Total After-Tax	(208)	(89)	(144)
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	(4)	(3)	(2)
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	$ (256)	$ (109)	$ (178)

SCHEDULE I - CONDENSED UNCONS_4

SCHEDULE I - CONDENSED UNCONSOLIDATED BALANCE SHEETS (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions		Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Current Assets
Cash and cash equivalents		$ 708	$ 815
Accounts Receivable [Abstract]
Other		91	105
Accounts receivable		790	687
Prepayments		96	79
Price risk management assets		94	147
Other current assets		130	98
Total Current Assets		2,768	2,767
Other Noncurrent Assets [Abstract]
Price risk management assets		52	149
Other noncurrent assets		398	386
Total Other Noncurrent Assets		6,456	6,431
Total Assets		48,116	45,680
Current Liabilities [Abstract]
Short-term debt		1,662	1,151
Long-term debt due within one year		1,574	1,172
Dividends		319	317
Taxes		91	99
Other current liabilities		684	535
Total Current Liabilities		5,977	4,900
Long-term Debt [Abstract]
Long-term Debt		21,553	20,721
Total Deferred Credits and Other Noncurrent Liabilities		7,213	7,068
Equity [Abstract]
Common stock	[1]	8	8
Additional paid-in capital		12,270	12,214
Earnings reinvested		5,315	5,127
Accumulated other comprehensive loss		(4,220)	(4,358)	$ (3,964)	$ (3,422)
Total Equity		13,373	12,991	11,657	10,761
Total Liabilities and Equity		$ 48,116	$ 45,680
PPL Corporation Shareowners' Common Equity Additional Information [Abstract]
Common stock par value		$ 0.01	$ 0.01
Common stock shares authorized		1,560,000	1,560,000
Common stock shares issued		768,907	767,233
Common stock shares outstanding		768,907	767,233
LG&E and KU Energy LLC Unconsolidated [Member]
Current Assets
Cash and cash equivalents		$ 0	$ 0	$ 0	$ 0
Accounts Receivable [Abstract]
Accounts receivable from affiliates		4	3
Income Taxes Receivable, Current		2	3
Notes receivable from affiliates		1,100	1,105
Total Current Assets		1,106	1,111
Investments [Abstract]
Affiliated companies at equity		5,944	5,577
Other Noncurrent Assets [Abstract]
Deferred income taxes		276	314
Total Assets		7,326	7,002
Current Liabilities [Abstract]
Notes payable to affiliates		251	150
Long-term debt due within one year		250	475
Accounts payable with affiliates		499	489
Taxes		5	0
Other current liabilities		2	6
Total Current Liabilities		1,007	1,120
Long-term Debt [Abstract]
Long-term debt		0	249
Notes payable to affiliates		1,203	691
Long-term Debt		1,203	940
Total Deferred Credits and Other Noncurrent Liabilities		0	0
Equity [Abstract]
Members Equity		5,116	4,942
Total Liabilities and Equity		$ 7,326	$ 7,002
[1]	1,560,000 shares authorized; 768,907 and 767,233 shares issued and outstanding at December 31, 2020 and December 31, 2019.

SCHEDULE I - NOTES TO CONDENSED

SCHEDULE I - NOTES TO CONDENSED UNCONSOLIDATED FINANCIAL STATEMENTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Condensed Unconsolidated Financial Statements [Line Items]
2022	$ 1,374
Aggregate maturities of long-term debt (Details) [Abstract]
2021	950
Principal outstanding	23,249	$ 22,002
Thereafter	15,916
LKE Guarantee [Member] | Indemnification Guarantee [Member] | Indemnification Of Lease Termination And Other Divestitures [Member]
Condensed Unconsolidated Financial Statements [Line Items]
Maximum exposure	$ 200
Term of guarantee (in years)	12 years
Maximum exposure of guarantee related to terminated lease specific to operational, regulatory and environmental issues	$ 200
LG&E and KU Energy LLC Unconsolidated [Member] | LKE Guarantee [Member] | Indemnification Guarantee [Member] | Indemnification Of Lease Termination And Other Divestitures [Member]
Condensed Unconsolidated Financial Statements [Line Items]
Term of guarantee (in years)	12 years
Maximum exposure of guarantee related to terminated lease specific to operational, regulatory and environmental issues	$ 200